WO2017105412A1 - Accouplement fileté de différentiel à parois minces et à haute résistance à la traction - Google Patents

Accouplement fileté de différentiel à parois minces et à haute résistance à la traction Download PDF

Info

Publication number
WO2017105412A1
WO2017105412A1 PCT/US2015/065866 US2015065866W WO2017105412A1 WO 2017105412 A1 WO2017105412 A1 WO 2017105412A1 US 2015065866 W US2015065866 W US 2015065866W WO 2017105412 A1 WO2017105412 A1 WO 2017105412A1
Authority
WO
WIPO (PCT)
Prior art keywords
mandrel
thread
coupler
conduit
aligning
Prior art date
Legal status (The legal status 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 status listed.)
Ceased
Application number
PCT/US2015/065866
Other languages
English (en)
Inventor
Robert Brice PATTERSON
Benjamin Thomas DERRYBERRY
Paul David Ringgenberg
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Halliburton Energy Services Inc
Original Assignee
Halliburton Energy Services Inc
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 Halliburton Energy Services Inc filed Critical Halliburton Energy Services Inc
Priority to US15/754,266 priority Critical patent/US20180238120A1/en
Priority to GB1802871.2A priority patent/GB2557105A/en
Priority to PCT/US2015/065866 priority patent/WO2017105412A1/fr
Publication of WO2017105412A1 publication Critical patent/WO2017105412A1/fr
Anticipated expiration legal-status Critical
Ceased legal-status Critical Current

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
    • E21B17/02—Couplings; joints
    • E21B17/04—Couplings; joints between rod or the like and bit or between rod and rod or the like
    • E21B17/042—Threaded
    • E21B17/0423—Threaded with plural threaded sections, e.g. with two-step threads
    • 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
    • E21B17/02—Couplings; joints
    • E21B17/04—Couplings; joints between rod or the like and bit or between rod and rod or the like
    • E21B17/042—Threaded
    • E21B17/043—Threaded with locking means
    • 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
    • E21B17/02—Couplings; joints
    • E21B17/04—Couplings; joints between rod or the like and bit or between rod and rod or the like
    • E21B17/042—Threaded
    • 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
    • E21B17/02—Couplings; joints
    • E21B17/04—Couplings; joints between rod or the like and bit or between rod and rod or the like
    • E21B17/042—Threaded
    • E21B17/0426—Threaded with a threaded cylindrical portion, e.g. for percussion rods
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F16—ENGINEERING ELEMENTS AND UNITS; GENERAL MEASURES FOR PRODUCING AND MAINTAINING EFFECTIVE FUNCTIONING OF MACHINES OR INSTALLATIONS; THERMAL INSULATION IN GENERAL
    • F16L—PIPES; JOINTS OR FITTINGS FOR PIPES; SUPPORTS FOR PIPES, CABLES OR PROTECTIVE TUBING; MEANS FOR THERMAL INSULATION IN GENERAL
    • F16L15/00—Screw-threaded joints; Forms of screw-threads for such joints
    • F16L15/08—Screw-threaded joints; Forms of screw-threads for such joints with supplementary elements
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F16—ENGINEERING ELEMENTS AND UNITS; GENERAL MEASURES FOR PRODUCING AND MAINTAINING EFFECTIVE FUNCTIONING OF MACHINES OR INSTALLATIONS; THERMAL INSULATION IN GENERAL
    • F16L—PIPES; JOINTS OR FITTINGS FOR PIPES; SUPPORTS FOR PIPES, CABLES OR PROTECTIVE TUBING; MEANS FOR THERMAL INSULATION IN GENERAL
    • F16L2201/00—Special arrangements for pipe couplings
    • F16L2201/10—Indicators for correct coupling

Definitions

  • the present disclosure relates to oil and gas exploration and production, and more particularly to a coupling subassembly for joining together tubing segments in a tool string.
  • Wells are drilled at various depths to access and produce oil, gas, minerals, and other naturally-occurring deposits from subterranean geological formations.
  • Wells are also drilled in a variety of environments, including in deep water where ocean floor conditions may be softer or more unconsolidated.
  • drill strings and completion strings may extend to a variety of depths and may follow relatively circuitous paths to reach a location of a geological formation that is rich in extractable hydrocarbons.
  • a tool string which may include a running tool, may be used to deploy tools or other devices.
  • tubing segments may be coupled together or with tooling subassemblies. These couplings may be achieved using coupling subassemblies that form robust, sealed joints between segments of tubing in a tool string. The coupling subassemblies also allow coupled tubing segments to disengage from each other.
  • FIG. 1A illustrates a schematic view of an off-shore well in which a tool string is deployed according to an illustrative embodiment
  • FIG. IB illustrates a schematic view of an on-shore well in which a tool string is deployed according to an illustrative embodiment
  • FIG. 2 illustrates a schematic, cross-section view of a coupling assembly for joining two segments of tubing together, in accordance with an illustrative embodiment
  • FIG. 3 illustrates a perspective view of a portion of an embodiment of a coupling used in the coupling assembly of FIG. 2;
  • FIG. 4A illustrates a perspective view of a portion of an embodiment of a first mandrel used in the coupling assembly of FIG. 2;
  • FIG. 4B illustrates a perspective view of a portion of an embodiment of a second mandrel used in the coupling assembly of FIG. 2;
  • FIG. 5A illustrates a cross-section view of a portion of a first external thread of the first mandrel of FIG. 4 A engaged to a first internal thread of the coupler of FIG. 3;
  • FIG. 5B illustrates a cross-section view of a portion of a second external thread of the second mandrel of FIG. 4B engaged to a second internal thread of the coupler of FIG. 3;
  • FIG. 6 illustrates a perspective view of the coupling assembly of FIG. 2 that includes the coupler of FIG. 3, the first mandrel of FIG. 4A, and the second mandrel of FIG. 4B.
  • Liner hanger systems and other types of tool strings may be used during well construction or well remediation and repair in locations ranging from just below the wellhead system to locations deep within a well.
  • Tool strings used in such systems may therefore be extendable, and may include couplings that are tolerant of bending and vibration induced forces to resist decoupling within the wellbore.
  • tool strings such as Drill String Testing (DST) strings, that deploy running tools used to place or set downhole equipment, such as liner hangers, plugs or packers, may be resistant to such induced forces to maintain the integrity of the tool string and prevent the loss of the tool in the well.
  • Tool strings that deploy other types of tools may be similarly resistant to such induced forces.
  • Some tool strings may include coupling assemblies where tubing segments are joined together by couplers to extend the tool string further into a formation.
  • the present disclosure relates to a coupling assembly that tolerates the static and dynamic loads experienced by the tool string and prevents the tool string from decoupling due to hoop stress, vibration, torsion, and other forces that may be experienced when the tool string is rotated and/or manipulated in a well.
  • the coupling assembly is also operable to withstand additional loads, which may result from non-conventional or unanticipated loading of threaded interfaces when the assembly is navigating a tight radius in the well.
  • the coupling assembly is used in a Landing String of a (DST string.
  • the coupling assembly is installed on an ocean floor subsea equipment such as a blowout preventer (BOP) to provide for disconnection and isolation of tubing pressure in case of a required ocean floor disconnect during the DST operations.
  • BOP blowout preventer
  • the coupling assembly is installed on DST tools positioned further downhole from the ocean floor.
  • the coupling assembly is used to couple tubing segments in any suitable tool string, including, for example, a running tool for deploying a liner hanger.
  • FIG. 1A illustrates a schematic view of an offshore platform 142 operating a tool string 128 that includes a coupling assembly 100 according to an illustrative embodiment.
  • the coupling assembly 100 in FIG. 1A may be deployed to couple sections of a subsea test tree residing in a blowout preventer 139 or to couple segments of the tool string 128 in a sub-sea well 138 accessed by the offshore platform 142.
  • the "offshore platform” 142 may be a floating platform, a platform anchored to a seabed 140 or a vessel.
  • FIG. IB illustrates a schematic view of a rig 104 in which a tool string 128 is deployed that includes a coupling assembly 100 in accordance with an illustrative embodiment.
  • the rig 104 is positioned at a surface 124 of a well 102.
  • the well 102 is positioned at a surface 124 of a well 102.
  • FIG. 102 includes a wellbore 130 that extends from the surface 124 of the well 102 to a subterranean substrate or formation 134.
  • the well 102 and the rig 104 are illustrated onshore in FIG. IB.
  • FIGS. 1A-1B each illustrate possible uses or deployments of the coupling assembly 100, which in either instance may be used in tool string 128 to deploy a tool 144 or other device downhole.
  • the wellbore 130 has been formed by a drilling process in which dirt, rock and other subterranean material has been cut from the formation 134 by a drill bit operated via a drill string to create the wellbore 130.
  • a portion of the wellbore may be cased with a casing (not illustrated in FIGS. 1A and IB).
  • the wellbore may be maintained in an open-hole configuration without casing.
  • the tool string 128 may include sections of tubing, each of which are joined to adjacent tubing by threaded or other connection types, such as coupling assembly 100.
  • the tool string 128 may refer to the collection of pipes, mandrels or tubes as a single component, or alternatively to the individual pipes, mandrels, or tubes that comprise the string.
  • the term tool string is not meant to be limiting in nature and may include a running tool or any other type of tool string used to deploy the tool 144 or equipment in the wellbore.
  • the tool string 128 may include a passage disposed longitudinally in the tool string 128 that is capable of allowing fluid communication between the surface 124 of the well 102 and a downhole location 136.
  • the coupling assembly 100 described herein may be used to couple tubing segments in any suitable tool string, including, for example, a running tool for deploying a liner hanger.
  • the lowering of the tool string 128 may be accomplished by a lift assembly 106 associated with a derrick 114 positioned on or adjacent to the rig 104 or offshore platform 142.
  • the lift assembly 106 may include a hook 110, a cable 108, a traveling block (not shown), and a hoist (not shown) that cooperatively work together to lift or lower a swivel 1 16 that is coupled an upper end of the tool string 128.
  • the tool string 128 may be raised or lowered as needed to add additional sections of tubing to the tool string 128 to position the distal end of the tool string 128 at the downhole location 136 in the wellbore 130.
  • Each coupling assembly 100 includes a first mandrel 204 and a second mandrel 206 joined by a coupler 202 at a first end 230 of the first mandrel 204 and a second end 232 of the second mandrel 206.
  • Each mandrel may form a portion of a segment of a tool string.
  • the coupler 202 includes a threaded interface about an internal surface of the coupler 202 to engage the first mandrel 204 and second mandrel 206.
  • the coupler 202 includes a first internal thread 210 on a first end 236 of the coupler 202 and a second internal thread 212 on a second end 238 of the coupler 202.
  • the first internal thread 210 engages a first extemal thread 218 of the first mandrel 204 and the second internal thread 212 engages a second external thread 226 of the second mandrel 206.
  • first internal thread 210 and the second internal thread 212 have different thread pitches.
  • first extemal thread 218 is complementary to and engages the first internal thread 210 and the second external thread
  • first mandrel aligning holes 219 and second mandrel aligning holes 217 are inserted into first mandrel aligning holes 219 and second mandrel aligning holes 217.
  • the aligning pin 216 is an aligning pin that is configured to engage a first mandrel aligning hole 219 and a second mandrel aligning hole 217 to align the first mandrel 204 with respect to the second mandrel 206, and to restrict axial movement of the first mandrel 204 with respect to the second mandrel 206 once the first mandrel 204 and second mandrel 206 are engaged.
  • the coupling assembly 100 further includes one or more port interfaces 220.
  • Each port interface 220 couples a first conduit 221 of the first mandrel 204 to a second conduit 222 of the second mandrel.
  • the first conduit 221 and second conduit 222 may be a hydraulic conduit, wire conduit, or other suitable conduit for conveying a hydraulic or electrical line, such as a control line.
  • the port interface may be an interface of a male connector of the first conduit 221 coupled to a female connector of the second conduit 222, or vise versa. In such embodiments, the port interface 220 forms an electrical or hydraulic coupling between the first mandrel 204 and second mandrel 206.
  • the coupling assembly 100 further includes a locking mechanism 240, such as a locknut, positioned adjacent to the first end 236 or the second end 238 of the coupler 202.
  • the locking mechanism 240 has a threaded interface 242 to engage the first mandrel 204 or second mandrel 206 and to prevent longitudinal motion of the coupler 202 with respect to the first mandrel 204 or the second mandrel 206.
  • multiple locking mechanisms are positioned adjacent to both the first end 236 and the second end 238 of the coupler 202 to secure the coupler 202 and to prevent longitudinal motion of with respect to the first or the second mandrels 204 and 206.
  • FIG. 3 shows a portion of an exemplary coupler 202 used in the coupling assembly 100.
  • the coupler 202 includes the first internal thread 210, which is configured to engage the first external thread 218 of the first mandrel 204, and the second internal thread 212, which is configured to engage the second external thread 226 of the second mandrel 206.
  • the coupler 202 also includes a plurality of visual indicators 265 that indicate the position of the coupler 202 with respect to the first mandrel 204 and second mandrel 206.
  • the first mandrel 204 and second mandrel 206 also include visual indicators, which when aligned with the visual indicators 265 of the coupler 202, indicate that the first mandrel 204 and second mandrel 206 are aligned with each other.
  • the coupler 202 also includes a window 260.
  • the window 260 may be a radial slot that is either open or filled with a transparent material to allow an operator to visually inspect the area surrounded by the coupler 202 to determine whether the first mandrel 204 and second mandrel 206 are aligned.
  • FIG. 4A shows an embodiment of a first end 230 of the first mandrel 204, as shown in the coupling assembly 100 of FIG. 2.
  • the first end 230 includes the first external thread 218 for engaging the first internal thread 210 of the coupler 202.
  • the first end 230 also includes the openings of the first conduits 221 having port interfaces 220 and first mandrel aligning holes 219 for receiving aligning pins 216.
  • the first end 230 also includes a first visual indicator 266.
  • the first conduits 221 and first mandrel aligning holes 219 are positioned about the periphery of the first mandrel to provide a desired number of aligning interfaces and port interfaces 220.
  • the first visual indicator 266 may be a milled, etched, painted, or otherwise marked radial line, on the outer surface of the first mandrel 204 at a first, predetermined distance from the first end 230 of the first mandrel 204.
  • the first visual indicator 266 marks the position of aligning pin 216 and provides a means to identify a location of the aligning pin 216 when the first mandrel 204 is engaged to the coupler 202 and the aligning pin 216 hidden from view by the coupler 202.
  • FIG. 4B shows an embodiment of a second mandrel 206, as shown in the coupling assembly 100 of FIG. 2, and more particularly, a second end 232 of the second mandrel 206.
  • the second end 232 of the second mandrel 206 includes the second external thread 226 for engaging the second internal thread 212 of the coupler 202.
  • the second end 232 also includes the openings of the second conduits 222 having port interfaces 220 and second mandrel aligning holes 217 for receiving aligning pins 216.
  • the second end 232 also includes a second visual indicator 267.
  • the second conduits 222 and second mandrel aligning holes 217 are positioned about the periphery of the second mandrel 206 to provide a desired number of aligning interfaces and port interfaces 220.
  • the second visual indicator 267 may be a milled, etched, painted, or otherwise marked radial line, on the outer surface of the second mandrel 206 at a first, predetermined distance from the second end 232 of the second mandrel 206.
  • the second visual indicator 267 provides a visual indication of a location of one of the second mandrel aligning holes 217 of the second mandrel 206.
  • the first and second visual indicators 266 and 267 provide a visual indication that the first mandrel 204 and second mandrel 206 are aligned.
  • first and second visual indicators 266 and 267 provide readily identifiable alignment indications even when view of the aligning pins 216 and port interfaces 220 are hidden from view by the coupler 202.
  • FIG. 5 A illustrates a cross-section view of the first external thread 218 of the first mandrel 204 of FIG. 4A engaged to the first internal thread 210 of the coupler 202 of FIG.
  • FIG. 5B illustrates a cross-section view of a portion of a second external thread 226 of the second mandrel 206 of FIG. 4B engaged to a second internal thread of the coupler of FIG. 3.
  • the first internal thread 210 and first external thread 218 have a thread pitch that is greater than the thread pitch of the second internal thread 212 and second external thread 226.
  • the first internal thread 210 and first external thread 218 may have a thread pitch of approximately three threads per inch while the second internal thread 212 and second external thread 226 may have a thread pitch of approximately two threads per inch. In such an embodiment, turning of the coupler
  • the first external thread 218 and the second external thread 226 have a reverse lead angle a, which may be, for example, negative seven degrees taken from a base line that is perpendicular to the longitudinal axis of the first mandrel 204 or second mandrel 206.
  • the negative flank angle results in the coupler 202 being drawn inward to compress the coupling assembly 100 when an axial tensile load is applied to the coupling assembly 100 through a tool string that includes the assembly.
  • the first external thread 218 and second external thread may have a trailing flank angle of ⁇ , which may be, for example, approximately forty-five degrees.
  • This configuration directs loads generated from axial loads experienced at the coupling of the first and second external threads 218 and 226 with the first and second internal threads 210 and 212 inwards and towards the longitudinal axis of the first mandrel 204 and second mandrel 206, respectively.
  • the first and second external threads have a reverse lead angle a of approximately negative three to negative thirty degrees and a trailing flank angle ⁇ of approximately thirty to sixty degrees to accommodate a variety of factors such as the tensile load of the first mandrel 204 and second mandrel 206, the length of the coupler 202, the thread pitch and thread profile of the external and internal threads 218, 226, 210, and 212, and the material composition of the first mandrel 204 and second mandrel 206 and the coupler 202.
  • the method includes axially aligning the first end 230 of the first mandrel 204 with the second end 232 of the second mandrel 206. This first and second ends 230 and 232 may be axially aligned by aligning the first visual indicator 266 with the second visual indicator 267. Once the first mandrel 204 and second mandrel 206 are axially aligned with each other, the first mandrel 204 and second mandrel 206 are then held in place to prevent axial motion.
  • the method also includes threading the first internal thread 210 of the coupler 202 onto the first external thread 218 of the first mandrel 204 to engage the first end 230 of the first mandrel 204 with the first end 236 of the coupler 202.
  • the second internal thread 212 of the coupler 202 is then threaded to the second external thread 226 of the second mandrel 206 to engage the second end 232 of the second mandrel 206 with the second end 238 of the coupler 202. Given that the first mandrel 204 is already engaged to the coupler 202, threading the coupler 202 to the second mandrel 206 causes the first mandrel 204 to disengage from the coupler 202 at the first engagement rate.
  • the differential pitch between the first internal thread 210 and second internal thread 212 induces the second mandrel 206 to axially engage the coupler 202 at a second engagement rate that is different than the first engagement rate (or disengagement rate of the first mandrel 204).
  • the coupler 202 will engage the second mandrel 206 approximately fifty percent faster than the coupler 202 will disengage from the first mandrel 204, thereby resulting in the first mandrel 204 moving toward the second mandrel 206 if the coupler 202 is tumed while the first mandrel 204 and second mandrel 206 are constrained from rotating.
  • the first mandrel 204 and second mandrel 206 are constrained from rotating relative to one another by aligning pins 216.
  • the foregoing method induces the second mandrel 206 to move towards the first mandrel 204 until the first end 230 of the first mandrel 204 is engaged to the second end 232 of the second mandrel 206.
  • the method may further include visually or optically inspecting the interface between the first mandrel 204 and second mandrel via the window 260to determine if the first mandrel 204 is aligned with the second mandrel 206.
  • a differential threaded coupling system comprising: a first mandrel having a first extemal thread about an external surface of the first mandrel; a second mandrel having a second external thread about an external surface of the second mandrel; a coupler comprising a first internal thread that complements the first external thread of the first mandrel and a second internal thread that complements the second extemal thread of the second mandrel; and an aligning pin configured to engage a first aligning hole of the first mandrel and a second aligning hole of the second mandrel to restrict axial rotation between the first mandrel and the second mandrel when the first mandrel is engaged to the second mandrel.
  • each tooth of the first extemal thread and second external thread has a reverse lead flank angle of approximately -3 to -30 degrees and a trailing flank angle of approximately 30 to 60 degrees.
  • Clause 4 the coupling system of any of clauses 1-3, wherein the first extemal thread and first internal thread have a first thread pitch and the second internal thread and second external thread have a second thread pitch, the second thread pitch being less than the first thread pitch, such that rotation of the coupler results in an engagement rate of the coupler to the second mandrel that is greater than a disengagement rate of the coupler to the first mandrel.
  • Clause 6 the coupling system of any of clauses 1-5, wherein the plurality of port interfaces comprises an electrical connector, and wherein the electrical connector is coupled to a first conduit comprising an electrical conduit, and a second conduit comprising an electrical conduit.
  • a method of coupling a first mandrel to a second mandrel comprising: aligning a first end of a first mandrel to a second end of a second mandrel, the first mandrel having a first external thread about an external surface of the first mandrel and the second mandrel having a second external thread about an external surface of the second mandrel; threading a coupler to the first mandrel to engage a first internal thread of the coupler to the first external thread of the first mandrel, wherein the first internal thread and first external thread have a first thread pitch; threading the coupler to the second mandrel to engage a second internal thread of the coupler to the second external thread of the second mandrel, wherein the second internal thread and second external thread have a second thread pitch, wherein the second thread pitch is less than the first thread pitch, such that rotating the coupler relative to the first mandrel and second mandrel simultaneously results in the
  • aligning the first end of the first mandrel to the second end of the second mandrel comprises aligning an aligning pin with a first aligning hole of the first mandrel and a second aligning hole of the second mandrel, wherein the aligning pin is configured to restrict axial rotation between the first mandrel and the second mandrel when the first mandrel is engaged to the second mandrel.
  • Clause 12 the method of any of clauses 9-11 , wherein the plurality of port interfaces comprises an electrical connector, and wherein each electrical connector is coupled to a first conduit comprising an electrical conduit, and a second conduit comprising an electrical conduit.
  • Clause 13 the method of any of clauses 9-12, wherein the plurality of port interfaces comprises a hydraulic connector, and wherein each hydraulic connector is coupled to a first conduit comprising a fluid conduit, and a second conduit comprising a fluid conduit.
  • Clause 14 the method of any of clauses 9-13, further comprising aligning a first visual indicator of the first mandrel to a second visual indicator of the second mandrel to align the first end of the first mandrel to the second end of the second mandrel.
  • Clause 15 the method of any of clauses 9-14, further comprising visually determining if the first end of the first mandrel is aligned with the second end of the second mandrel by observing the first mandrel and second mandrel through a window of the coupler.
  • each of the first external thread and second external thread has a reverse lead flank angle of approximately -3 to -30 degrees and a trailing flank angle of approximately 30 to 60 degrees.
  • a coupler comprising: a cavity having a first end for receiving a first mandrel and a second end for receiving a second mandrel; a first intemal thread at the first end, the first intemal thread having a thread profile that complements a first external thread of the first mandrel, wherein the first internal thread and first external thread have a first thread pitch; and a second internal thread having a thread profile that complements a second external thread of the second mandrel, wherein the second internal thread and second external thread have a second thread pitch, the second thread pitch being less than the first thread pitch such that rotating the coupler relative to the first mandrel and second mandrel simultaneously results in the coupler engaging the second mandrel at a faster rate than the coupler disengages the first mandrel.

Landscapes

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

Abstract

Les modes de réalisation de l'invention concernent un système d'accouplement de différentiel, un procédé d'accouplement d'un premier mandrin à un second mandrin et un élément d'accouplement. Selon un mode de réalisation, ledit système comprend un premier mandrin présentant un premier filetage externe autour d'une surface externe du premier mandrin. Le système comprend en outre un second mandrin présentant un second filetage externe autour d'une surface externe du second mandrin. Le système comprend en outre un élément d'accouplement qui présente un premier filetage interne complémentaire au premier filetage externe du premier mandrin et un second filetage interne complémentaire au second filetage externe du second mandrin. Le système comprend en outre une broche d'alignement configurée pour venir en prise avec un premier trou d'alignement du premier mandrin et un second trou d'alignement du second mandrin de sorte à limiter la rotation axiale entre le premier et le second mandrin lorsque le premier mandrin est en prise avec le second mandrin.
PCT/US2015/065866 2015-12-15 2015-12-15 Accouplement fileté de différentiel à parois minces et à haute résistance à la traction Ceased WO2017105412A1 (fr)

Priority Applications (3)

Application Number Priority Date Filing Date Title
US15/754,266 US20180238120A1 (en) 2015-12-15 2015-12-15 High-tensile, thin-wall differential threaded coupling
GB1802871.2A GB2557105A (en) 2015-12-15 2015-12-15 High-tensile, thin-wall differential threaded coupling
PCT/US2015/065866 WO2017105412A1 (fr) 2015-12-15 2015-12-15 Accouplement fileté de différentiel à parois minces et à haute résistance à la traction

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
PCT/US2015/065866 WO2017105412A1 (fr) 2015-12-15 2015-12-15 Accouplement fileté de différentiel à parois minces et à haute résistance à la traction

Publications (1)

Publication Number Publication Date
WO2017105412A1 true WO2017105412A1 (fr) 2017-06-22

Family

ID=59057148

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/US2015/065866 Ceased WO2017105412A1 (fr) 2015-12-15 2015-12-15 Accouplement fileté de différentiel à parois minces et à haute résistance à la traction

Country Status (3)

Country Link
US (1) US20180238120A1 (fr)
GB (1) GB2557105A (fr)
WO (1) WO2017105412A1 (fr)

Families Citing this family (8)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US11613940B2 (en) 2018-08-03 2023-03-28 National Oilwell Varco, L.P. Devices, systems, and methods for robotic pipe handling
US11891864B2 (en) 2019-01-25 2024-02-06 National Oilwell Varco, L.P. Pipe handling arm
US11988059B2 (en) 2019-02-22 2024-05-21 National Oilwell Varco, L.P. Dual activity top drive
NO20220404A1 (en) * 2019-09-12 2022-04-01 Baker Hughes Oilfield Operations Llc Optimized placement of vibration damper tools through modeshape tuning
US11834914B2 (en) * 2020-02-10 2023-12-05 National Oilwell Varco, L.P. Quick coupling drill pipe connector
CA3180958A1 (fr) 2020-05-03 2021-11-11 National Oilwell Varco, L.P. Deconnexion de rotation passive
US11814911B2 (en) 2021-07-02 2023-11-14 National Oilwell Varco, L.P. Passive tubular connection guide
US11982139B2 (en) 2021-11-03 2024-05-14 National Oilwell Varco, L.P. Passive spacer system

Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20020193004A1 (en) * 2001-06-14 2002-12-19 Boyle Bruce W. Wired pipe joint with current-loop inductive couplers
US20030085038A1 (en) * 2000-07-13 2003-05-08 Restarick Henry L. Sand screen with integrated sensors
US20080136166A1 (en) * 2006-12-12 2008-06-12 John Guest International Limited Tube couplings
US20140374084A1 (en) * 2012-01-13 2014-12-25 Los Alamos National Security, Llc System for fracturing an underground geologic formation
US20150267494A1 (en) * 2014-03-24 2015-09-24 Access Downhole Lp Hydraulic jar and a flow control device usable in the hydraulic jar

Family Cites Families (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4762344A (en) * 1985-01-30 1988-08-09 Lee E. Perkins Well casing connection
WO2005035930A2 (fr) * 2003-09-15 2005-04-21 Exxonmobil Upstream Research Company Raccords filetes et procedes de formation associes
US7213655B2 (en) * 2004-01-15 2007-05-08 Schlumberger Technology Corporation System for connecting downhole tools
US7434848B2 (en) * 2005-05-12 2008-10-14 Boyd Anthony R Threaded tubular connection having interlocking tubular end structures
MX2013000387A (es) * 2010-07-02 2013-03-22 Sunstone Technologies Llc Cableado electrico para varilla de perforacion, revestimiento y tuberia.
GB2504671A (en) * 2012-08-03 2014-02-12 Bae Systems Plc Alignment device, and method of alignment using an alignment device

Patent Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20030085038A1 (en) * 2000-07-13 2003-05-08 Restarick Henry L. Sand screen with integrated sensors
US20020193004A1 (en) * 2001-06-14 2002-12-19 Boyle Bruce W. Wired pipe joint with current-loop inductive couplers
US20080136166A1 (en) * 2006-12-12 2008-06-12 John Guest International Limited Tube couplings
US20140374084A1 (en) * 2012-01-13 2014-12-25 Los Alamos National Security, Llc System for fracturing an underground geologic formation
US20150267494A1 (en) * 2014-03-24 2015-09-24 Access Downhole Lp Hydraulic jar and a flow control device usable in the hydraulic jar

Also Published As

Publication number Publication date
GB201802871D0 (en) 2018-04-11
US20180238120A1 (en) 2018-08-23
GB2557105A (en) 2018-06-13

Similar Documents

Publication Publication Date Title
CA2978519C (fr) Mecanisme de verrouillage d'outil de pose
US20180238120A1 (en) High-tensile, thin-wall differential threaded coupling
US9534466B2 (en) Cap system for subsea equipment
US11988048B2 (en) Self-locking coupler
US11261708B2 (en) Energy transfer mechanism for wellbore junction assembly
BR112019015572A2 (pt) Aparelho para formar pelo menos uma parte de um sistema de produção para um furo do poço, e uma linha para e método de realizar uma operação para ajustar um tampão de cimento em um furo do poço
US11506024B2 (en) Energy transfer mechanism for wellbore junction assembly
NO348860B1 (en) Big bore running tool quick lock adaptor
US20210040815A1 (en) Electrohydraulic quick union for subsea landing string
US20140076575A1 (en) System and Method for Producing Through a Multi Bore Tubing Hanger to a Subsea Manifold Without BOP Modifications
GB2387187A (en) Deepwater drilling system
US12497852B2 (en) Big bore low pressure surface wellhead housing systems
CN105874146A (zh) 井筒中的深度、载荷和转矩参考

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: 15910891

Country of ref document: EP

Kind code of ref document: A1

WWE Wipo information: entry into national phase

Ref document number: 15754266

Country of ref document: US

ENP Entry into the national phase

Ref document number: 201802871

Country of ref document: GB

Kind code of ref document: A

Free format text: PCT FILING DATE = 20151215

NENP Non-entry into the national phase

Ref country code: DE

122 Ep: pct application non-entry in european phase

Ref document number: 15910891

Country of ref document: EP

Kind code of ref document: A1

ENPC Correction to former announcement of entry into national phase, pct application did not enter into the national phase

Ref country code: GB