EP2823130A1 - Joint de sécurité à blocage à utiliser dans un puits souterrain - Google Patents

Joint de sécurité à blocage à utiliser dans un puits souterrain

Info

Publication number
EP2823130A1
EP2823130A1 EP12870623.1A EP12870623A EP2823130A1 EP 2823130 A1 EP2823130 A1 EP 2823130A1 EP 12870623 A EP12870623 A EP 12870623A EP 2823130 A1 EP2823130 A1 EP 2823130A1
Authority
EP
European Patent Office
Prior art keywords
safety joint
locking device
mandrel
tubular string
packer
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.)
Withdrawn
Application number
EP12870623.1A
Other languages
German (de)
English (en)
Other versions
EP2823130A4 (fr
Inventor
Reid E. ZEVENBERGEN
Paul D. 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
Publication of EP2823130A1 publication Critical patent/EP2823130A1/fr
Publication of EP2823130A4 publication Critical patent/EP2823130A4/fr
Withdrawn legal-status Critical Current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
    • E21B17/06—Releasing-joints, e.g. safety joints

Definitions

  • This disclosure relates generally to equipment utilized and operations performed in conjunction with a subterranean well and, in one example described below, more particularly provides for locking a safety joint in an extended
  • a safety joint is typically interconnected in a tubular string to allow the tubular string to be parted at the safety joint, for example, in the event that a packer or other equipment becomes stuck in a wellbore. After the safety joint separates, the tubular string above the safety joint can be readily retrieved from the wellbore.
  • the safety joint can include separable portions which, when separated, disconnect sections of a tubular string. Elongation of the safety joint is permitted while longitudinal compression of the safety joint is prevented.
  • a method of activating a safety joint in a subterranean well is also provided to the art.
  • the method can include: providing the safety joint with portions having end connectors which interconnect the safety joint between sections of a tubular string;
  • Another safety joint can include separable portions, and a locking device which permits relative displacement between a generally tubular mandrel and a component of the safety joint in one direction, and prevents relative
  • FIG. 1 is a representative partially cross-sectional view of a well system and associated method which can embody principles of this disclosure.
  • FIG. 2 is a partially cross-sectional view of a prior art packer.
  • FIG. 3 is a cross-sectional view of a safety joint which can embody principles of this disclosure, and which may be used in the system and method of FIG. 1.
  • FIG. 4 is an enlarged scale representative cross- sectional view of a locking device of the safety joint.
  • FIGS. 5A-C are representative cross-sectional views of the safety joint in an extended and locked configuration.
  • FIG. 1 Representatively illustrated in FIG. 1 is a well system 10 and associated method which can embody principles of this disclosure.
  • system 10 and method are merely one example of how the principles of this disclosure can be applied in practice, and so the scope of this disclosure is not limited at all to the details of the system and method as depicted in the drawings and described below.
  • a tubular string 12 is installed in a wellbore 14 lined with cement 16 and casing 18.
  • a packer 20 is set to thereby seal off an annulus 22 formed radially between the tubular string 12 and the wellbore 14.
  • Another packer 24 (or a bridge plug, etc.) may be used if desired to seal off the wellbore 14, so that the annulus 22 is isolated between the packers 20, 24.
  • the tubular string 12 could be used for any purpose
  • one or more perforating guns 26 are interconnected in the tubular string 12 for perforating the casing 18 and cement 16, so that fluid can be produced from, or injected into, an earth formation 28 penetrated by the wellbore 14.
  • the formation 28 can then be tested by performing pressure buildup and drawdown tests, in a manner well known to those skilled in the art.
  • a safety joint 30 is interconnected in the tubular string 12 below (as viewed in FIG. 1) the packer 20.
  • the safety joint can be activated to disconnect an upper section 12a of the tubular string 12 from a lower section 12b of the tubular string, so that the upper section can be retrieved.
  • a separate "fishing" trip can then be used to retrieve the lower section 12b of the tubular string 12.
  • tubular string 12 could include additional, fewer or different elements from those depicted in FIG. 1, the wellbore can be horizontal or inclined, etc.
  • the scope of this disclosure is not limited to the example configuration representatively illustrated in FIG. 1.
  • the safety joint 30 includes a feature which prevents the packer 20 from setting after the safety joint has been elongated.
  • the upper section 12a of the tubular string 12 can be conveniently retrieved from the wellbore 14, without the possibility of the packer 20 inadvertently setting after the safety joint 30 has been elongated.
  • setting of the packer 20 can be prevented, whether or not the tubular string 12 has parted at the safety joint 30.
  • the packer 20 is representatively illustrated, apart from the remainder of the system 10.
  • the packer 20 may be similar in many respects to a prior art RTTS(TM) packer marketed by Halliburton
  • the packer 20 is representative of a retrievable packer, operation of which can benefit from the principles of this disclosure.
  • other types of packers may be used, in keeping with the scope of this disclosure.
  • packers which may be used include the CHAMP IV(TM) and CHAMP V(TM) packers, also marketed by Halliburton Energy Services, Inc.
  • the packer 20 includes a generally tubular mandrel 34, a set of hydraulically actuated slips 36, a set of seal elements 38, a set of mechanically actuated slips 40 and a drag block 42.
  • a J-slot mechanism (not visible in FIG. 2) controls whether the mandrel 34 can be lowered (as viewed in FIG. 2) relative to the seal elements 38, slips 40 and drag block 42.
  • the drag block 42 is biased into contact with an inner wall of the casing 18 (or the formation 28 in an uncased wellbore) and thereby provides a frictional force, so that the mandrel 34 will displace downward relative to the seal elements 38, slips 40 and drag block when the J- slot mechanism is operated to its "set” position (allowing downward displacement of the mandrel relative to the drag block 42, etc.).
  • the packer is positioned lower in the wellbore 14 than its intended setting location, the packer is then raised and rotated to select the J-slot mechanism "set” position, and the tubular string 12 is then lowered to set the packer.
  • the frictional force provided by the drag block 42 urges the slips 40 upward along ramps 44, so that the slips displace radially outward and obtain an initial "bite” into the casing 18 (or formation 28 if the wellbore 14 is uncased) .
  • Further lowering of the tubular string 12 and mandrel 34 compresses the seal elements 38, thereby radially outwardly extending the seal elements and sealing off the annulus 22.
  • the packer 20 can be unset by raising the mandrel 34, thereby decompressing the seal elements 38 and allowing the slips 40 to retract inward.
  • the safety joint 30 is representatively illustrated, apart from the remainder of the system 10.
  • the safety joint 30 may be similar in many respects to a prior art Below Packer Hydraulic Safety Joint marketed by Halliburton Energy Services, Inc., and well known to those skilled in the art.
  • the safety joint 30 is representative of an improved type of safety joint, operation of which can benefit from the principles of this disclosure.
  • other types of safety joints may be used in the system 10, in keeping with the scope of this disclosure.
  • Examples of other safety joints which may be improved using the principles of this disclosure include the Anchor Pipe Safety Joint, the RTTS (TM) Safety Joint and the VR (TM) Safety Joint, also
  • the safety joint 30 includes a generally tubular mandrel 46 extending between end connectors 48, 50.
  • the upper section 12a When interconnected in the tubular string 12, the upper section 12a is connected to the connector 48, and the lower section 12b is connected to the connector 50.
  • the upper connector 48 has internal tapered threads for connecting to the upper tubular string section 12a
  • the lower connector 50 has external tapered threads for connecting to the lower tubular string section 12b.
  • any types of connections may be used, as desired.
  • a piston 52 is connected at a lower end of the mandrel 46.
  • the piston 52 is sealingly and reciprocably received in an outer housing 54.
  • the lower connector 50 is connected to the outer housing 54 via left-hand threads 56.
  • the mandrel 46 is connected to the upper connector 48.
  • the shear pins 58 will shear, thereby permitting relative axial displacement between the mandrel 46 and the outer housing 54.
  • the splines 59 do not prevent such relative axial displacement between the mandrel 46 and the outer housing 54.
  • a hydraulic fluid is contained in an annular chamber 60 formed radially between the mandrel 46 and the outer housing 54.
  • the piston 52 When the mandrel 46 is permitted to displace axially upward relative to the outer housing 54 (e.g., upon shearing of the pins 58), the piston 52 will compress the fluid in the chamber 60.
  • pressure in the chamber 60 reaches a predetermined level, a rupture disk 62 will burst, allowing the fluid to drain from the chamber, and thereby permitting relatively unrestricted upward displacement of the mandrel 46 relative to the outer housing 54.
  • castellated lugs 64 on an upper end of the piston 52 engage complementary lugs 66 on a floating piston 68, which also has lugs 70 which engage similar lugs (not visible in FIG. 3 ) on a component 72 connected to the outer housing 54.
  • This engagement of lugs 64, 66, 70 prevents relative rotation between the mandrel 46 and the outer housing 54.
  • the splines 59 are disengaged.
  • a lower portion 74 of the safety joint 30 (comprising the lower connector 50, threads 56, etc.) is left attached to the tubular string lower section 12b.
  • the lower portion 74 is configured internally for convenient "fishing" of the tubular string lower section 12b.
  • a locking device 78 which prevents downward displacement of the mandrel 46 relative to the component 72 (which, at this point, remains rigidly connected to the lower connector 50), after the safety joint has been
  • the locking device 78 includes a resilient internally and externally toothed ring 80 which engages a complementarily toothed external surface 82 on the mandrel 46.
  • An enlarged scale cross-sectional view of the locking device 78 is representatively illustrated in FIG. 4.
  • the ring 80 has relatively coarse buttress-type
  • the ring 80 is longitudinally split on one side, so that it can radially expand or contract
  • a fastener 88 is installed in the longitudinal split to prevent rotation of the ring 80 relative to the component 72 in which it is received (e.g., so that the ring does not unthread from the component).
  • the locking device 78 does not prevent upward or downward displacement of the mandrel relative to the component 72.
  • the mandrel 46 has displaced upward a sufficient distance for the internal threads 86 to engage the toothed external surface 82, downward displacement of the mandrel relative to the component 72 will be prevented by such engagement, thereby preventing downward displacement of the upper portion 73 of the safety joint 30 (and the tubular string section 12a to which it is connected) . This will prevent resetting of the packer 20.
  • the threads 84, 86 could instead be circumferential ridges, grooves, recesses, or other shapes which can facilitate a gripping or other locking engagement between the mandrel 46 and the component 72.
  • the toothed external surface 82 on the mandrel 46 can be made up of any shapes or configurations which can operate
  • the safety joint 30 is representatively illustrated after the shear pins 58 have been sheared, the rupture disk 62 has ruptured, and the safety joint has been elongated sufficiently far for the internal threads 86 of the locking device 78 to engage the toothed external surface 82 of the mandrel 46.
  • the safety joint 30 is prevented from being longitudinally compressed, since the locking device 78 now prevents downward displacement of the mandrel 46.
  • the mandrel 46 can still be displaced upward relative to the component 72 as needed (e.g., to permit right-hand rotation to unthread the threads 56 and disconnect the upper portion of the safety joint 30 from the lower portion 74).
  • a jar (not shown) interconnected in the tubular string 12 can be used to transmit an impact through the safety joint 30, if desired, to free any stuck equipment below the safety joint.
  • the safety joint 30 could be used in other systems and methods, and in circumstances in which its features are useful (e.g., in jarring operations, etc.), whether or not resetting of a packer is to be avoided.
  • the safety joint 30 for use in a subterranean well.
  • the safety joint 30 comprises separable portions 74, 76 which, when separated, disconnect sections 12a, b of a tubular string 12. Elongation of the safety joint 30 is permitted while longitudinal compression of the safety joint 30 is prevented.
  • the safety joint 30 can also include a locking device 78 which prevents the longitudinal compression of the safety joint 30.
  • the locking device 78 may include a resilient toothed member.
  • the resilient toothed member can comprise a longitudinally split ring 80.
  • the locking device 78 may grip an external surface 82 of a generally tubular mandrel 46.
  • the external surface 82 can be gripped by an internally toothed member (e.g., the ring 80).
  • the locking device 78 may prevent longitudinal compression of the safety joint 30 in response to a
  • the method can, in some examples, comprise providing the safety joint 30 with portions 74, 76 having end connectors 48, 50 which interconnect the safety joint 30 between sections 12a, b of a tubular string 12; permitting elongation of the safety joint 30, thereby facilitating parting of the tubular string sections 12a, b; and then preventing longitudinal compression of the safety joint 30 prior to the tubular string 12 parting .
  • the permitting step can be performed after
  • the preventing step can be performed after a
  • the preventing step may include a locking device 78 engaging, thereby preventing the end connectors 48, 50 from displacing toward each other.
  • the locking device 78 can comprise a resilient toothed member.
  • the locking device 78 may engage an external surface 82 of a generally tubular mandrel 46 of the safety joint 30.
  • the external surface 82 can comprise a toothed surface which is engaged by the locking device 78.
  • the preventing step can comprise preventing a packer mandrel 34 from displacing relative to a packer drag block 42.
  • the preventing step may include preventing a packer 20 from setting.
  • the safety joint 30 can comprise separable portions 74, 76 and a locking device 78 which permits relative displacement between a generally tubular mandrel 46 and a component 72 of the safety joint 30 in one direction, and prevents relative displacement between the mandrel 46 and the component 72 in an opposite
  • the locking device 78 may prevent relative displacement between the mandrel 46 and the component 72 in the opposite direction in response to a predetermined amount of relative displacement between the mandrel and the component in the one direction.

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)
  • Pipe Accessories (AREA)

Abstract

Cette invention concerne un joint de sécurité à utiliser dans un puits souterrain, comprenant optionnellement des parties séparables qui, quand elles sont séparées, déconnectent les sections d'une colonne de production. Ledit joint de sécurité peut s'allonger mais sa compression longitudinale est empêchée. L'invention concerne en outre un procédé d'actionnement d'un joint de sécurité dans un puits souterrain, comprenant les étapes consistant à : utiliser le joint de sécurité comprenant des connecteurs d'extrémité qui interconnectent le joint de sécurité entre sections d'une colonne de production ; permettre l'allongement du joint de sécurité de façon à faciliter le désaccouplement des sections de colonne de production et empêcher la compression longitudinale du joint de sécurité. Selon un autre mode de réalisation, ledit joint de sécurité comprend des parties séparables et un dispositif de blocage qui permet le déplacement relatif entre un mandrin généralement tubulaire et un composant du joint de sécurité dans une direction, et qui empêche le déplacement relatif du mandrin et du composant dans un sens opposé.
EP12870623.1A 2012-03-06 2012-03-06 Joint de sécurité à blocage à utiliser dans un puits souterrain Withdrawn EP2823130A4 (fr)

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
PCT/US2012/027803 WO2013133797A1 (fr) 2012-03-06 2012-03-06 Joint de sécurité à blocage à utiliser dans un puits souterrain

Publications (2)

Publication Number Publication Date
EP2823130A1 true EP2823130A1 (fr) 2015-01-14
EP2823130A4 EP2823130A4 (fr) 2015-09-02

Family

ID=49117136

Family Applications (1)

Application Number Title Priority Date Filing Date
EP12870623.1A Withdrawn EP2823130A4 (fr) 2012-03-06 2012-03-06 Joint de sécurité à blocage à utiliser dans un puits souterrain

Country Status (5)

Country Link
EP (1) EP2823130A4 (fr)
AU (1) AU2012372854B2 (fr)
BR (1) BR112014019420A8 (fr)
SG (1) SG11201403187QA (fr)
WO (1) WO2013133797A1 (fr)

Family Cites Families (9)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4778008A (en) * 1987-03-05 1988-10-18 Exxon Production Research Company Selectively releasable and reengagable expansion joint for subterranean well tubing strings
US5086843A (en) * 1990-09-27 1992-02-11 Union Oil Company Of California Oil tool release joint
GB2290812B (en) * 1994-07-01 1998-04-15 Petroleum Eng Services Release mechanism for down-hole tools
GB2317629B (en) * 1996-09-27 2001-03-28 Red Baron Safety joint
US6349767B2 (en) * 1998-05-13 2002-02-26 Halliburton Energy Services, Inc. Disconnect tool
CA2462012C (fr) * 2004-03-23 2007-08-21 Smith International, Inc. Systeme et methode d'installation d'une colonne perdue dans un trou de forage
US7426964B2 (en) * 2004-12-22 2008-09-23 Baker Hughes Incorporated Release mechanism for downhole tool
US7431094B2 (en) * 2006-03-10 2008-10-07 Halliburton Energy Services, Inc. Method for utilizing downhole safety joint
GB2468271B (en) * 2008-11-28 2013-06-19 Intelligent Drilling Tools Ltd Disconnect device for downhole assembly

Also Published As

Publication number Publication date
EP2823130A4 (fr) 2015-09-02
AU2012372854B2 (en) 2014-10-02
WO2013133797A1 (fr) 2013-09-12
AU2012372854A1 (en) 2014-07-24
BR112014019420A8 (pt) 2017-07-11
SG11201403187QA (en) 2014-07-30
BR112014019420A2 (fr) 2017-06-20

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