EP0504848B1 - Method and apparatus to cut and remove casing - Google Patents

Method and apparatus to cut and remove casing Download PDF

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Publication number
EP0504848B1
EP0504848B1 EP92104700A EP92104700A EP0504848B1 EP 0504848 B1 EP0504848 B1 EP 0504848B1 EP 92104700 A EP92104700 A EP 92104700A EP 92104700 A EP92104700 A EP 92104700A EP 0504848 B1 EP0504848 B1 EP 0504848B1
Authority
EP
European Patent Office
Prior art keywords
casing
slips
assembly
casing string
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.)
Expired - Lifetime
Application number
EP92104700A
Other languages
German (de)
English (en)
French (fr)
Other versions
EP0504848A1 (en
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
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 Weatherford Holding US Inc filed Critical Weatherford Holding US Inc
Publication of EP0504848A1 publication Critical patent/EP0504848A1/en
Application granted granted Critical
Publication of EP0504848B1 publication Critical patent/EP0504848B1/en
Anticipated expiration legal-status Critical
Expired - Lifetime legal-status Critical Current

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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 relates to a method and apparatus for cutting and retrieving a casing string.
  • GB-A-2 194 978 discloses a fishing tool for recovering a logging tool from a well.
  • the fishing tool comprises a conical tip on which are mounted wedges.
  • hydraulic fluid causes the wedges to move along the conical tip and, in so doing, move outwardly to engage the logging tool.
  • the finishing tool and logging tool can then be withdrawn from the well.
  • US-A-4 047 568 which forms the basis of the pre-characterising clause of Claim 1, discloses an apparatus for cutting and retrieving a casing string, and adapted to be utilised on a workstring, said apparatus comprising a grapple assembly adapted to be insertable into said casing string, said grapple assembly including a plurality of slips adapted to move between a first position wherein said slips do not substantially engage said casing and a second position in which said slips substantially engage said casing, said slips moveable between said first and second positions at virtually any location within said casing string; a mandrel assembly extending through said grapple assembly, said mandrel assembly being mounted on and rotatable relative to said grapple assembly; and operatively connectable to a cutting assembly.
  • 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 assembly 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.
  • an apparatus for cutting and retrieving a casing string comprising a grapple assembly adapted to be insertable into said casing string, said grapple assembly including a plurality of slips adapted to move between a first position wherein said slips do not substantially engage said casing and a second position in which said slips substantially engage said casing, said slips moveable between said first and second positions at virtually any location within said casing string; a mandrel assembly extending through said grapple assembly, said mandrel assembly being mounted on and rotable relative to said grapple assembly; and operatively connectable to a cutting assembly, characterized by a spring disposed between said mandrel assembly and said grapple assembly whereby, in use, said casing string can be biased upwardly while said casing string is being cut by said cutting assembly.
  • said slips comprise generally circumferentially arranged segments.
  • said segments are disposed about the periphery of a cone arranged generally coaxially with said mandrel assembly.
  • the cone angle of said cone is from 4° to 30°.
  • the segments include a plurality of teeth disposed about their outer contacting surfaces, said teeth having tangential cut angles when viewed in end cross section and axial cut angles when viewed in side cross section.
  • said slips are moveable between said first and second positions in response to fluid pressure.
  • said slips are moveable between said first and second positions in response to fluid pressure within said workstring.
  • said slips can be returned to their first position by reducing fluid pressure in said workstring.
  • the present invention also provides a method for cutting and removing casing string from a wellbore on a single tip of a workstring in to said wellbore, said method using an apparatus in accordance with the invention and comprising the steps of securing said apparatus; securing said cutting assembly to the mandrel assembly of said apparatus; lowering said apparatus and said cutting assembly into said casing string until said cutting assembly is at a depth whereat it is desired to cut said casing string; applying hydraulic pressure in said workstring to actuate the grapple assembly of said apparatus to urge said slips into engagement with said casing string; applying tension to said workstring to place said casing string in tension via said spring; rotating said workstring to rotate said cutting assembly so as to cut said casing string; and after said casing string has been cut, raising said workstring to remove said casing string from said wellbore.
  • said method further comprises the steps of releasing said hydraulic pressure to release slips from engagement with said casing; moving said workstring to place said apparatus and said cutting assembly at a different desired placement within said casing string; and applying hydraulic pressure to cause said slips to engage said casing at said different desired location in said casing string.
  • said method further comprises the steps of attaching a drilling jar to the workstring; and after cutting said casing, actuating said drilling jar to impact said casings.
  • Casing cutting and receiving assembly 100 includes a body or mandrel 1 which includes a 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 a 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. Bearing 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 hearing 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.

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  • 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)
  • Control And Other Processes For Unpacking Of Materials (AREA)
  • Removal Of Insulation Or Armoring From Wires Or Cables (AREA)
  • Placing Or Removing Of Piles Or Sheet Piles, Or Accessories Thereof (AREA)
  • Turning (AREA)
EP92104700A 1991-03-19 1992-03-18 Method and apparatus to cut and remove casing Expired - Lifetime EP0504848B1 (en)

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 EP0504848A1 (en) 1992-09-23
EP0504848B1 true EP0504848B1 (en) 1995-05-24

Family

ID=24697101

Family Applications (1)

Application Number Title Priority Date Filing Date
EP92104700A Expired - Lifetime EP0504848B1 (en) 1991-03-19 1992-03-18 Method and apparatus to cut and remove casing

Country Status (5)

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EP (1) EP0504848B1 (no)
AT (1) ATE123107T1 (no)
CA (1) CA2062928C (no)
DE (1) DE69202601T2 (no)
NO (1) NO303880B1 (no)

Families Citing this family (23)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US7762330B2 (en) 2008-07-09 2010-07-27 Smith International, Inc. Methods of making multiple casing cuts
US10316617B2 (en) 2011-08-22 2019-06-11 Downhole Technology, Llc Downhole tool and system, and method of use
US10246967B2 (en) 2011-08-22 2019-04-02 Downhole Technology, Llc Downhole system for use in a wellbore and method for the same
US10570694B2 (en) 2011-08-22 2020-02-25 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
US9777551B2 (en) 2011-08-22 2017-10-03 Downhole Technology, Llc Downhole system for isolating sections of a wellbore
US10036221B2 (en) 2011-08-22 2018-07-31 Downhole Technology, Llc Downhole tool and method of use
AU2012298866B2 (en) 2011-08-22 2016-11-10 The Wellboss Company, Llc Downhole tool and method of use
US9896899B2 (en) 2013-08-12 2018-02-20 Downhole Technology, Llc Downhole tool with rounded mandrel
WO2016168782A1 (en) 2015-04-17 2016-10-20 Downhole Technology, Llc Tool and system for downhole operations and methods for the same
GB201516452D0 (en) * 2015-09-16 2015-10-28 Telfer George Downhole cutting and pulling tool and method of use
CN108350727A (zh) 2016-07-05 2018-07-31 井下技术有限责任公司 物质组成及其使用
GB2561814B (en) 2016-10-10 2019-05-15 Ardyne Holdings Ltd Downhole test tool and method of use
CN108337898B (zh) 2016-11-17 2020-08-18 井博士有限责任公司 井下工具及使用方法
US10458196B2 (en) * 2017-03-09 2019-10-29 Weatherford Technology Holdings, Llc Downhole casing pulling tool
CA3081865C (en) 2018-04-12 2023-02-28 The Wellboss Company, Llc Downhole tool with bottom composite slip
CA3081968C (en) 2018-04-23 2022-07-19 The Wellboss Company, Llc Downhole tool with tethered ball
WO2020056185A1 (en) 2018-09-12 2020-03-19 The Wellboss Company, Llc Setting tool assembly
US11248428B2 (en) 2019-02-07 2022-02-15 Weatherford Technology Holdings, Llc Wellbore apparatus for setting a downhole tool
CA3154248A1 (en) 2019-10-16 2021-04-22 Gabriel Slup Downhole tool and method of use
AU2020366213B2 (en) 2019-10-16 2023-05-25 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
US11408241B2 (en) * 2020-07-31 2022-08-09 Baker Hughes Oilfield Operations Llc Downhole pulling tool with selective anchor actuation

Family Cites Families (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
EP0154520A3 (en) * 1984-03-02 1986-08-27 Smith International (North Sea) Limited Releasable spear for retrieving tubular members from a well bore
GB2194978B (en) * 1986-09-09 1990-01-10 Coal Ind Tube retracting device
US4811785A (en) * 1987-07-31 1989-03-14 Halbrite Well Services Co. Ltd. No-turn tool

Also Published As

Publication number Publication date
DE69202601D1 (de) 1995-06-29
NO921068D0 (no) 1992-03-18
CA2062928C (en) 2003-07-29
EP0504848A1 (en) 1992-09-23
NO303880B1 (no) 1998-09-14
CA2062928A1 (en) 1992-09-20
ATE123107T1 (de) 1995-06-15
NO921068L (no) 1992-09-21
DE69202601T2 (de) 1996-02-01

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