WO2022076106A1 - Accouplements de tige de pompage et raccords de tige comportant des éléments de diamant polycristallin - Google Patents

Accouplements de tige de pompage et raccords de tige comportant des éléments de diamant polycristallin Download PDF

Info

Publication number
WO2022076106A1
WO2022076106A1 PCT/US2021/048247 US2021048247W WO2022076106A1 WO 2022076106 A1 WO2022076106 A1 WO 2022076106A1 US 2021048247 W US2021048247 W US 2021048247W WO 2022076106 A1 WO2022076106 A1 WO 2022076106A1
Authority
WO
WIPO (PCT)
Prior art keywords
sucker rod
polycrystalline diamond
engagement
metal
tubular
Prior art date
Application number
PCT/US2021/048247
Other languages
English (en)
Inventor
Michael R. Reese
David P. Miess
Gregory Prevost
Edward C. Spatz
William W. King
Original Assignee
XR Downhole, LLC
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by XR Downhole, LLC filed Critical XR Downhole, LLC
Priority to CN202180065571.1A priority Critical patent/CN116391070A/zh
Publication of WO2022076106A1 publication Critical patent/WO2022076106A1/fr

Links

Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
    • E21B17/10—Wear protectors; Centralising devices, e.g. stabilisers
    • E21B17/1071—Wear protectors; Centralising devices, e.g. stabilisers specially adapted for pump rods, e.g. sucker rods
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B12/00—Accessories for drilling tools
    • E21B12/04—Drill bit protectors

Definitions

  • the present disclosure relates to polycrystalline diamond elements for use as protection between tubulars that are movably engaged with one another; to apparatus and systems including the same; and to methods of making, assembling, and using the same.
  • Polycrystalline diamond elements have, in the past, been contraindicated for engagement with the inner surfaces of casing or production tubing.
  • polycrystalline diamond including thermally stable polycrystalline diamond and polycrystalline diamond compact, has been considered as contraindicated for use in the engagement with ferrous metals, and other metals, metal alloys, composites, hardfacings, coatings, or platings that contain more than trace amounts of diamond solvent-catalyst including cobalt, nickel, ruthenium, rhodium, palladium, chromium, manganese, copper, titanium, or tantalum.
  • Some embodiments of the present disclosure include a sucker rod assembly.
  • the assembly includes production tubing positioned within a wellbore.
  • the production tubing has an internal cavity wall defining a cavity of the production tubing.
  • the internal cavity wall is a metal surface including a metal that contains at least 2 wt.% of a diamond solvent-catalyst based on a total weight of the metal.
  • a sucker rod string is positioned within the cavity of the production tubing.
  • the sucker rod string includes a first sucker rod, a second sucker rod, and a sucker rod coupler. The first sucker rod is coupled with a first end of the sucker rod coupler, and the second sucker rod is coupled with a second end of the sucker rod coupler.
  • a plurality of polycrystalline diamond elements are coupled with the sucker rod coupler.
  • Each polycrystalline diamond element has an engagement surface of polycrystalline diamond.
  • the engagement surfaces of polycrystalline diamond are positioned along the sucker rod string to interface engagement between the sucker rod string and the metal surface of the production tubing.
  • Some embodiments of the present disclosure include a method of interfacing engagement between a sucker rod string and production tubing.
  • the method includes providing a sucker rod string having a first sucker rod, a second sucker rod, and a sucker rod coupler.
  • the first sucker rod is coupled with a first end of the sucker rod coupler
  • the second sucker rod is coupled with a second end of the sucker rod coupler.
  • the method includes positioning a plurality of polycrystalline diamond elements on the sucker rod coupler. Each polycrystalline diamond element has an engagement surface of polycrystalline diamond.
  • the method includes providing production tubing positioned within a wellbore.
  • the production tubing has an internal cavity wall defining a cavity.
  • the internal cavity wall is a metal surface including a metal that contains at least 2 wt.% of a diamond solvent-catalyst based on a total weight of the metal.
  • the method includes positioning the sucker rod string within the cavity of the production tubing such that the engagement surfaces of polycrystalline diamond are positioned along the sucker rod string to interface engagement between the sucker rod string and the metal surface of the production tubing.
  • Some embodiments ofthe present disclosure include a downhole tubular assembly.
  • the assembly includes a tubular having a first end, a second end, and a tool joint at the second end.
  • a plurality of polycrystalline diamond elements are coupled with the tool joint.
  • Each polycrystalline diamond element has an engagement surface of polycrystalline diamond.
  • the assembly includes casing in a wellbore.
  • the casing has an internal wall having a metal surface.
  • the metal surface includes a metal that contains at least 2 wt.% of a diamond solvent-catalyst based on a total weight of the metal.
  • the tubular is positioned within the casing such that the engagement surfaces of the polycrystalline diamond are positioned to interface engagement between the tool joint and the internal wall of the casing.
  • Some embodiments of the present disclosure include a method of interfacing engagement between a tool joint and casing.
  • the method includes providing a tubular having a first end, a second end, and a tool joint at the second end.
  • the method includes coupling a plurality of polycrystalline diamond elements with the tool joint.
  • Each polycrystalline diamond element has an engagement surface of polycrystalline diamond.
  • the method includes providing casing in a wellbore.
  • the casing has an internal wall having a metal surface.
  • the metal surface includes a metal that contains at least 2 wt.% of a diamond solvent-catalyst based on a total weight of the metal.
  • the method includes positioning the tubular in the casing such that the engagement surfaces of the polycrystalline diamond are positioned to interface engagement between the tool joint and the internal wall ofthe casing.
  • FIG. 1A is a side view of a tubular engagement interface including polycrystalline diamond elements extending above an engagement surface of a body of the tubular engagement interface.
  • FIG. 1B is a side view of a tubular engagement interface including polycrystalline diamond elements that are flush with an engagement surface of a body of the tubular engagement interface.
  • FIG. 1C is a side view of a tubular engagement interface including polycrystalline diamond elements positioned below an engagement surface of a body of the tubular engagement interface.
  • FIG. 1D is a top view of a tubular engagement interface including polycrystalline diamond elements.
  • FIG. 2A is a perspective view of a hollow tubular.
  • FIG. 2B is an end view of the hollow tubular of FIG. 2A.
  • FIG. 2C is a perspective view of a hollow tubular having a smaller diameter than that of FIG. 2A.
  • FIG. 2D is a perspective view of a solid tubular.
  • FIG. 2E is a perspective view of a relatively smaller diameter tubular movably engaged within a relative larger diameter tubular, with a tubular engagement interface coupled on the relatively larger diameter tubular and interfacing the engagement therebetween.
  • FIG. 2F is a perspective view of a relatively smaller diameter tubular movably engaged within a relatively larger diameter tubular, with a tubular engagement interface coupled on the relatively smaller diameter tubular and interfacing the engagement therebetween.
  • FIG. 3A is a side view of a tubular engagement interface including polycrystalline diamond elements positioned below an engagement surface of a body of the tubular engagement interface, prior to the occurrence of wear.
  • FIG. 3B is a side view of a tubular engagement interface including polycrystalline diamond elements that are flush with an engagement surface of a body of the tubular engagement interface, with the polycrystalline diamond elements positioned within a socket in the body.
  • FIG. 3C is a side view of a tubular engagement interface including polycrystalline diamond elements extending above an engagement surface of a body of the tubular engagement interface, with the polycrystalline diamond elements positioned within a socket in the body.
  • FIG. 3D is a side view of the tubular engagement interface of FIG. 3A, after the occurrence of wear.
  • FIG. 4A is a perspective view of a sucker rod and sucker rod guide with polycrystalline diamond elements thereon.
  • FIG. 4B is a side view of the sucker rod and sucker rod guide of FIG. 4A.
  • FIG. 4C is a top view of the sucker rod and sucker rod guide of FIG. 4A.
  • FIG. 4D is a top view of the sucker rod and sucker rod guide of FIG. 4A positioned within production tubing.
  • FIG. 5 is a side view of another sucker rod guide with polycrystalline diamond elements thereon.
  • FIG. 6 is a partial, perspective view of a drill pipe protector frame having polycrystalline diamond elements thereon.
  • FIG. 7A is a side view of a pipe protector, including polycrystalline diamond elements thereon, on a drill pipe.
  • FIG. 7B is an end view of the pipe protector and drill pipe of FIG. 7A.
  • FIG. 7C is an end view of the pipe protector and drill pipe of FIG. 7A, positioned within a wellbore casing.
  • FIG. 8 is a cross-sectional view of a drill pipe protector having polycrystalline diamond elements thereon.
  • FIG. 9 is another perspective view of a drill pipe protector having polycrystalline diamond elements thereon.
  • FIG. 10 depicts a sucker rod.
  • FIG. 11 depicts a sucker rod coupler.
  • FIG. 12 is an end view of a sucker rod coupler positioned within production tubing.
  • FIG. 13 is a cross-sectional view of a sucker rod string positioned within production tubing.
  • FIG. 14 depicts the sucker rod string of FIG. 13 in isolation from the production tubing.
  • FIG. 15A depicts a tubular positioned in a casing, with the tubular having a tool joint with polycrystalline diamond elements.
  • FIG. 15B depicts the tubular of FIG. 15A, with the polycrystalline diamond elements engaged with a surface of the casing.
  • Certain embodiments of the present disclosure include polycrystalline diamond elements for use as protection between tubulars that are movably engaged with one another; protectors or guides including the polycrystalline diamond elements; tubular assemblies including the protectors or guides; apparatus and systems including the tubular assemblies; and to methods of making, assembling, and using the polycrystalline diamond elements, the protectors or guides, the tubular assemblies, and the apparatus and systems.
  • Engagement interface 10 includes body 12.
  • Body 12 may be or include a material such as metal, such as steel, or a polymer, such as a rubber or a plastic.
  • Some exemplary polymers of which body 12 may be or include are nylon, polyurethane, polyamide (e.g., synthetic polyamide), or polyether ether ketone (PEEK).
  • Body 12 is not limited to being or including any of these particular materials.
  • Engagement interface 10 includes a plurality of polycrystalline diamond elements 14.
  • Each polycrystalline diamond element 14 is coupled with body 12.
  • each polycrystalline diamond element 14 maybe embedded within body 12 or otherwise coupled to body 12.
  • body 12 may be molded onto, over, or with polycrystalline diamond elements 14 via a polymer molding process.
  • FIGS. 1B and 1C show variations of polycrystalline diamond elements 14 embedded into body 12, with body 12 molded over polycrystalline diamond elements 14.
  • polyctystalline diamond elements 14 may be attached to body 12, such as attached onto the surface of body 12 or attached within a machined recess in body 12.
  • FIG. 1A shows polycrystalline diamond elements 14 attached on top of body 12.
  • polycrystalline diamond elements 14 are static relative to body 12.
  • Body 12 includes body engagement surface 16, and each polycrystalline diamond element 14 includes a diamond engagement surface 18.
  • polycrystalline diamond elements 14 extend above body engagement surface 16, such that diamond engagement surfaces 18 are positioned above body engagement surface 16 by first distance 20.
  • diamond engagement surfaces 18 are flush with body engagement surface 16, such that diamond engagement surfaces 18 lie in the same plane 24 as (i.e., are coplanar with) body engagement surface 16.
  • body engagement surface 16 extends above diamond engagement surfaces 18, such that body engagement surface 16 is positioned above each of diamond engagement surfaces 18 by second distance 22.
  • engagement surface refers to the surface of a material (e.g., polycrystalline diamond or polymer or steel) that is positioned and arranged within an assembly (e.g., within a tubular assembly) such that, in operation of the assembly, the engagement surface interfaces contact between two tubulars of the tubular assembly.
  • a material e.g., polycrystalline diamond or polymer or steel
  • the diamond engagement surface and/or body engagement surface are not limited to being necessarily in constant engagement with the opposing engagement surface. Rather, the diamond engagement surface and/or body engagement surface are positioned such that one or both of the diamond engagement surface and/or body engagement surface will engage with the opposing engagement surface prior to direct, surface-to-surface engagement between the two tubulars.
  • Engagement interface 10 may provide protection at the interface of two different tubulars that are movably (e.g., slidingly and/or rotatably) engaged with one another.
  • engagement interface 10 is a drill pipe protector.
  • engagement interface 10 is a sucker rod guide. While shown and described herein as a drill pipe protector and a sucker rod guide, the engagement interface disclosed herein is not limited to being a drill pipe protector or a sucker rod guide, and may be another structure that is capable of being coupled with a tubular and interfacing movable engagement between that tubular and another tubular.
  • the engagement interface is integral with the tubular.
  • the engagement interface is static relative to one tubular (i.e., the tubular to which the engagement interface is coupled), and is movable relative to the other tubular (i.e., is movably engaged with the other tubular).
  • Certain embodiments include tubular assemblies that include the engagement interfaces disclosed herein positioned to interface the engagement between the tubulars of the tubular assemblies.
  • a first tubular and a second tubular are shown.
  • the first and second tubulars may be, for example and without limitation, piping, casing, rods, tubing, downhole tools, or other tubulars.
  • Tubular 30 is a hollow tubular having inner wall 32 defining cavity 34 therethrough, such as a pipe or other conduit.
  • Tubular 30 has outer wall 36.
  • Tubular 30 has an outer diameter 38 defined by outer wall 36, and an inner diameter 31 defined by inner wall 32.
  • tubular 40 is a hollow tubular, such as a pipe or other conduit, having inner wall 42 defining cavity 44 therethrough.
  • tubular 40 is a solid tubular, such as rod, without a cavity or conduit defined therethrough.
  • Tubular 40 has an outer wall 46, defining outer diameter 48 of tubular 40.
  • Outer diameter 48 of tubular 40 and inner diameter 31 of tubular 30 are sized such that tubular 40 may be coupled or engaged at least partially within cavity 34 of tubular 30, as shown in FIG. 2E. That is, tubular 30 is a relatively larger diameter tubular, and tubular 40 is a relatively smaller diameter tubular, such that outer diameter 48 of tubular 40 is smaller than inner diameter 31 of tubular 30.
  • tubular assemblies 100a and 100b each include tubulars 30 and 40, which are movably engaged with one another.
  • Tubular 40 is slidingly engaged within tubular 30 such that one or both of tubulars 30 and 40 are movable along one or both directions 50 and 52.
  • slidingly engaged refers to an engagement between at least two tubulars that allows at least one of the tubulars to slide relative to the other of the tubulars.
  • tubular 40 may slide within tubular 30 along one or both directions 50 and 52
  • tubular 30 may slide about tubular 40 along one or both directions 50 and 52, or combinations thereof.
  • Tubular 40 is rotatably engaged within tubular 30 such that one or both of tubulars 30 and 40 are rotatable in one or both directions 54 and 56 (as shown in FIG. 2B).
  • “rotatably engaged” refers to an engagement between at least two tubulars that allows at least one of the tubulars to rotate relative to the other of the tubulars.
  • tubular 40 may rotate within tubular 30 along one or both directions 54 and 56
  • tubular 30 may rotate about tubular 40 along one or both directions 54 and 56, or combinations thereof.
  • tubular 40 is movably engaged within tubular 30 such that one or both of tubulars 30 and 40 are movable relative to the other tubular.
  • movably engaged in reference to engaged tubulars, refers to an engagement between at least two tubulars that allows at least one of the tubulars to move relative to the other of the tubulars.
  • tubular 40 may move (e.g., slide and/or rotate) relative to tubular 30, tubular 30 may move relative to tubular 40, or combinations thereof.
  • Engagement interfaces 10 may be positioned on and coupled with the larger diameter tubular for interfacing engagement thereof with the smaller diameter tubular, or engagement interfaces 10 may be positioned on and coupled with the smaller diameter tubular for interfacing engagement thereof with the larger diameter tubular.
  • engagement interfaces 10 are positioned on and coupled with tubular 30, and engaged with opposing engagement surface of tubular 40, i.e., outer wall 46.
  • FIG. 2F engagement interfaces 10 are positioned on and coupled with tubular 40, and engaged with opposing engagement surface of tubular 30, i.e., inner wall 32.
  • opposite tubular refers to a tubular that is movably engaged with a different tubular, where the different tubular has at least one of the engagement interfaces coupled thereon to interface engagement with the opposing tubular.
  • Bodies 12a- 12c of engagement interfaces 10a- 10c which each may be the body of, part of, attached to, or integral with a drill pipe protector or sucker rod guide, are depicted with three differently mounted polycrystalline diamond elements 14a, 14b, and 14c, as shown in FIGS. 3A, 3B and 3C, respectively.
  • Polycrystalline diamond element 14a is exemplary of an “underexposed” polycrystalline diamond element, such that the polycrystalline diamond element is positioned below plane 24a defined by body engagement surface 16a.
  • polycrystalline diamond element 14a will engage with another tubular after the body engagement surface 16a is worn down sufficiently to expose the diamond engagement surface 18a of the polycrystalline diamond element 14a, as shown in FIG. 3D, which depicts engagement interface 10a after the occurrence of wear, depicted in FIG. 3D as 60.
  • diamond engagement surface 18a is positioned within plane 23a and body engagement surface 16a is positioned within 24a, which is above plane 23a and, in operation, in closer proximity to an opposing tubular surface.
  • body 12a is worn down to a degree that plane 24a is coplanar with plane 23a; or such that plane 24a is below plane 23a and, in operation, plane 23a is in equal or closer proximity to an opposing tubular surface.
  • Polycrystalline diamond element 14b is exemplary of a “flush” mounted polycrystalline diamond element, such that diamond engagement surface 18b resides in plane 24b defined by body engagement surface 16b of body 12b. That is, the plane defined by diamond engagement surface 18b, plane 23b, is coplanar with the plane defined by body engagement surface 16b, plane 24b.
  • polycrystalline diamond element 14b will engage with an opposing tubular simultaneously with the engagement between body engagement surface 16b and the opposing tubular.
  • Polycrystalline diamond element 14c is exemplary of an “exposed” polycrystalline diamond element, such that the polycrystalline diamond element is positioned above plane 24c defined by body engagement surface 16c of body 12c, and within plane 23c. Thus, in operation, polycrystalline diamond element 14c will engage with an opposing tubular prior to engagement between body engagement surface 16c and the opposing tubular.
  • the polycrystalline diamond elements disclosed herein provide “back-up wear resistance capability” to the associated engagement interface.
  • back-up wear resistance capability refers to the arrangement of the polycrystalline diamond elements relative to the body such that, the diamond engagement surfaces engage with an opposing tubular only after sufficient wear of the body has occurred (e.g.
  • the polycrystalline diamond elements disclosed herein provide “concurrent wear resistance capability” to the associated engagement interface.
  • “concurrent wear resistance capability” refers to the arrangement of the polycrystalline diamond elements relative to the body such that, the diamond engagement surfaces engage with an opposing tubular upon engagement between the body and the opposing tubular, without requiring the occurrence of wear prior to engagement between the diamond engagement surfaces and the opposing tubular (e.g., as shown in FIG. 3B).
  • the polycrystalline diamond elements disclosed herein provide “primary wear resistance capability” to the associated engagement interface.
  • primary wear resistance capability refers to the arrangement of the polycrystalline diamond elements relative to the body such that, the diamond engagement surfaces engage with an opposing tubular prior to engagement between the body and the opposing tubular, and without requiring the occurrence of wear prior to engagement between the diamond engagement surfaces and the opposing tubular (e.g., as shown in FIG. 3C).
  • polycrystalline diamond elements 14a, 14b, and 14c provide primary, concurrent, and back-up wear resistance capability to protectors for drill pipe or sucker rods, respectively.
  • the engagement interfaces disclosed herein are not limited to including only one of exposed (FIGS. 1A and 3C), flush (FG. 1B and 3B, or recess (FIGS. 1C and 3 A) mounted polycrystalline diamond elements, but may include any combination thereof.
  • polycrystalline diamond elements 14a-14c may be positioned in or coupled with or within sockets or cavities 62a-62c within bodies 12a- 12c, respectively. Also, each polycrystalline diamond element 14a- 14c includes support 15a- 15c, respectively, and diamond layer 17a-17c, respectively. Diamond layers 17a-17c may be coupled with supports 15a-15c, and supports 15a-15c may be coupled with bodies 12a-12c, respectively. For example, diamond layers 17a- 17c may be or include thermally stable polycrystalline diamond or PDC, and supports may be or include tungsten carbide.
  • the engagement interfaces disclosed herein include a plurality of polycrystalline diamond elements (e.g.., PDCs), and each of the polycrystalline diamond elements is discrete from the other of the plurality of polycrystalline diamond elements.
  • PDCs polycrystalline diamond elements
  • the engagement interfaces disclosed herein are provided on a sucker rod guide, such as for interfacing the engagement between a sucker rod string movably positioned within production tubing.
  • tubular 40 may be a sucker rod with engagement interfaces 10 forming at least a portion of a sucker rod guide thereon
  • tubular 30 may be a production tubing within which the sucker rod is positioned.
  • a sucker rod is a rod (e.g. , a steel rod) that is used to make up the mechanical assembly between the surface and downhole components of a rod pumping system.
  • Sucker rods may be from 20 to 40 feet, or from 24 to 35 feet, or from 25 to 30 feet in length, and may be threaded at each end to enable the downhole components to be run and retrieved easily.
  • sucker rods may be other lengths, depending on the particular application.
  • sucker rod assembly 101a is depicted, including sucker rod 102 with sucker rod guide 104.
  • Sucker rod 102 is engaged with sucker rod guide 104.
  • at least some portions of sucker rod guide 104 are molded directly onto sucker rod 102.
  • body 12 of sucker rod guide 104 may be or include a moldable material (e.g, a polymer), such as molded rubber, nylon, polyurethane, synthetic polyamide, polyether ether ketone (PEEK), or another plastic or elastomer.
  • a moldable material e.g, a polymer
  • PEEK polyether ether ketone
  • Such materials may be molded onto sucker rod 102 via any of various polymer molding techniques, such as extrusion molding.
  • Sucker rod 102 may be or include a metal rod, such as a steel rod.
  • sucker rod guide 104 is coupled with sucker rod 102.
  • sucker rod guide 104 is static, relative to sucker rod 102.
  • Body 12 of sucker rod guide 104 includes base 13 circumferentially surrounding sucker rod 102.
  • Body 12 also includes protrusions 110 extending outward from base 13, away from sucker rod 102.
  • protrusions 110 are in the form of peaks, blades, ribs, fins, or vanes extending outward from sucker rod 102.
  • Protrusions 110 are spaced radially about base 13 and sucker rod 102, such that cavities or valleys 111 are positioned between adjacent protrusions 110.
  • Each protrusion 110 defines a body engagement surface 16 for engagement with, for example, production tubing to protect and/or guide sucker rod 102 during operation thereof.
  • At least one polycrystalline diamond element is coupled with the sucker rod guides disclosed herein.
  • sucker rod guide 104 includes four protrusions 110, each with two polycrystalline diamond elements 14 thereon.
  • the sucker rod guides disclosed herein are not limited to having this number of protrusions or polycrystalline diamond elements, and may include any number of polycrystalline diamond elements arranged in any of various arrangements.
  • Each polycrystalline diamond element 14 may be embedded within body engagement surface 16 or otherwise attached to sucker rod guide 104, such that polycrystalline diamond elements 14 are positioned to protect and guide the engagement between sucker rod 102 and, for example, production tubing. As shown, polycrystalline diamond elements 14 have convex engagement surfaces 18 for engagement with production tubing and are in the form of inserts that are inserted into sucker rod guide 104. However, the polycrystalline diamond elements disclosed herein are not limited to this particular arrangement, shape, or number.
  • FIG. 4D depicts tubular assembly 103, including sucker rod 102 and sucker rod guide 104, engaged within production tubing 109. As shown, diamond engagement surfaces 18 interface engagement between sucker rod 102 and inner surface o of production tubing 109.
  • FIG. 5 depicts another embodiment of a sucker rod assembly 101b, including sucker rod 102 and sucker rod guide 104, with like reference numerals indicating like elements.
  • Sucker rod 102 is engaged with sucker rod guide 104, which includes protrusions 110, each having convex polycrystalline diamond elements 14 inserted therein.
  • the difference between FIGS. 4A-4D and FIG. 5 is in the form, shape, arrangement, and positioning of sucker rod guide 104.
  • the tubular engagement interface disclosed herein, including body 12 and polycrystalline diamond elements 14 are in the form of, or form a portion of, a sucker rod guide.
  • the sucker rod guide disclosed herein is a sucker rod guide the same or similar as described in Figures 1-6 of U.S. Patent No. 6,152,223, with the addition of the polycrystalline diamond elements described herein.
  • the engagement interfaces disclosed herein are provided on a pipe protector of a pipe (e.g., a drill pipe), such as for interfacing the engagement between a drill pipe and casing during drilling operations where the drill pipe is movably positioned within the casing.
  • a pipe protector of a pipe e.g., a drill pipe
  • tubular 40 may be a drill pipe with engagement interfaces 10 forming at least a portion of a pipe protector thereon
  • tubular 30 may be casing within which the drill pipe is positioned.
  • FIGS. 6 and 8 one drill pipe protector in accordance with the present disclosure will be described.
  • the drill pipe protector disclosed is in accordance with the pipe protector shown and described in U.S. Patent No. 5,833,019, such as in Figures 1, 2 and 4 of U.S. Patent No. 5,833,019, with the addition of the polycrystalline diamond elements disclosed herein incorporated into the pipe protector.
  • Drill pipe protector 820 includes body 822, also referred to as a sleeve, which defines a portion of the wear surface or body engagement surface 16. Embedded within body 822 is frame 200, forming cage 222, as shown in FIG. 6. Also, inner frame 221 may be embedded within body 822. Polycrystalline diamond elements 14 may be coupled with frame 222, such that polycrystalline diamond elements 14 are also embedded at least partially within body 822. Polycrystalline diamond elements 14 may be embedded within body such that engagement surface 18 is flush with body engagement surface 16, is recessed relative to body engagement surface 16, or extends above body engagement surface 16.
  • frame 200 includes frame body 224 and protrusions 226. Protrusions 226 extend outward from flame body 224. Attached to, embedded within, inserted within, or otherwise coupled with protrusions 226 are polycrystalline diamond elements 14, which are positioned to engage with, for example, casing during drilling operations.
  • Frame 200 includes cavity 228, which is at least partially defined by frame body 224.
  • a cross-sectional view of drill pipe protector 820 frame 200 is embedded within body 822.
  • Polycrystalline diamond elements 14 are positioned to engage with, for example, casing during drilling operations.
  • Drill pipe may be positioned within opening 828, such that body 822 and drill pipe protector frame 200 are positioned about drill pipe, and between drill pipe and casing.
  • drill pipe protector 820 may be arranged about a drill pipe in the same or substantially the same way as drill pipe protector 722, as shown in FIGS. 7A-7C.
  • FIG. 7A depicts a side view of tubular assembly 701, including drill pipe 700 with drill pipe protector 722 coupled thereabout, including polycrystalline diamond elements 14.
  • FIG. 7B depicts atop view of drill pipe 700 and drill pipe protector 722, showing cavity 702 of drill pipe 700 defined by inner surface 704 of drill pipe 700, and drill pipe protector 722 coupled about outer surface 706 of drill pipe 700.
  • FIG. 7C depicts atop view of assembly 703, including tubular assembly 701 positioned within casing 790. As shown, drill pipe 700 and drill pipe protector 722 are positioned within cavity 794 of casing 790. Polycrystalline diamond elements 14 interface any engagement that may occur between drill pipe 700 and innerwall 791 of casing 790 during operation. [0081] With reference to FIG.
  • drill pipe protector 920 is depicted, including drill pipe protector body 922, which may be formed of any material, such as molded rubber, nylon, plastic, polymer, polyurethane, synthetic polyamide, or polyether ether ketone (PEEK).
  • Drill pipe protector body 922 includes base 924 and protrusions 926, which extend outward from base 924. Attached to, embedded within, or inserted within protrusions 926 are polycrystalline diamond elements 14 positioned to engage with, for example, casing during drilling operations. Drill pipe may be positioned within opening 928, such that drill pipe protector body 922 is positioned about drill pipe, and between drill pipe and casing.
  • Drill pipe protector 920 in FIG. 9 is a wedgelift drill pipe-protector.
  • drill pipe protector 920 may be coupled to drill pipe via latch pins, such that the drill pipe is positioned within opening 928.
  • Drill pipe protector 920 is slidingly engageable with drill pipe, such that drill pipe protector 920 is movable axially along the length of the drill pipe during operation of the drill pipe.
  • the drill pipe rotates within and relative to drill pipe protector 920.
  • Protrusions 926 of drill pipe protector 920 extend outward, away from the drill pipe, by a distance that is sufficient to prevent the drill bit, bottom hole assembly, and other components of the drill string from engaging with the casing.
  • protrusions 926 extend outward, away from the drill pipe, such that protrusions 926 and/or polycrystalline diamond elements 14 thereon engage with the casing while keeping the drill bit, bottom hole assembly, and other components of the drill string spaced apart from the casing.
  • the drill pipe couples with a downhole tool, such as a drill bit
  • the drill pipe typically includes threading therein to couple with the tool.
  • the portion of the drill pipe that includes the threading is typically thicker than other portions of the drill pipe to compensate for the loss of metal due to the presence of threading.
  • the drill pipe has a larger outer diameter as a result of the additional thickness.
  • the protrusions 926 extend outward and away from the drill pipe by a distance that is sufficient to prevent the upset of the drill pipe from engaging with the casing.
  • the drill pipe protectors disclosed herein contact the internal diameter of a well (e.g., the casing) when the drill pipe deflects off center in the casing or wellbore to protect the casing or wellbore from contact with the drill pipe or portions thereof during rotation of the drill pipe .
  • the drill pipe protector disclosed herein is a pipe protector in accordance with Figure 7 of U.S. Patent No. 6,378,633, with the addition of the polycrystalline diamond elements disclosed herein.
  • the technology of the present application preferably employs convex polycrystalline diamond elements, preferably polished polycrystalline diamond compact (PDC) elements, to provide primary, concurrent, or back-up wear resistance capability to protectors for drill pipe or sucker rods.
  • the polycrystalline diamond elements of the present technology may alternatively be planar with radiused or highly radiused edges.
  • the polycrystalline diamond elements of the current application may be, for example, thermally stable polycrystalline diamond or PDC.
  • the polycrystalline diamond elements are backed (e.g., supported) or unbacked (e.g., unsupported), such as by tungsten carbide.
  • the polycrystalline diamond elements disclosed herein maybe non-leached, leached, leached and backfilled, or coated (e.g., via CVD) all by methods known in the art.
  • the polycrystalline diamond elements disclosed herein may have diameters as small as 3 mm (about 1/8”) or as large as 75mm (about 3”), for example, depending on the application and the configuration and diameter of the engaged surface. Some of the polycrystalline diamond elements disclosed herein will have diameters of from 8 mm (about 5/16”) to 25mm (about 1”). One skilled in the art would understand that the polycrystalline diamond elements are not limited to these particular dimensions and may vary in size and shape depending on the particular application.
  • the polycrystalline diamond elements disclosed herein have increased cobalt content transitions layers between the outer polycrystalline diamond surface and a supporting tungsten carbide slug.
  • the polycrystalline diamond elements disclosed herein may be unsupported by tungsten carbide and may be substantially “standalone”, discrete polycrystalline diamond bodies that are directly mounted (e.g., onto tubular member).
  • the polycrystalline diamond elements may be mounted in a manner to allow the polycrystalline diamond elements to rotate about its own axis.
  • U.S. Patent No. 8,881,849, to Shen et. al. as anon-limiting example of methods to provide for a polycrystalline diamond element that spins about its own axis while in facial contact with a diamond reactive material.
  • the polycrystalline diamond elements are most commonly available in cylindrical shapes, it is understood that the technology of the application may be practiced with polycrystalline diamond elements that are square, rectangular, oval, any of the shapes described herein with reference to the Figures, or any other appropriate shape known in the art.
  • the polycrystalline diamond elements are subjected to edge radius treatment.
  • edge radius treatment In some embodiments of the technology of this application that employ planar or concave polycrystalline diamond elements, it is preferred to employ edge radius treatment of such polycrystalline diamond elements.
  • One purpose of employing an edge radius treatment is to reduce or avoid potential for outer edge cutting or scribing at the outer limits of the linear engagement area of a given polycrystalline diamond element with the opposing tubular (e.g.. , a curved surface).
  • the polycrystalline diamond elements of the present application may be deployed in a manner that preferably precludes any edge or sharp contact between the polycrystalline diamond elements and ferrous materials with which they are slidingly engaged (e.g., ferrous casing or production tubing).
  • the preclusion of edge contact can overcome the potential for machining of the ferrous material and chemical interaction between the diamond and ferrous material.
  • the polycrystalline diamond elements of the present application may be mounted on a metal frame and over-molded by a thermoplastic material, or other common materials used for protectors.
  • the polycrystalline elements of the present application may be underexposed, flush mounted, or exposed relative to the protector or guide body.
  • the polycrystalline diamond elements of the present application may be molded directly into protector materials and retained therein. Such molding may occur directly onto the parent tubular or may occur separate flora the parent tubular and then the molded parts may be attached in a separate step. Alternatively, sockets may be molded into the thermoplastic or alternative body material and the polycrystalline diamond elements may then be mounted afterwards using gluing, or threading or other methods as known in the art. In some embodiments, the polycrystalline diamond elements may be mounted on couplings of a sucker rod assembly.
  • the polycrystalline diamond elements of the current application may be attached to a metal frame that is not over molded but, rather, acts as the primary frame with the polycrystalline diamond elements providing substantially all of the wear resistance and stand-off distance of the protector.
  • the polycrystalline diamond elements of tire current technology may be mounted in subassemblies that allow for the polycrystalline diamond elements to rotate about their own axis, as is known in the art.
  • the polycrystalline diamond elements of tire current technology may be recovered from used protectors or guides and reused in freshly molded or deployed protectors or guides.
  • the ability to recover and reuse the polycrystalline diamond elements reduces the ultimate cost of the use of the technology.
  • the polycrystalline diamond element, or at least the engagement surface thereof is lapped or polished, optionally highly lapped or highly polished.
  • a surface is defined as “highly lapped” if the surface has a surface finish (Ra) of 20 ⁇ in Ra or about 20 ⁇ in Ra, such as a surface finish (Ra) ranging from about 18 to about 22 ⁇ in Ra.
  • a surface is defined as “polished” if the surface has a surface finish (Ra) of less than about 10 ⁇ in Ra, or of from about 2 to about 10 ⁇ in Ra.
  • a surface is defined as “highly polished” if the surface has a surface finish (Ra) of less than about 2 ⁇ in Ra, or from about 0.5 ⁇ in Ra to less than about 2 ⁇ in Ra.
  • the engagement surface has a surface finish (Ra) ranging from 0.5 ⁇ in Ra to 40 ⁇ in Ra, or from 2 ⁇ in Ra to 30 ⁇ in Ra, or from 5 ⁇ in Rato 20 ⁇ in Ra, or from 8 ⁇ in Rato 15 ⁇ in Ra, or less than or equal to 32 ⁇ in Ra, or less than 20 ⁇ in Ra, or less than 10 ⁇ in Ra, or less than 2 ⁇ in Ra, or any range therebetween.
  • Polyciystalline diamond that has been polished to a surface finish (Ra) of 0.5 ⁇ in Ra has a coefficient of friction that is about half of standard lapped polyciystalline diamond with a surface finish of 20-40 ⁇ in Ra.
  • Ra surface finish
  • U.S. Patent Nos. 5,447,208 and 5,653,300 to Lund et al. provide disclosure relevant to polishing of polyciystalline diamond.
  • surface finish may be measured with a profilometer or with Atomic Force Microscopy. Surface finish may be determined in accordance with ASME B46.1-2009.
  • the opposing tubular, or at least the surface thereof is or includes a diamond reactive material.
  • a “diamond reactive material” is a material that contains more than trace amounts of diamond solvent-catalyst.
  • a diamond reactive material that contains more than “trace amounts” of diamond solvent-catalyst contains at least 2 percent by weight (wt.%) diamond solvent-catalyst based on a total weight of the diamond reactive material.
  • the diamond reactive materials disclosed herein contain from 2 to 100 wt.%, or from 5 to 95 wt.%, or from 10 to 90 wt.%, or from 15 to 85 wt.%, or from 20 to 80 wt.%, or from 25 to 75 wt.%, or from 25 to 70 wt.%, or from 30 to 65 wt.%, or from 35 to 60 wt.%, or from 40 to 55 wt.%, or from 45 to 50 wt.% of diamond solvent-catalyst based on a total weight of the diamond reactive material.
  • diamond solvent-catalysts also referred to as “diamond catalyst,” “diamond solvent,” “diamond catalyst-solvent,” “catalyst-solvent,” or “solvent-catalyst” are disclosed in: U.S. Patent No. 6,655,845; U.S. Patent No. 3,745,623; U.S. Patent No. 7,198,043; U.S. Patent No. 8,627,904; U.S. Patent No. 5,385,715; U.S. Patent No. 8,485,284; U.S. Patent No. 6,814,775; U.S. Patent No. 5,271,749; U.S. Patent No. 5,948,541; U.S.
  • diamond solvent-catalysts are chemical elements, compounds, or materials (e.g., metals) that are capable of reacting with polycrystalline diamond (e.g. , catalyzing and/or solubilizing), resulting in the graphitization of the polycrystalline diamond, such as under load and at a temperature at or exceeding the graphitization temperature of diamond (f.e., about 700 °C).
  • diamond reactive materials include materials that, under load and at a temperature at or exceeding the graphitization temperature of diamond, can lead to wear, sometimes rapid wear, and failure of components formed of polycrystalline diamond, such as diamond tipped tools.
  • Diamond solvent-catalysts include, but are not limited to, iron, cobalt, nickel, ruthenium, rhodium, palladium, chromium, manganese, copper, titanium, and tantalum.
  • Diamond reactive materials include, but are not limited to, metals, metal alloys, and composite materials that contain more than trace amounts of diamond solvent-catalyst.
  • the diamond reactive materials are in the form of hard facings, coatings, or platings.
  • the diamond reactive material may contain ferrous, cobalt, nickel, ruthenium, rhodium, palladium, chromium, manganese, copper, titanium, tantalum, or alloys thereof.
  • the diamond reactive material is a steel or cast iron.
  • the diamond reactive material is a superalloy including, but not limited to, iron-based, cobalt-based and nickel-based superalloys.
  • the opposing engagement surface (i. e. , the surface in opposing engagement with the polycrystalline diamond engagement surface) is a metal surface.
  • a metal surface is a surface of a material that is primarily metal, by weight percent.
  • the opposing engagement surface contains from 2 to 100 wt.%, or from 5 to 95 wt.%, or from 10 to 90 wt.%, or from 15 to 85 wt.%, or from 20 to 80 wt.%, or from 25 to 75 wt.%, or from 25 to 70 wt.%, or from 30 to 65 wt.%, or from 35 to 60 wt.%, or from 40 to 55 wt.%, or from 45 to 50 wt.% of diamond solvent-catalyst based on a total weight of the material of the opposing engagement surface.
  • the opposing engagement surface contains from 2 to 100 wt.%, or from 5 to 95 wt.%, or from 10 to 90 wt.%, or from 15 to 85 wt.%, or from 20 to 80 wt.%, or from 25 to 75 wt.%, or from 25 to 70 wt.%, or from 30 to 65 wt.%, or from 35 to 60 wt.%, or from 40 to 55 wt.%, or from 45 to 50 wt.% of iron, cobalt, nickel, ruthenium, rhodium, palladium, chromium, manganese, copper, titanium, or tantalum.
  • the opposing engagement surface contains at least 50 wt.%, at least 55 wt.%, at least 60 wt.%, at least 65 wt.%, at least 70 wt.%, at least 75 wt.%, at least 80 wt.%, at least 85 wt.%, at least 90 wt.%, at least 95 wt.%, or 100 wt.% of a metal, where the metal is a diamond reactive material.
  • the opposing tubular, or at least the surface thereof is not and/or does not include (i.e. , specifically excludes) so called “‘superhard materials.”
  • “superhard materials” are a category of materials defined by the hardness of the material, which may be determined in accordance with the Brinell, Rockwell, Knoop and/or Vickers scales. For example, superhard materials include materials with a hardness value exceeding 40 gigapascals (GPa) when measured by the Vickers hardness test.
  • superhard materials include materials that are at least as hard as tungsten carbide tiles and/or cemented tungsten carbide, such as is determined in accordance with one of these hardness scales, such as the Brinell scale.
  • a Brinell scale test may be performed, for example, in accordance with ASTM E10-14; the Vickers hardness test may be performed, for example, in accordance with ASTM E384; the Rockwell hardness test may be performed, for example, in accordance with ASTM E18; and tire Knoop hardness test may be performed, for example, in accordance with ASTM E384.
  • the “superhard materials” disclosed herein include, but are not limited to, tungsten carbide (e.g., tile or cemented), infiltrated tungsten carbide matrix, silicon carbide, silicon nitride, cubic boron nitride, and polycrystalline diamond.
  • the opposing tubular is partially or entirely composed of material(s) (e.g., metal, metal alloy, composite) that is softer (less hard) than superhard materials, such as less hard than tungsten carbide (e.g., tile or cemented), as determined in accordance with one of these hardness tests, such as the Brinell scale.
  • hardness may be determined using the Brinell scale, such as in accordance with ASTM E10-14.
  • a “superalloy” is a high-strength alloy that can withstand high temperatures.
  • the opposing tubular, or at least the surface thereof, is not and/or does not include (i.e.., specifically excludes) diamond.
  • Some examples of surfaces disclosed herein that may be or include diamond reactive material are: inner wall 32 shown in FIGS. 2A, 2B, 2E and 2F; outer wall 36 shown in FIGS. 2A and 2B; outer wall 46 shown in FIGS. 2C-2F; inner wall 42 shown in FIG. 2C; inner surface 107 shown in FIG. 4D; outer surface 706 shown in FIGS. 7A and 7B; inner wall 791 shown in FIG. 7C; opposing engagement surface 1121 shown in FIGS. 12 and 13; and internal wall shown in FIG. 15.
  • the engagement interfaces disclosed herein are provided on the couplings of a tubular, such as a rod (e.g. , a sucker rod), rather than or in addition to being on a guide of the tubular (e.g. , rod) .
  • sucker rod couplers are or include the engagement interfaces.
  • the engagement interfaces on the couplings can interface the engagement between a sucker rod string movably positioned within production tubing.
  • a sucker rod is a rod (e.g. , a steel rod) that is used to make up the mechanical assembly between the surface and downhole components of a rod pumping system.
  • a sucker rod string or assembly may include a plurality of sucker rods coupled together.
  • the plurality of sucker rods are threadably coupled together.
  • a rod coupler may be coupled with a first sucker rod and with a second sucker rod such that the first and second sucker rods are coupled together via the rod coupler.
  • Exemplary sucker rods may be from 20 to 40 feet, or from 24 to 35 feet, or from 25 to 30 feet in length, and may be threaded at each end to enable coupling with the rod coupler.
  • FIG. 10 depicts sucker rod 1002.
  • Sucker rod 1002 includes rod body 1004.
  • Rod body 1004 may be a metal body, such as steel.
  • Rod body 1004 has first end 1006 and second end 1008.
  • sucker rod 1002 includes a threaded end 1010a and 1010b. Threaded ends 1010a and 1010b allow for sucker rod 1002 to be threadably coupled with other components, such as other sucker rods. While shown as including threaded ends, the sucker rods disclosed herein are not limited to threaded couplings.
  • threaded ends 1010a and 1010b are shown as male threads, some embodiments of the sucker rods disclosed herein include female threads.
  • FIG. 11 depicts sucker rod coupler 1102.
  • Sucker rod coupler 1102 includes coupler body 1104. Coupler body 1104 may be a metal body, such as steel.
  • Sucker rod coupler 1102 includes threading 1110a and 1110b formed on an internal diameter of coupler body 1104 at each end 1106 and 1108 of coupler body 1104. Threading 1110a and 1110b allows sucker rod coupler 1102 to be threadably coupled with two different sucker rods such that sucker rod coupler 1102 couples the two different sucker rods together. That is, threading on a first sucker rod can be threadably coupled with threading 1110a, and threading on a second sucker rod can be threadably coupled with threading 1110b.
  • sucker rods 1002 the same as shown in FIG. 10 can threadably coupled with sucker rod coupler 1102.
  • sucker rod coupler 1102. the sucker rod in FIG. 10 and the sucker rod coupler in FIG. 11 are not drawn to scale relative to one another. While shown as including threaded ends, the sucker rod couplers disclosed herein are not limited to threaded couplings. While threading 1110a and 1110b are shown as female threads, some embodiments of the sucker rod couplers disclosed herein include male threads.
  • Sucker rod coupler 1102 includes a plurality of polycrystalline diamond elements 1114 on coupler body 1104.
  • the polycrystalline diamond elements 1114 may be the same or similar to those described throughout this disclosure, including those described with reference to FIGS. 1 A-9.
  • polycrystalline diamond elements 1114 include polycrystalline diamonds 1116 supported on supports 1118 (e.g.., tungsten carbide supports).
  • supports 1118 e.g.., tungsten carbide supports.
  • the sucker rod couplers disclosed herein are not limited to including polycrystalline diamond elements that are supported on supports, and may include unsupported polycrystalline diamond elements.
  • Each polycrystalline diamond 1116 has an engagement surface 1120.
  • the engagement surfaces 1120 are dome shaped, curved, or otherwise contoured.
  • the engagement surfaces 1120 can be convex.
  • the engagement surfaces 1120 have a curvature that matches or is less than the curvature of coupler body 1104.
  • the exterior surface of coupler body 1104 is shown as having a curvature.
  • Engagement surfaces 1120 can have this same surface curvature as coupler body 1104.
  • engagement surfaces 1120 have a surface curvature that is less than the surface curvature of coupler body 1104.
  • engagement surfaces 1120 are flush with the exterior surface of coupler body 1104.
  • engagement surfeces 1120 are raised above the exterior surface of coupler body 1104 (as shown).
  • engagement surfaces 1120 are recessed below the exterior surface of coupler body 1104. As shown in FIG.
  • coupler body 1104 (as well as the sucker rods to which it is attached) can be hollow, including a cavity 1107 that defines a flow path for fluids therethrough.
  • the sucker rod coupler 1102 and the sucker rods to which it is attached (not show) is positioned within production tubing 1111.
  • the sucker rod string i.e., a plurality of threadably coupled sucker rods and sucker rod couplers
  • the engagement surfaces 1120 will interface that engagement. That is, engagement surfaces 1120 will engage with the opposing engagement surfaces 1121 of production tubing (i.e. , the internal diameter of the production tubing) .
  • the engagement surfaces 1120 will prevent, or at least reduce, the occurrence of the outer surface of the sucker rod body or the outer surface of the sucker rod coupler body from engaging with the production tubing 1111. As such, wear on the outer surface of the sucker rod body or the outer surface of the sucker rod coupler body as a result of engagement with the production tubing is prevented or reduced. Correspondingly, wear on the inner surface of the production tubing is prevented or reduced.
  • FIG. 13 depicts a sucker rod string 1300, including two sucker rods 1002a and 1002b each threadably engaged with a sucker rod coupler 1102.
  • Sucker rod string 1300 is positioned within production tubing 1111.
  • Engagement surfaces 1120 are raised above the exterior surface of sucker rod coupler body 1104 and sucker rod bodies 1004a and 1004b, such that engagement surfaces 1120 are positioned and arranged to interface any engagement between sucker rod string 1300 and production tubing 1111.
  • the opposing engagement surface 1121 is a diamond reactive material, such as steel.
  • FIG. 14 depicts the sucker rod string 1300 in isolation from the production tubing.
  • sucker rod strings typically include more than two individual segments of sucker rods and more than one sucker rod coupler
  • FIGS. 13 and 14 is simplified and for tire purpose of explaining the coupling between two adjacent segments of sucker rod.
  • the embodiments shown in FIGS. 10-14 show that polycrystalline diamond elements can be mounted directly onto the sucker rod couplers.
  • the concepts described with respect to FIGS. 10-14 can be combined with those described herein in reference to FIGS. 1A-5 where sucker rod guides are provided with polycrystalline diamond elements that act as engagement interfaces.
  • the addition of sucker rod guides to sucker rod strings stiffens the sucker rod strings, complementing the protection provided to the string by the PDCs on sucker rod couplers.
  • the sucker rod guides may also include PDCs thereon, or may lack PDCs.
  • the guides may be of a smaller diameter than traditional rod guides.
  • the sucker rod string with polycrystalline diamond elements on the sucker rod couplers lacks additional sucker rod guides, as the sucker rod couplers themselves provide the dual function of sucker rod couplers and sucker rod guides (rod centralizers).
  • the tubulars disclosed herein include joints for coupling with other components, such as with other tubulars or with tools (e.g., a tool joint).
  • FIG. 15A depicts a tubular having a joint with polycrystalline diamond elements positioned on the joint.
  • tubular 1502 which may be a drill pipe
  • tubing 3111 which may be casing in a wellbore.
  • Tubing 3111 has an internal wall 3121.
  • Tubular 1502 includes body 1504, which expands at body section 1506 to a larger diameter joint section 1508.
  • Joint section 1508 includes threading 1511 on an internal diameter thereof, which allowed tubular 1502 to be coupled with tools, other tubulars, or other components. As shown, joint section 1508 is coupled with tool 1510 (only a portion of which is depicted).
  • Tool 1510 may be, for example, a drill bit.
  • a plurality of polycrystalline diamond elements 1114 are positioned on joint section 1508, such that engagement surfaces 1120 interface engagement between tubular 1502 and opposing engagement surface 1321.
  • FIG. 15B depicts the tubular 1502 of FIG. 15A, but at an angle within tubing 3111. With tubular 1502 positioned at an angle within tubing 3111, at least some of the engagement surfaces 1120 are in engagement with internal wall 3121 of tubing 3111. Thus, the engagement surfaces 1120 of the plurality of polycrystalline diamond elements 1114 engage with tubing 3111 rather than other portions of tubular 1502.
  • the engagement surfaces of a sucker rod string e.g., sucker rod string 1300 shown in FIG. 13
  • function in substantially the same manner such that the engagement surfaces of the plurality of polycrystalline diamond elements thereon will engage with the production tubing rather than other portions of the sucker rod string when the sucker rod string is at an angle within the production tubing.
  • the PDC elements disclosed herein are positioned on a tool joint.
  • the tool joint may be at one end of a drill pipe, for example, that includes threads and has a larger outer diameter (OD) than a remainder of the drill pipe.
  • tubulars with such tool joints e.g., joint section 1508 do not have couplers, such as those shown in FIGS. 10-14, because the tool joint for coupling with other components is integral with the tubular.
  • some embodiments provide for the positioning of PDC elements on and/or around such tool joints.

Landscapes

  • Engineering & Computer Science (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Mechanical Engineering (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Earth Drilling (AREA)

Abstract

La présente divulgation comprend des trains de tige de pompage, des protecteurs de tube et des raccords de tige sur lesquels sont positionnés des éléments de diamant polycristallin pour assurer une interface de mise en prise avec d'autres surfaces dans des applications de fond de trou. Les éléments de diamant polycristallin peuvent être positionnés sur des guides de tige de pompage, des coupleurs de tige de pompage, des protecteurs de tube et des raccords de tige.
PCT/US2021/048247 2020-09-25 2021-08-30 Accouplements de tige de pompage et raccords de tige comportant des éléments de diamant polycristallin WO2022076106A1 (fr)

Priority Applications (1)

Application Number Priority Date Filing Date Title
CN202180065571.1A CN116391070A (zh) 2020-09-25 2021-08-30 具有多晶金刚石元件的抽油杆联接器和工具接头

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US202063083252P 2020-09-25 2020-09-25
US63/083,252 2020-09-25

Publications (1)

Publication Number Publication Date
WO2022076106A1 true WO2022076106A1 (fr) 2022-04-14

Family

ID=81126701

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/US2021/048247 WO2022076106A1 (fr) 2020-09-25 2021-08-30 Accouplements de tige de pompage et raccords de tige comportant des éléments de diamant polycristallin

Country Status (2)

Country Link
CN (1) CN116391070A (fr)
WO (1) WO2022076106A1 (fr)

Cited By (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN114961592A (zh) * 2022-07-11 2022-08-30 中国地质大学（北京） 具有金刚石微粒复合耐磨带的钻杆

Citations (8)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4938299A (en) * 1989-07-27 1990-07-03 Baroid Technology, Inc. Flexible centralizer
US5810100A (en) * 1996-11-01 1998-09-22 Founders International Non-rotating stabilizer and centralizer for well drilling operations
US20040134687A1 (en) * 2002-07-30 2004-07-15 Radford Steven R. Expandable reamer apparatus for enlarging boreholes while drilling and methods of use
US20150330150A1 (en) * 2013-12-05 2015-11-19 Halliburton Energy Services Inc. Directional casing-while-drilling
US20170114597A1 (en) * 2015-10-26 2017-04-27 Josh Chevalier Downhole drilling assembly with concentric alignment feature
WO2018132915A1 (fr) * 2017-01-19 2018-07-26 Plainsman Mfg. Inc. Centreur de tige de pompage
US20200063503A1 (en) * 2018-08-02 2020-02-27 XR Downhole, LLC Polycrystalline diamond tubular protection
US20200165881A1 (en) * 2018-11-26 2020-05-28 Cobalt Extreme Pty Ltd Centralising assembly for a downhole device, coupling device including a centralising device and method of manufacture

Patent Citations (8)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4938299A (en) * 1989-07-27 1990-07-03 Baroid Technology, Inc. Flexible centralizer
US5810100A (en) * 1996-11-01 1998-09-22 Founders International Non-rotating stabilizer and centralizer for well drilling operations
US20040134687A1 (en) * 2002-07-30 2004-07-15 Radford Steven R. Expandable reamer apparatus for enlarging boreholes while drilling and methods of use
US20150330150A1 (en) * 2013-12-05 2015-11-19 Halliburton Energy Services Inc. Directional casing-while-drilling
US20170114597A1 (en) * 2015-10-26 2017-04-27 Josh Chevalier Downhole drilling assembly with concentric alignment feature
WO2018132915A1 (fr) * 2017-01-19 2018-07-26 Plainsman Mfg. Inc. Centreur de tige de pompage
US20200063503A1 (en) * 2018-08-02 2020-02-27 XR Downhole, LLC Polycrystalline diamond tubular protection
US20200165881A1 (en) * 2018-11-26 2020-05-28 Cobalt Extreme Pty Ltd Centralising assembly for a downhole device, coupling device including a centralising device and method of manufacture

Cited By (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN114961592A (zh) * 2022-07-11 2022-08-30 中国地质大学（北京） 具有金刚石微粒复合耐磨带的钻杆

Also Published As

Publication number Publication date
CN116391070A (zh) 2023-07-04

Similar Documents

Publication Publication Date Title
US11225842B2 (en) Polycrystalline diamond tubular protection
US10267096B2 (en) Drill bit rolling element with retaining ring
US10753151B2 (en) Bearings for downhole drilling motors
US7762359B1 (en) Cutter assembly including rotatable cutting element and drill bit using same
CA2749602C (fr) Manchon non rotatif pour trou decouvert et ensemble correspondant
US20120057814A1 (en) Bearing elements, bearing assemblies and related methods
US20030226660A1 (en) Expandable retaining shoe
CN102221042A (zh) 轴承组件、使用该轴承组件的轴承设备以及相关的方法
EP3658738B1 (fr) Dispositifs de coupe rotatifs et éléments destinés à être utilisés sur des outils de forage de terre dans des trous de forage souterrains, outils de forage de terre les comprenant, et procédés associés
US11603715B2 (en) Sucker rod couplings and tool joints with polycrystalline diamond elements
WO2016081807A1 (fr) Ensembles de dispositif de coupe à rouleau et composant incorporé dans celui-ci
WO2022076106A1 (fr) Accouplements de tige de pompage et raccords de tige comportant des éléments de diamant polycristallin
WO2019083953A1 (fr) Ensembles éléments de coupe comprenant des éléments de coupe rotatifs, outils de forage du sol comprenant de tels ensembles éléments de coupe, et procédés associés
CN111032992A (zh) 包括可旋转切削元件的切削元件组件和井下工具及相关方法
US10851592B2 (en) Movable cutters and devices including one or more seals for use on earth-boring tools in subterranean boreholes and related methods
US11634965B2 (en) Downhole tool and method of use
US20220098936A1 (en) Circumferential wear bands for oilfield tubulars
CA2914103C (fr) Moteur a boue a structure integree resistante a l'abrasion

Legal Events

Date Code Title Description
121 Ep: the epo has been informed by wipo that ep was designated in this application

Ref document number: 21878191

Country of ref document: EP

Kind code of ref document: A1

NENP Non-entry into the national phase

Ref country code: DE

122 Ep: pct application non-entry in european phase

Ref document number: 21878191

Country of ref document: EP

Kind code of ref document: A1