EP0504848A1 - Procédé et appareil pour couper et enlever un tubage de puits - Google Patents

Procédé et appareil pour couper et enlever un tubage de puits Download PDF

Info

Publication number
EP0504848A1
EP0504848A1 EP92104700A EP92104700A EP0504848A1 EP 0504848 A1 EP0504848 A1 EP 0504848A1 EP 92104700 A EP92104700 A EP 92104700A EP 92104700 A EP92104700 A EP 92104700A EP 0504848 A1 EP0504848 A1 EP 0504848A1
Authority
EP
European Patent Office
Prior art keywords
casing
assembly
grapple
slips
workstring
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.)
Granted
Application number
EP92104700A
Other languages
German (de)
English (en)
Other versions
EP0504848B1 (fr
Inventor
B. Carter Thurman
Shane P. Hart
Carl D. Reynolds
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.)
Weatherford Lamb Inc
Original Assignee
Homco International Inc
Weatherford Holding US 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 Homco International Inc, Weatherford Holding US Inc filed Critical Homco International Inc
Publication of EP0504848A1 publication Critical patent/EP0504848A1/fr
Application granted granted Critical
Publication of EP0504848B1 publication Critical patent/EP0504848B1/fr
Anticipated expiration legal-status Critical
Expired - Lifetime legal-status Critical Current

Links

Images

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
    • E21B31/00—Fishing for or freeing objects in boreholes or wells
    • E21B31/12—Grappling tools, e.g. tongs or grabs
    • E21B31/20—Grappling tools, e.g. tongs or grabs gripping internally, e.g. fishing spears
    • 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
    • E21B31/00—Fishing for or freeing objects in boreholes or wells
    • E21B31/12—Grappling tools, e.g. tongs or grabs
    • E21B31/16—Grappling tools, e.g. tongs or grabs combined with cutting or destroying means

Definitions

  • the present invention is directed generally to a method and apparatus to cut and remove well casing, and, more specifically, is directed to a method and apparatus to cut well casing and extract it from the well bore in a single downhole trip.
  • casing removal requires that the casing string first be severed and the free end then pulled to the surface, to remove the severed portion.
  • a grapple assembly or "spear" is adapted to be inserted in the top portion of the casing, with the degree of insertion of the spear into the casing limited by a stop ring.
  • the spear in such systems is a mechanically actuated spear, which is actuated through use of interference between the spear grapple and the casing, and through manipulation of the workstring.
  • Such systems offer the disadvantages that there is a fixed distance between this stop and the cutting elements. Accordingly, when the grapple is placed inside the casing (and its depth is established by the placement of the stop), there is a fixed depth that which the cutter can be placed. Accordingly, if the first attempt to free the casing is not successful, this type of tool must be pulled out of the hole, and the distance between the grapple stop and cutting elements either lengthened or shortened to facilitate another cut of the casing at a different depth.
  • the present invention provides a new method and apparatus whereby casing may be cut and pulled with the string in tension, and whereby the grapples may be placed at virtually any desired location within the casing, allowing multiple attempts to cut and pull the casing on a single trip of the workstring into the wellbore.
  • Apparatus for cutting and retrieving a casing string in accordance with the present invention preferably include a grapple assembly which is adapted to be insertable into the casing, and which can be actuated to engage the casing at virtually any desired location.
  • the grapple assembly will include a plurality of slips which are adapted to move between a first position wherein the slips do not substantially engage the casing (i.e., the grapple assembly may move longitudinally through the casing), and a second position in which the slips do substantially engage the casing (i.e., the grapple assembly will engage the casing with a minimum of either rotational or longitudinal movement).
  • the grapple assembly will preferably be rotatably mounted relative to a mandrel assembly which is adapted to be secured to the workstring.
  • a cutting assembly will be operatively coupled to the lower end of the mandrel assembly such that the cutting assembly will be rotatable in response to rotation of the workstring.
  • the grapple assembly will include a plurality of slips generally circumferentially arranged around the assembly, which slips will be moved between the engaged and unengaged positions in response to the application of fluid pressure within the workstring.
  • the application of such fluid pressure will cause movement of the slips relative to a support member having a generally conical section, and such movement of the slips relative to such support member will cause the slips to engage or disengage the casing.
  • Fig. 1 illustrates a side, external view of the apparatus of the present invention.
  • Fig. 2 illustrates a side, partial cutaway view of the cutting and retrieval apparatus illustrated in Fig. 1.
  • Fig. 3 illustrates a side, partial cutaway view of the upper assembly of the spear showing the relative position of the J-groove and the friction blocks.
  • Fig. 4 illustrates a side detail view of the grapple slips as mounted on the swivel cone.
  • Fig. 5 illustrates a side, detail view of the lower sub and wear collar.
  • Fig. 6 illustrates a side view of the mandrel.
  • Fig. 7 illustrates a side partial cutaway view of the tool as it would appear when lowered into the wellbore prior to cutting operation.
  • Fig. 8 illustrates a side view of the tool as it would appear during the cutting operation.
  • Fig. 9 illustrates a side view of the tool as it would appear during the extraction of the casing.
  • Fig. 10 illustrates a side, partial cutaway, detail view of the latching assembly of the mandrel sleeve when positioned in the "closed" position.
  • Fig. 11 illustrates a section view through lines 11-11' in Fig. 10.
  • Fig. 12 illustrates a side, partial cutaway, detail view of the latching assembly of the mandrel when in the "engaged" position.
  • Fig. 13 is a section view through lines 13-13' in Fig. 12.
  • Fig. 14 is a side, detail cross section of the piston tube when positioned in a "closed" configuration.
  • Fig. 15 is a side, detail cross section of the piston tube when in an "extended" position.
  • Fig. 16 is an end cross section of the grapple slips taken through lines 16-16' of Fig. 7.
  • Fig. 17 is an end cross section of the grapple slips taken through lines 17-17' of Fig. 8.
  • Fig. 18 is an end cross section of the friction blocks taken through lines 18-18' of Fig. 8.
  • Fig. 19 is an oblique view of the swivel cone.
  • Fig. 20 is a side, detail view of the teeth formed along the contact surface of the slip segments illustrating the tangential angle of inclination of the teeth surface.
  • Fig. 21 is a side, detail view of the slip segments of Fig. 20 illustrating the axial angle of inclination of the teeth surface.
  • Casing cutting and receiving assembly 100 includes a body or mandrel 1 which includes an upper end attachment 1A for coupling to a workstring 105.
  • An optional drilling jar 104 is depicted in one exemplary configuration between mandrel 1 and workstring 105.
  • Drilling jar 104 may be one of any appropriate and conventional type as will be readily appreciated by those skilled in the art.
  • the term "workstring” includes any string, whether formed of drill pipe, work pipe, production tubing, etc., as may be utilized to perform well operations.
  • casing cutting, and retrieving assembly 100 disposed within casing 101. Casing 101 is conventionally installed in a formation 102, and is secured in position by cement 103.
  • mandrel 1 of casing cutting and retrieving assembly 100 is threadedly coupled to a lower subassembly 49 which may in turn be connected to a cutting tool via box end 49A as will be further described herein.
  • Mandrel 1 defines a bore 52 therethrough to accommodate the passage of well fluid as will be further described.
  • the uppermost portion of the tool includes an outer shield or sleeve 3 which is threadedly disposed about the mandrel 1.
  • Outer shield 3 serves to furnish physical protection of mandrel 1 and J-groove 51, the function of which will be further described herein.
  • shield 3 is held in place by a fastener 2. (See Fig. 2).
  • Shield 3 includes a pressure relief valve 4 which covers the access hole to a J-groove key 6.
  • a piston tube 8 is disposed about mandrel 1 immediately below shield 3.
  • Piston tube 8 serves to house J-groove 51 and defines a hydraulic chamber 54, the integrity of said chamber being maintained by packing seals 10 and 11. (See Fig. 2). Contaminants are also prevented from entering J-groove slot 51 by the inclusion of a wiper seal 9.
  • Piston tube 8 is biased in a closed or upper position by a compression spring 15.
  • a drive sleeve 14 is threadedly connected to piston tube 8 about mandrel 1 and secured by locking screw 13. Accidental unthreading of screw 13 is prevented by an internal retaining ring 12.
  • Drive sleeve 14 serves to support friction blocks 19 and house compression spring 15. (See Fig. 2).
  • Drive sleeve 14 also serves as a means to connect piston tube 8 and floating sleeve 24 as will be further described herein.
  • a lower bearing 26, ideally an anti-friction bearing, is disposed below bearing 23 between sleeves 24 and 14.
  • Bearing 26 serves to limit the travel of floating sleeve 24 and acts as a lower bearing for drive sleeve 14 and floating sleeve 24. Contamination of bearings 23 and 26 is inhibited by upper seal 22 and lower seal 28.
  • Compression spring 15 is mounted on a ring 16 which constitutes a removable shoulder used to transmit the load of spring 15 to an external retaining ring 17. (See Fig. 2). Ring 16 also serves to facilitate the assembly of compression spring 15.
  • Friction blocks 19 are circumferentially disposed about drive sleeve 14 as illustrated in Figs. 2 and 18.
  • Friction blocks 19A are outwardly biased via a plurality of extrusion springs 18. In such a fashion, the outer contact surfaces of blocks 19A maintain continuous contact with the interior of the casing 101. As a result of such contact, friction block assembly 19 serves to provide resistance when mandrel 1 is rotated relative to tube 8. This rotational resistance is necessary to operate the J-groove 51 lock mechanism as will be further discussed herein.
  • Friction blocks 19 are axially retained in place by a friction block retainer 20 which is circumferentially disposed about mandrel 1. Retainer 20 is held in place by an external retaining ring 21.
  • Sleeve 24 is capable of axial movement about mandrel 1. When urged downward about the mandrel 1, sleeve 24 forces slips 32 into contact with the inner diameter of the casing 101. Floating sleeve 24 also allows drive sleeve 14 to rotate when grapple slips 32 are situated in engagement with the casing 100 as will be further described herein.
  • Grapple slips 32 are disposed immediately below sleeve 24 as illustrated in Fig. 1.
  • Slips 32 are comprised of a number of segments 32A which are held in place by slip guide rails 35. (See Figs. 16-17).
  • Sleeve 24 is also adapted to hold grapple slip segments 32A in suspension.
  • Slip segments 32A preferably include a tongue or T-groove which fits in a complementary tongue or T-groove in floating sleeve 24, the overall structural makeup of slips 32 being generally conventional in fashion.
  • Slip segments 32A preferably include tongues or grooves which fit into complementary tongues or grooves in rails 35. Rails 35 prevent rotational movement of segments 32A relative to swivel cone 37.
  • grapple slips 32 When actuated, grapple slips 32 serve to engage the inner bore of the well casing with a sufficient force to support the weight of the casing in addition to the overpull necessary to break the casing loose from the formation during retrieval. Slips 32 are physically moved into contacting engagement with the inner diameter of the casing by swivel cone 37 and floating sleeve 24. Structurally, swivel cone 37 is located immediately below grapple slips 32 and guide rails 35 as illustrated in Fig. 1. Slip guide rails 35 are retained in place by a fastener 34.
  • Swivel cone 37 comprises an upper cone shaped portion whose exterior slidably engages the interior of grapple segments 32A. (See Figs. 4, 16 and 17). In such a fashion, when segments 32A are forced downward along rails 35 by the downward movement of sleeve 24, segments 32A are interiorly supported by the tapered wedge shaped surface provided by cone 37.
  • cone 37 defines at least two tapered surfaces 37A which may be better seen by reference to Figure 19.
  • the upper conic portion of cone 37 is disposed proximate an upper journal bearing 33, and a lower journal bearing 38. Both bearings 33 and 38 are preferably self-lubricating. Bearings 33 and 38 permit rotation of cone 37 relative to mandrel 1.
  • Bearings 33 and 38 are lubricated via a lubrication fitting 36 as shown in Fig. 2.
  • Upper wiper seal 61 is retained by a cone bushing 30, which bushing also serves to protect the small end 112 of cone 37 and inhibit the introduction of contaminants therein.
  • a lower wiper seal 39 serves to inhibit the introduction of contaminants into swivel cone 37.
  • slips 32 as referenced above is hydraulically actuated.
  • mud or other fluid is pumped through mandrel bore 52.
  • a majority of this fluid flow is utilized to operate the casing cutter tool 56 in a conventional fashion.
  • backpressure in cutting tool 56 forces some fluid through actuation conduit 53 to hydraulic chamber 54. (See Figs. 14 and 15).
  • Fluid entering chamber 54 forces piston tube 8 and sleeve 24 downward.
  • the downward movement of sleeve 24 forces grapple slips 32 downward over cone 37. This results in grapple segments 32A being moved outward in a radial direction by the wedge shaped profile of cone 37 as earlier described. In such a fashion, grapple slips 32 are forced downward until slip segments 32A contact and "bite" into the interior of casing 101.
  • cone 37 should be provided with multiple wedging surfaces so that swivel cone 37, when viewed in side cross section, describes two or more conic sections preferably defining a tapered angle in the range of 4°-30° with respect to the axis of the tool, and most preferably defining an angle within the range of approximately 4°-8°. This may be better seen by reference to Fig. 19 in which is illustrated a taper angle of 4°.
  • teeth 60 are formed at an angle in the range of approximately 5-60° in an axial direction and 0-45° in a tangential direction.
  • teeth 60 will be formed at an angle in the range of approximately 5-30° in the axial direction and 5-30° in the tangential direction.
  • teeth formed at an angle of 12° in the axial direction and 8° in a tangential direction have been found to perform satisfactorily. See Fig. 20-21.
  • teeth 60 are formed so as to offer nonslip capacity to both pulling tension and rotation in either a clockwise or counterclockwise direction.
  • Grapple segments 32A are preferably manufactured from hardened steel, e.g., induction hardened 4140 steel.
  • the surface of teeth 60 may also include other elements to increase hardness.
  • an upper thrust bearing 40 is situated immediately below swivel cone 37 so as to permit rotation between swivel cone 37 and lower sub 49.
  • Bearing 40 rests on an upper bearing race 41 which achieves even load distribution between disc springs 42 and thrust bearing 40.
  • a conventional prestressed disc spring array incorporating 28 individual segments has been found to be desirable. Such disc springs will preferably be manufactured to D.I.N. spec. 2093.
  • Disc springs 42 serve to compensate for axial movement of the drilling string when the mandrel 1 is rotated under tension. As will be further described herein, it is desirable to rotate casing cutter 56 while a moderate to large tensional force is applied to the workstring.
  • One reason for applying such tension to the workstring is to maintain constant pressure and rate of rotation of the cutting tool independent of deflections of the workstring caused by swells (in the case of a floating platform), and/or deflection caused by marine currents. Tension drawn on the workstring substantially reduces such deflection, thereby enhancing performance of the cutter tool 56 while reducing wear on the cutter and the drill string.
  • Springs 42 behave as a solid member when subjected to a tensional force sufficient to place them in a fully collapsed position, e.g., > 35,000 lbs., in the case of the embodiment described above utilizing a 28 disc spring array.
  • Disc springs 42 are axially disposed above lower bearing race 43 on a lower thrust bearing 44.
  • Bearing race 43 serves to establish an even load distribution between springs 42 and lower thrust bearing 44.
  • Bearing 44 permits rotation of swivel cone 37 relative to lower sub 49.
  • a wear collar 46 Disposed immediately below lower thrust bearing 44 is a wear collar 46. Collar 46 defines the largest outside diameter of the tool and thus serves as a physical gauge which prevents the tool from entering an overly small diameter casing.
  • Lower sub 49 is threadedly coupled to mandrel 1 below wear collar 46. Sub 49 forms an attachment means whereby a casing cutter or the like may be coupled to the mandrel.
  • Sub locking nut 47 is secured to mandrel 1 with opposite hand threads to prevent lower sub 49 from accidentally uncoupling from said mandrel 1.
  • Internal retaining ring 48 serves to prevent inadvertent unthreading of sublocking nut 47. Fluid leakage between bore 52 and the annulus of the casing is prevented by seal 45.
  • the operation of the present invention may be described as follows by reference to Figs. 1-21 and especially by reference to Figs. 7-9.
  • the overall spear assembly is threadedly coupled to a standard workstring via female joint 1A or other attachment means conventional in the art.
  • one or more jars may be coupled below the workstring and above the spear.
  • a casing cutter 56 preferably an A-1 big inch cutter or marine cutter as described in U.S. Patent No. 3,468,373, is then threadedly attached to sub assembly 49 via box end 49A.
  • the cutting tool, retrieval tool, jars and workstring are then run in the hole to a desired and predetermined depth.
  • tension is applied to the workstring in an amount to moderately compress disc springs 42 and to straighten the workstring.
  • This tension also serves to "set" the slips 32 in the casing. While the amount of such tension or overpull will vary on the depth of water in which the platform is situated, if any, and the nature of the platform (floating, stationary, etc.), it is desirable that an average overpull value of 10,000 lbs. be maintained on the workstring and the casing spear. The benefit of such overpull has been previously discussed in relation to the efficiency of the cutting tool and the reduction of wear on the workstring. Benefits of overpull also include the positive indication that such tension furnishes when the casing has been severed, thus reducing the chance that the cutting tool 56 will continue to be rotated in the hole after the casing has been cut.
  • the cutting tool 56 is rotated below the spear in a conventional manner to effect a severance of the casing.
  • Pump pressure is maintained during this operation to maintain cutting arms 57 in an extended position and to circulate cuttings out of the wellbore.
  • completion of the cutting operation (and thus severance of the casing) will ordinarily result in the free end 101A of the casing 101 being pulled or jerked a few feet up the wellbore due to the overpull maintained on the workstring. This will obviously result in a noticeable tension drop on the workstring. If a tension release in the workstring is not accomplished, completion of the cut will nevertheless result in a noticeable drop in fluid pressure. Both events evidence that the casing is severed and efforts may be undertaken for retrieval.
  • the jars may be reset while the tool remains in the hole. This is accomplished by first lowering the workstring without rotation while maintaining pump pressure to hold grapple slips 32 in their engaged position. As this occurs, the cutter arms 57 of the casing cutter 56 unfold out into the area where the casing 101 has been severed until the cutter arms 57 come to rest upon the cut fixed end of the casing 101B. Arms 57 then serve to hold the workstring while the jars are reset after which time the jarring procedure is repeated as set forth above.
  • grapple slips 32 which involves reducing pump pressure and lowering the workstring (usually a few inches). This allows the upward bias in spring 15 to overcome the force in hydraulic chamber 54. The assembly is then rotated in right-hand rotation to reengage key 6 in J-groove 51. Casing cutter 56 is then adjusted to a different cutting level whereupon the aforedescribed cutting sequence is repeated.

Landscapes

  • Life Sciences & Earth Sciences (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Engineering & Computer Science (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Fluid Mechanics (AREA)
  • Marine Sciences & Fisheries (AREA)
  • Environmental & Geological Engineering (AREA)
  • Physics & Mathematics (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Earth Drilling (AREA)
  • Placing Or Removing Of Piles Or Sheet Piles, Or Accessories Thereof (AREA)
  • Removal Of Insulation Or Armoring From Wires Or Cables (AREA)
  • Control And Other Processes For Unpacking Of Materials (AREA)
  • Turning (AREA)
EP92104700A 1991-03-19 1992-03-18 Procédé et appareil pour couper et enlever un tubage de puits Expired - Lifetime EP0504848B1 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US67208991A 1991-03-19 1991-03-19
US672089 1991-03-19

Publications (2)

Publication Number Publication Date
EP0504848A1 true EP0504848A1 (fr) 1992-09-23
EP0504848B1 EP0504848B1 (fr) 1995-05-24

Family

ID=24697101

Family Applications (1)

Application Number Title Priority Date Filing Date
EP92104700A Expired - Lifetime EP0504848B1 (fr) 1991-03-19 1992-03-18 Procédé et appareil pour couper et enlever un tubage de puits

Country Status (5)

Country Link
EP (1) EP0504848B1 (fr)
AT (1) ATE123107T1 (fr)
CA (1) CA2062928C (fr)
DE (1) DE69202601T2 (fr)
NO (1) NO303880B1 (fr)

Cited By (23)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
GB2461639A (en) * 2008-07-09 2010-01-13 Smith International One trip casing cutting device
US9567827B2 (en) 2013-07-15 2017-02-14 Downhole Technology, Llc Downhole tool and method of use
GB2543410A (en) * 2015-09-16 2017-04-19 Telfer George Downhole cut and pull tool and method of use
US9631453B2 (en) 2011-08-22 2017-04-25 Downhole Technology, Llc Downhole tool and method of use
US9777551B2 (en) 2011-08-22 2017-10-03 Downhole Technology, Llc Downhole system for isolating sections of a wellbore
US9896899B2 (en) 2013-08-12 2018-02-20 Downhole Technology, Llc Downhole tool with rounded mandrel
US9970256B2 (en) 2015-04-17 2018-05-15 Downhole Technology, Llc Downhole tool and system, and method of use
US10036221B2 (en) 2011-08-22 2018-07-31 Downhole Technology, Llc Downhole tool and method of use
WO2018165069A1 (fr) * 2017-03-09 2018-09-13 Weatherford Technology Holdings, Llc Outil de repêchage de tubage de fond de trou
US10246967B2 (en) 2011-08-22 2019-04-02 Downhole Technology, Llc Downhole system for use in a wellbore and method for the same
US10316617B2 (en) 2011-08-22 2019-06-11 Downhole Technology, Llc Downhole tool and system, and method of use
US10480267B2 (en) 2016-11-17 2019-11-19 The Wellboss Company, Llc Downhole tool and method of use
US10570694B2 (en) 2011-08-22 2020-02-25 The Wellboss Company, Llc Downhole tool and method of use
US10633534B2 (en) 2016-07-05 2020-04-28 The Wellboss Company, Llc Downhole tool and methods of use
CN111075364A (zh) * 2020-01-10 2020-04-28 新疆恒智伟业石油工程技术开发有限公司 一种高温高压油气井清洁完井管柱及工艺
US10801298B2 (en) 2018-04-23 2020-10-13 The Wellboss Company, Llc Downhole tool with tethered ball
US10961796B2 (en) 2018-09-12 2021-03-30 The Wellboss Company, Llc Setting tool assembly
US11078739B2 (en) 2018-04-12 2021-08-03 The Wellboss Company, Llc Downhole tool with bottom composite slip
US11078754B2 (en) 2016-10-10 2021-08-03 Ardyne Holdings Limited Downhole test tool and method of use
WO2022026710A1 (fr) * 2020-07-31 2022-02-03 Baker Hughes Oilfield Operations Llc Outil de traction de fond de trou avec actionnement d'ancre sélectif
US11248428B2 (en) 2019-02-07 2022-02-15 Weatherford Technology Holdings, Llc Wellbore apparatus for setting a downhole tool
US11634965B2 (en) 2019-10-16 2023-04-25 The Wellboss Company, Llc Downhole tool and method of use
US11713645B2 (en) 2019-10-16 2023-08-01 The Wellboss Company, Llc Downhole setting system for use in a wellbore

Citations (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US2991834A (en) * 1957-08-21 1961-07-11 Thomas A Kennard Cutting tool
US3570598A (en) * 1969-05-05 1971-03-16 Glenn D Johnson Constant strain jar
US4047568A (en) * 1976-04-26 1977-09-13 International Enterprises, Inc. Method and apparatus for cutting and retrieving casing from a well bore
EP0155129A2 (fr) * 1984-03-02 1985-09-18 The Red Baron (Oil Tools Rental) Limited Dispositif pour récupérer des tiges de forage d'un puits
GB2194978A (en) * 1986-09-09 1988-03-23 Coal Ind Extracting broken tubes from boreholes
US4811785A (en) * 1987-07-31 1989-03-14 Halbrite Well Services Co. Ltd. No-turn tool

Patent Citations (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US2991834A (en) * 1957-08-21 1961-07-11 Thomas A Kennard Cutting tool
US3570598A (en) * 1969-05-05 1971-03-16 Glenn D Johnson Constant strain jar
US4047568A (en) * 1976-04-26 1977-09-13 International Enterprises, Inc. Method and apparatus for cutting and retrieving casing from a well bore
EP0155129A2 (fr) * 1984-03-02 1985-09-18 The Red Baron (Oil Tools Rental) Limited Dispositif pour récupérer des tiges de forage d'un puits
GB2194978A (en) * 1986-09-09 1988-03-23 Coal Ind Extracting broken tubes from boreholes
US4811785A (en) * 1987-07-31 1989-03-14 Halbrite Well Services Co. Ltd. No-turn tool

Cited By (52)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
GB2461639A (en) * 2008-07-09 2010-01-13 Smith International One trip casing cutting device
US7762330B2 (en) 2008-07-09 2010-07-27 Smith International, Inc. Methods of making multiple casing cuts
GB2461639B (en) * 2008-07-09 2010-10-27 Smith International Methods of making multiple casing cuts
US10570694B2 (en) 2011-08-22 2020-02-25 The Wellboss Company, Llc Downhole tool and method of use
US11136855B2 (en) 2011-08-22 2021-10-05 The Wellboss Company, Llc Downhole tool with a slip insert having a hole
US9631453B2 (en) 2011-08-22 2017-04-25 Downhole Technology, Llc Downhole tool and method of use
US9689228B2 (en) 2011-08-22 2017-06-27 Downhole Technology, Llc Downhole tool with one-piece slip
US9719320B2 (en) 2011-08-22 2017-08-01 Downhole Technology, Llc Downhole tool with one-piece slip
US9725982B2 (en) 2011-08-22 2017-08-08 Downhole Technology, Llc Composite slip for a downhole tool
US10605044B2 (en) 2011-08-22 2020-03-31 The Wellboss Company, Llc Downhole tool with fingered member
US9777551B2 (en) 2011-08-22 2017-10-03 Downhole Technology, Llc Downhole system for isolating sections of a wellbore
US11008827B2 (en) 2011-08-22 2021-05-18 The Wellboss Company, Llc Downhole plugging system
US10900321B2 (en) 2011-08-22 2021-01-26 The Wellboss Company, Llc Downhole tool and method of use
US9976382B2 (en) 2011-08-22 2018-05-22 Downhole Technology, Llc Downhole tool and method of use
US10711563B2 (en) 2011-08-22 2020-07-14 The Wellboss Company, Llc Downhole tool having a mandrel with a relief point
US10036221B2 (en) 2011-08-22 2018-07-31 Downhole Technology, Llc Downhole tool and method of use
US10156120B2 (en) 2011-08-22 2018-12-18 Downhole Technology, Llc System and method for downhole operations
US10494895B2 (en) 2011-08-22 2019-12-03 The Wellboss Company, Llc Downhole tool and method of use
US10214981B2 (en) 2011-08-22 2019-02-26 Downhole Technology, Llc Fingered member for a downhole tool
US10246967B2 (en) 2011-08-22 2019-04-02 Downhole Technology, Llc Downhole system for use in a wellbore and method for the same
US10316617B2 (en) 2011-08-22 2019-06-11 Downhole Technology, Llc Downhole tool and system, and method of use
US10480277B2 (en) 2011-08-22 2019-11-19 The Wellboss Company, Llc Downhole tool and method of use
US10605020B2 (en) 2011-08-22 2020-03-31 The Wellboss Company, Llc Downhole tool and method of use
US9567827B2 (en) 2013-07-15 2017-02-14 Downhole Technology, Llc Downhole tool and method of use
US9759029B2 (en) 2013-07-15 2017-09-12 Downhole Technology, Llc Downhole tool and method of use
US9896899B2 (en) 2013-08-12 2018-02-20 Downhole Technology, Llc Downhole tool with rounded mandrel
US9970256B2 (en) 2015-04-17 2018-05-15 Downhole Technology, Llc Downhole tool and system, and method of use
GB2543410B (en) * 2015-09-16 2019-01-09 Ardyne Holdings Ltd Downhole cut and pull tool and method of use
GB2543410A (en) * 2015-09-16 2017-04-19 Telfer George Downhole cut and pull tool and method of use
US10633534B2 (en) 2016-07-05 2020-04-28 The Wellboss Company, Llc Downhole tool and methods of use
US11180973B2 (en) 2016-10-10 2021-11-23 Ardyne Holdings Limited Downhole test tool and method of use
US11078754B2 (en) 2016-10-10 2021-08-03 Ardyne Holdings Limited Downhole test tool and method of use
US10907441B2 (en) 2016-11-17 2021-02-02 The Wellboss Company, Llc Downhole tool and method of use
US10480267B2 (en) 2016-11-17 2019-11-19 The Wellboss Company, Llc Downhole tool and method of use
US10781659B2 (en) 2016-11-17 2020-09-22 The Wellboss Company, Llc Fingered member with dissolving insert
US10480280B2 (en) 2016-11-17 2019-11-19 The Wellboss Company, Llc Downhole tool and method of use
EP4306767A3 (fr) * 2017-03-09 2024-02-21 Weatherford Technology Holdings, LLC Outil de traction de tubage de fond de trou
US10458196B2 (en) 2017-03-09 2019-10-29 Weatherford Technology Holdings, Llc Downhole casing pulling tool
WO2018165069A1 (fr) * 2017-03-09 2018-09-13 Weatherford Technology Holdings, Llc Outil de repêchage de tubage de fond de trou
EP4119766A1 (fr) * 2017-03-09 2023-01-18 Weatherford Technology Holdings, LLC Outil de traction de tubage de fond de trou
US11078739B2 (en) 2018-04-12 2021-08-03 The Wellboss Company, Llc Downhole tool with bottom composite slip
US11634958B2 (en) 2018-04-12 2023-04-25 The Wellboss Company, Llc Downhole tool with bottom composite slip
US10801298B2 (en) 2018-04-23 2020-10-13 The Wellboss Company, Llc Downhole tool with tethered ball
US10961796B2 (en) 2018-09-12 2021-03-30 The Wellboss Company, Llc Setting tool assembly
US11643892B2 (en) 2019-02-07 2023-05-09 Weatherford Technology Holdings, Llc Wellbore apparatus for setting a downhole tool
US11248428B2 (en) 2019-02-07 2022-02-15 Weatherford Technology Holdings, Llc Wellbore apparatus for setting a downhole tool
US11713645B2 (en) 2019-10-16 2023-08-01 The Wellboss Company, Llc Downhole setting system for use in a wellbore
US11634965B2 (en) 2019-10-16 2023-04-25 The Wellboss Company, Llc Downhole tool and method of use
CN111075364A (zh) * 2020-01-10 2020-04-28 新疆恒智伟业石油工程技术开发有限公司 一种高温高压油气井清洁完井管柱及工艺
GB2612254A (en) * 2020-07-31 2023-04-26 Baker Hughes Oilfield Operations Llc Downhole pulling tool with selective anchor actuation
US11408241B2 (en) 2020-07-31 2022-08-09 Baker Hughes Oilfield Operations Llc Downhole pulling tool with selective anchor actuation
WO2022026710A1 (fr) * 2020-07-31 2022-02-03 Baker Hughes Oilfield Operations Llc Outil de traction de fond de trou avec actionnement d'ancre sélectif

Also Published As

Publication number Publication date
CA2062928C (fr) 2003-07-29
EP0504848B1 (fr) 1995-05-24
NO921068D0 (no) 1992-03-18
NO303880B1 (no) 1998-09-14
CA2062928A1 (fr) 1992-09-20
ATE123107T1 (de) 1995-06-15
DE69202601T2 (de) 1996-02-01
DE69202601D1 (de) 1995-06-29
NO921068L (no) 1992-09-21

Similar Documents

Publication Publication Date Title
US5253710A (en) Method and apparatus to cut and remove casing
EP0504848B1 (fr) Procédé et appareil pour couper et enlever un tubage de puits
US11193343B2 (en) Method of removing a downhole casing
US4294313A (en) Kickover tool
US6419021B1 (en) Deviated borehole drilling assembly
EP0973994B1 (fr) Appareil de retrait d'un article d'un trou de forage
US4703802A (en) Cutting and recovery tool
US6719044B2 (en) Wear bushing running and retrieval tools
CA2192131A1 (fr) Methode de forage avec tubage avec recuperation du mecanisme d'entrainement du trepan
AU1928695A (en) Whipstock apparatus and methods of use
AU2262100A (en) One-trip casing cutting & removal apparatus
GB2406112A (en) Liner running system and method, and swivel
CA2621033C (fr) Ensemble support pour joint a rotule
US20040108739A1 (en) Whipstock retrieving overshot
EP1540129B1 (fr) Train de tiges a marteau de fond de trou comportant un sous-ensemble retractable
EP0391541B1 (fr) Outil pour la récupération d'une douille de protection contre l'usure
EP2971454B1 (fr) Soupape de libération utilisée dans un ensemble tube interne destinée à être utilisée avec un carottier
WO1992015767A1 (fr) Procede de recuperation de tubages de puits utilisant un dispositif d'accrochage interne
AU7250200A (en) Liner sliver retrieval method for multilateral wells

Legal Events

Date Code Title Description
PUAI Public reference made under article 153(3) epc to a published international application that has entered the european phase

Free format text: ORIGINAL CODE: 0009012

17P Request for examination filed

Effective date: 19920429

AK Designated contracting states

Kind code of ref document: A1

Designated state(s): AT BE CH DE DK ES FR GB GR IT LI LU MC NL PT SE

RAP1 Party data changed (applicant data changed or rights of an application transferred)

Owner name: WEATHERFORD U.S. INC.

17Q First examination report despatched

Effective date: 19940325

GRAA (expected) grant

Free format text: ORIGINAL CODE: 0009210

AK Designated contracting states

Kind code of ref document: B1

Designated state(s): AT BE CH DE DK ES FR GB GR IT LI LU MC NL PT SE

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: DK

Effective date: 19950524

Ref country code: AT

Effective date: 19950524

Ref country code: GR

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 19950524

Ref country code: LI

Effective date: 19950524

Ref country code: CH

Effective date: 19950524

Ref country code: BE

Effective date: 19950524

Ref country code: ES

Free format text: THE PATENT HAS BEEN ANNULLED BY A DECISION OF A NATIONAL AUTHORITY

Effective date: 19950524

REF Corresponds to:

Ref document number: 123107

Country of ref document: AT

Date of ref document: 19950615

Kind code of ref document: T

REG Reference to a national code

Ref country code: GB

Ref legal event code: 732E

REF Corresponds to:

Ref document number: 69202601

Country of ref document: DE

Date of ref document: 19950629

ET Fr: translation filed
ITF It: translation for a ep patent filed

Owner name: GUZZI E RAVIZZA S.R.L.

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: SE

Effective date: 19950824

Ref country code: PT

Effective date: 19950824

REG Reference to a national code

Ref country code: CH

Ref legal event code: PL

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: MC

Effective date: 19960318

PLBE No opposition filed within time limit

Free format text: ORIGINAL CODE: 0009261

STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: NO OPPOSITION FILED WITHIN TIME LIMIT

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: LU

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 19960331

26N No opposition filed
NLS Nl: assignments of ep-patents

Owner name: . WEATHERFORD/LAMB, INC.

REG Reference to a national code

Ref country code: FR

Ref legal event code: TP

REG Reference to a national code

Ref country code: GB

Ref legal event code: IF02

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: IT

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES;WARNING: LAPSES OF ITALIAN PATENTS WITH EFFECTIVE DATE BEFORE 2007 MAY HAVE OCCURRED AT ANY TIME BEFORE 2007. THE CORRECT EFFECTIVE DATE MAY BE DIFFERENT FROM THE ONE RECORDED.

Effective date: 20050318

PGFP Annual fee paid to national office [announced via postgrant information from national office to epo]

Ref country code: FR

Payment date: 20110317

Year of fee payment: 20

Ref country code: NL

Payment date: 20110317

Year of fee payment: 20

PGFP Annual fee paid to national office [announced via postgrant information from national office to epo]

Ref country code: GB

Payment date: 20110316

Year of fee payment: 20

Ref country code: DE

Payment date: 20110316

Year of fee payment: 20

REG Reference to a national code

Ref country code: DE

Ref legal event code: R071

Ref document number: 69202601

Country of ref document: DE

REG Reference to a national code

Ref country code: DE

Ref legal event code: R071

Ref document number: 69202601

Country of ref document: DE

REG Reference to a national code

Ref country code: NL

Ref legal event code: V4

Effective date: 20120318

REG Reference to a national code

Ref country code: GB

Ref legal event code: PE20

Expiry date: 20120317

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: DE

Free format text: LAPSE BECAUSE OF EXPIRATION OF PROTECTION

Effective date: 20120319

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: GB

Free format text: LAPSE BECAUSE OF EXPIRATION OF PROTECTION

Effective date: 20120317