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Publication numberUS3924678 A
Publication typeGrant
Publication dateDec 9, 1975
Filing dateJul 15, 1974
Priority dateJul 15, 1974
Publication numberUS 3924678 A, US 3924678A, US-A-3924678, US3924678 A, US3924678A
InventorsAhlstone Arthur G
Original AssigneeVetco Offshore Ind Inc
Export CitationBiBTeX, EndNote, RefMan
External Links: USPTO, USPTO Assignment, Espacenet
Casing hanger and packing running apparatus
US 3924678 A
Images(5)
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Description  (OCR text may contain errors)

United States Patent 1191 stone Dec. 9, 1975 CASING HANGER AND PACKING 3,489,436 1/1970 14111516116 285/84 RUNNING APPARATUS 3,492,026 1/1970 Ahlstone 166/87 3,543,847 12/1970 Haeber 166/208 Inventor: Arthur Ahlstone, a, C 3,797,864 3/1974 l-lynes et al. 285/140 [73] Assignee: vetco Offshore Industries, Inc. 3,827,488 8/1974 Plazza et a1 166/87 Ventura, Calif. Primary ExaminerDav1d H. Brown [22] F1led: July 15, 1974 Attorney, Agent, or Firm-Bemard Kriegel [21] Appl. No.2 488,430

[57] ABSTRACT 52 us. c1. 166/120; 166/87; 166/124; Casing, hanger and packing running apparatus is 166/182; 166/20 235/1 2 5/ ered on a tubular running string to locate the casing [51] Int. (:1. E21B 23/06; E21B 33/035 hanger and Packing in a Surrounding housing beneath [58] Field of Search 166/120, 124, 182, 208, a body of Water- The apparatus is responsive to fluid 16 212 37; 2 5 1 4 pressure to expand the packing in the annular space between the hanger body and the housing, and to ac- [56] References Cited tuate a wedge-type lock which retains the packing in UNITED STATES PATENTS the packed off condition. The apparatus is releasable from the casing hanger and the packing for retrieval. 3,468,558 9/1969 Ahlstone 285/18 3,468,559 9/1969 Ahlstone 285/18 30 Claims, 11 Drawing Figures US. Patent D6C. 9, 1975 Sheet 1 of5 3,924,678

U.S. Patent Dec. 9, 1975 Sheet 2 of5 3,924,678

U.S. Patent Dec. 9, 1975 Sheet 3 of5 3,924,678

US Patent Dec. 9, 1975 Sheet 5 of5 3,924,678

CASING HANGER AND PACKING RUNNING APPARATUS The present invention relates to well apparatus, and more particularly to apparatus for running a casing hanger into a wellhead housing and effecting a seal in the region between the hanger body and the surrounding wellhead housing disposed at the upper end of the well bore.

In the drilling and completion of subaqueous or subsea well bores extending downwardly from the floor of a body of water, apparatus has been provided for low ering a casing string through a wellhead housing at the top of the well and into the well bore, and for landing a hanger body secured to the upper end of the casing string in the wellhead housing. A sealing region or space is present between the hanger body and housing. The casing string is cemented in place and a suitable seal structure is then disposed in the sealing region to provide an effective seal between the hanger body and the surrounding wellhead. An apparatus employed in the performance of the above operations is illustrated and described in US. Pat. No. 3,492,026.

In the present invention, the casing hanger and the packing assembly are lowered from a drilling barge or platform into position within the wellhead through use of a running string secured to a running and setting tool apparatus releasably connected to the casing hanger and to the packing assembly. Fluid pressure is operable on the setting and running too] to effect deformation of the packing to form a seal between the housing and the casing hanger and the locking of a wedge-lock device which prevents the packing from recovering and breaking the seal. Thereafter, the running and setting tool is released from the casing hanger and from the packing and wedge-lock for recovery or retrieval to the drilling rig.

In accordance with the present invention the setting and running tool enables the use of fluid pressure applied through the usual kill line or choke of the subsurface blowout preventer to test the efficacy of the packing. Fluid pressure applied through the running string acts on the setting and running tool to set the packing, and the test pressure releases the locking wedge ring from its support and actuates the wedge-lock mechanism.

More particularly, the wedge-lock device for holding the packing packed off comprises a normally expanded resiliently contractable locking ring engageable with a tapered shoulder externally of the casing hanger body and a wedge ring normally held in a position allowing the lock ring to be in its expanded position, but releasable to be moved axially to circumferentially deform the lock ring inwardly into locking co-engagement with a locking recess or tapered shoulder of the casing hanger. The wedge ring and the lock ring have cooperative locking wedge surfaces whereby the locking action is maintained to hold the packing in a packed off condition.

In the event it becomes necessary to release the packing the locking wedge ring can be pulled from its looking position, for example, by the pulling tool which is the subject of my copending application for Pat. Ser. No. 475,586, filed June 3, 1974, for RETRIEVING TOOL FOR WELLHEAD PACKING."

Among the objectives of the invention is the provision of a tool or apparatus for running a casing hanger and a packing and a locking wedge device for holding the packing in a packed off condition in the annular space between a casing hanger and the surrounding wellhead or housing. Another objective of the invention is to provide a running and setting tool operable in response to the pressure of fluid supplied through the running string to initially deform the packing and packoff the annular space and thereafter in response to applied test pressure to actuate the wedge lock to the locked position prior to removal of the setting and'running tool from the casing hanger.

This invention possesses many other advantages, and has other purposes which may be made more clearly apparent from a consideration of the forms in which it may be embodied. These forms are shown in the drawings accompanying and forming part of the present specification. They will now be described in detail, for the purpose of illustrating the general principals of the invention; but it is to be understood that such detailed descriptions are not to be taken in a limiting sense.

Referring to the drawings:

FIG. 1 is a view partly in longitudinal section and partly in elevation showing one form of the running tool and packing apparatus connected to the casing hanger which has been lowered into a subaqueous wellhead housing on a running pipe string, but prior to operation of the running tool;

FIG. 2 is an enlarged fragmentary detail view in longitudinal section, as taken on the line 22 of FIG. 1;

FIG. 3 is a detail transverse section, as taken on the line 33 of FIG. 2;

FIG. 4 is a detail transverse section, as taken on the line 44 of FIG. 2; I

FIG. 5 is a fragmentary view in vertical section, as taken on the line S5 of FIG. 3;

FIG. 6 is a fragmentary view in vertical section, as taken on the line 6-6 of FIG. 3;

FIG. 7 is a fragmentary view in trasverse section, as taken on the line 7-7 of FIG. 5;

FIG. 8 is a view in longitudinal section, generally corresponding with FIG. 2, but showing the packing packed off by fluid pressure applied to the running tool through the running string;

FIG. 9 is a view generally corresponding with FIG. 8, but showing the packing locking means actuated to the locking condition in response to test pressure applied to the housing;

FIG. 10 is a view in longitudinal section, generally corresponding with FIG. 2, showing the packing setting means held in an upper position by fluid pressure; and

FIG. 11 is a view partly in elevation and partly in longitudinal section, showing another form of the running tool.

In the drilling and completion of wells, such as oil and gas wells, form vessels on a body of water, the blowout preventer equipment and casing hanger equipment are located and supported on in a base mounted on the floor of a body of water. The well casing is supported by a wellhead housing, and a marine riser pipe extends downwardly from the vessel to the blowout preventer which is connected to the wellhead housing, all as is well known.

As seen in the drawings, referring first to the embodiment of FIGS. 1 through 7, the wellhead housing H has a casing hanger body C landed therein and supported upon an upwardly facing seat or shoulder 10. The casing hanger C has suitable passages 13 whereby circulating and cementing operations can be conducted in the usual manner by the displacement of cement downwardly through the casing, fluid in the well being displaced upwardly through the passages 13 and through an annular space 14 defined between the cylindrical inner .wall 15 of the housing H and the opposing cylindrical wall 16 of the casing hanger C.

A seal is provided between the opposing cylindrical walls 15 and 16 after the cementing operation is completed by setting a packing P in the annular space 14 in sealing engagement between the opposing cylindrical walls 15 and 16 and securely locking the packing in packed off condition by locking means L. The casing hanger C, the packing means P, and the locking means L are lowered from the drilling vessel on a running and setting tool T which is connected at 17 to a running pipe string R.

The casing hanger C supports at 18 a string of casing 19 which is adapted to extend downwardly into the well and be supported by the casing hanger on a support collar 20 threadedly connected at 21 to the casing hanger body and engageable with an upwardly facing tapered seat 22 in the wellhead housing H. Above the seat 22 the wellhead housing H has a circumferentially extended locking groove 23 adapted, as will be later described, to receive a locking ring 24 above the seating collar 20, whereby the casing hanger is locked against upward movement in the housing H. Typically, the casing hanger C comprises a main body 25 provided with an internal cylindrical bore 26 above which is a left hand thread 27. Another thread 28 extends about the upper end of the upper body section 29 of the casing hanger C. Either of the threads 27 or 28 is adapted for engagement by suitable running tools. In the present case, the running tool T has a lower body section 30 provided with a thread 31 engaged with the internal left hand thread 27 within the casing hanger C, whereby, as will be later described, the casing hanger with the casing 19 depending therefrom can be lowered into the well and seated in the wellhead housing H on the running tool T. The body section 30 of the tool T also has a cylindrical section 30a provided with side ring seals 32 engageable in the bore 26 of the casing hanger C.

The running tool T not only supports the casing hanger C, but also the packing means P and the locking means L as more particularly shown in FIG. 2.

The packing P includes a lower abutment ring or collar 33 and an annular body 34 of resiliently deformable elastomeric sealing material connected by a dove-tailed connection 35 to the lower ring 33, and by a corresponding upper dove-tailed connection 36 with a packing support sleeve 37. The packing body 34 is deformable outwardly and inwardly into sealing engagement with the opposed cylindrical walls 15 and 16, respectively, of the housing H and the casing hanger C upon axial deformation of the packing body. Such a packing is more fully disclosed in US. Pat. No. 3,797,864, granted Mar. 18, 1974, for COMBINED METAL AND ELASTOMER SEAL.

The packing support sleeve 37, at a location above the packing 34, has an internal upwardly facing shoulder or seat 38 on which rests a split resilient lock ring 39 which is normally of such diameter as to pass downwardly over the upwardly extended annular section 29 of the casing hanger C. This casing hanger section 29 is undercut on its outer periphery at 40 to provide a groove, or, as shown in this specific embodiment, a downwardly and inwardly tapered annular surface adapted to receive the correspondingly downwardly and inwardly tapered side 41 of the lock ring 39, when the latter is deformed inwardly from its normally expanded condition of FIG. 2 to its contracted or locking position of FIG. 9. In order to effect locking contraction of the lock ring 39 a lock ring actuator 42 is provided. This lock ring actuator is in the form of an annular wedge having an outer cylindrical wall 43 slidably disposed within the packing support sleeve 37 and an inner downwardly and outwardly tapered wedge surface 44 opposed to and engageable with the outer downwardly and outwardly tapered surface 45 of the lock ring 39, whereby upon downward .movement of the actuator 42 within the support sleeve 37 the lock ring 39 will be wedged or cammed circumferentially inwardly to the locking position with the locking surface 40 of the casing hanger C. The angles of the surfaces 44 and 45 of the actuator ring 42 and the lock ring 39, respectively, are selected to be locking wedge angles, so that once the wedge action has deformed and locked the lock ring in place, the actuator 42 must be forcefully retracted before the lock ring can be released. Accordingly, the actuator 42 has an internally undercut neck 46 at its upper extremity and an internal fishing or retrieving shoulder 47 adapted to be engaged by a pulling tool, such as the wedge lock pulling tool of my copending application Ser. No. 475,586, filed June 3, 1974, for RETRIEVING TOOL FOR WELLl-IEAD PACKING.

During the lowering of the packing and the locking assembly through the riser pipe and into the wellhead housing H, and during the initial packing off of the packing P, the actuating wedge 42 is held in an upper inoperative position by releasable means such as one or more shear pins 48 which interconnect the actuator 42 to the packing support sleeve 37.. These shear pins are selected so that they will retain the actuator 42 in the initial position until the packing is fully set, and a downward force is applied to the actuating wedge 42 to shear the pins 48 enabling downward locking movement of the actuator wedge 42.

Referring more particularly to the running tool T, it has a tubular neck 50 extending upwardly from a makeup shoulder 51 above the lower body section 30. An inner body section or cylinder 52 extends upwardly from the neck 50 and has the threaded connection 17 with the running string R. An outer body assembly 53 is carried by the inner body section 52 and includes a supporting sleeve and cylinder head 54 fixedly or threadedly connected at 54a to the inner body 52, and an external cylinder sleeve 55 which carries a packing actuator sleeve 56 threaded at 57 to the outer cylinder sleeve 55.

The cylinder head 54 has an inner side ring seal 58 engaged with the inner body 52 and an outer side ring seal 59 engaged within an upper bore 60 of the outer cyIinder sleeve 55 above a number of circumferentially spaced upper ports 61 which extend from the bore 62 in the tool inner body into the space or piston chamber 63 defined between the inner body section 52 and the outer cylinder sleeve 55. At the lower end of the chamber 63 the body section 52 has a side ring seal 64 slidably engaged with the inner cylindrical wall of the cylinder sleeve 55 below a number of circumferentially spaced lower ports 65 which also extend between the body bore 62 and the chamber 63. Reciprocable in the chamber 63 is an annular piston 66 carried by the cylin-' der sleeve 55 and having a side ring seal 67 slidably engaging the body section 52.

As previously indicated, fluid circulation and casing cementing operations are performed by displacing fluid and cement downwardly through the running string R and the tool T. In order to protect the piston chamber 63 from dirty or cementitious fluids, a protector sleeve 68 is disposed in the body bore 62 and spans the ports 61 and 64 to normally close the ports. This protector sleeve has an external seating shoulder 69 engageable with an internal shoulder in the bore 62 and an upper seal ring 70 engageable in the bore 62. When it is desired to operate the tool T, as will be later described, the protector sleeve 68 is pulled by the usual wireline fishing tool (not shown) having gripping means engageable with an internal fishing shoulder 71 adjacent to the upper end of the sleeve 68.

As previously indicated, the outer body assembly 53 includes the packing actuator sleeve 56 which has a cylindrical skirt portion 75 extending downwardly and disposed in abutting engagement with the upper end 76 of the packing supporting sleeve 37. This upper end 76 of the sleeve 37 is releasably connected to the lower end of the cylinder sleeve 55 by a number of circumferentially spaced shear pins 77a which normally connect the packing supporting sleeve 37 to the cylinder sleeve 55 for simultaneous movement as the cylinder sleeve 55 moves downwardly in response to the application of fluid under pressure to the piston chamber 63 above the piston 66, as will be later described. Disposed between the packing actuator sleeve 56 and the outer periphery of the outer cylinder sleeve 55 is a differential actuator piston 77 of annular form, this piston having an upper section 78 of major diameter disposed between the inner cylindrical wall 79 of the sleeve 56 and the outer cylindrical wall 80 of the cylinder sleeve 55 and a lower minor diameter section 81 disposed between the actuator sleeve wall 79 and an enlarged diameter section 82 of the cylinder sleeve 55. Depending from the differential piston 77, as best seen in FIGS. 2, 3 and 11, is a plurality of circumferentially spaced fingers 83 which extend downwardly through correspondingly circumferentially spaced and longitudinally extended slots 84 formed on the outer periphery of the cylinder sleeve 55. The lower ends 85 of the fingers 83 extend into abutting engagement with the upper end of the locking wedge ring 42 so that upon downward actuation of the piston 77 the fingers 83 will be forced downwardly, forcing the wedge ring 42 downwardly, to lock the packing in sealing condition, as will be later described.

A pressure chamber 86 is defined between the actuator piston 77 and the cylinder sleeve 55 between an upper seal ring 87 and a lower seal ring 88, respectively, disposed between the upper large end section 78 of the piston 77 and the smaller diameter lower section 81 of the piston 77 and the cylinder sleeve 55, whereby a differential area 89 is provided on the piston 77, facing downardly and exposed to pressure in the chamber 86 to normally hold the piston 77 in its upper position. The piston 77 is adapted to be actuated downwardly under the influence of pressure fluid action on its larger upper end area which is exposed through a suitable number of apertures 90 in the upper end of the actuator sleeve 56. Such pressure fluid is applied to the upper end of the piston 77, as will be later described.

As previously indicated, the casing hanger and the packing P are landed in the wellhead housing H in the initial condition as seen in FIGS. 1 through 7, and thereafter fluid is circulated downwardly through the running string R, the casing 19, and thence upwardly through the passages 13, bypassing the running tool T. To facilitate such fluid bypass the running tool T is provided with a number of circumferentially spaced bypass flow passages. In the present form, such flow passages are formed at 91 through the cylindrical sleeve 55. One of such flow passages 91a as seen in FIG. 3, 5 and 7 is plugged by a suitable plug 92 at its upper end and has a filler valve 93 at its lower end, whereby the passage 91a is adapted, while the apparatus is on the drilling rig platform, to be filled with a compressible fluid, such as air, such pressurized air finding access through a radial port 94 in the cylinder sleeve 55 to the previously de scribed chamber 86, so as to act upwardly on the differential area 89 of the actuator piston 77 to hold the latter in its upper position. It is apparent that the air in the chamber 86 acts as an air spring which must be overcome before the actuator piston 77 can be move downwardly.

In operation, when it is desired to set the packing P, as shown in FIG. 8, and lock the packing in place as shown in FIG. 9, the apparatus functions as follows. Initially, the cylinder sleeve 55 is held in the upper position of FIG. 2 by a suitable number of shear pins 55a which releasably interconnect the cylinder sleeve 55 with the cylinder head 54. Following the conduct of the cementing operations, the protector sleeve 68 is pulled, and a dart 100, as seen in FIG. 8, is dropped into the running string R and lands upon the shoulder 69 formed within the body shore 62. The dart has suitable side ring seals 101 sealingly engageable in the bore 62 below an annular groove 102 formed in the body of the dart and communicating with a flow passage 103 which opens at the top of the dart. When the dart is seated the groove 102 communicates with the ports 61 through the body section 52 above the actuator piston 66. Thus, with the dart seated fluid pressure supplied through the running string R is applied to the piston 66 in the piston chamber 63 to force the cylinder sleeve 55 downwardly after shearing the upper shear pins 55a. The cylinder sleeve 55 and the actuating sleeve 56, together with the packing supporting sleeve 37 move downwardly simultaneously to the position of FIG. 8, at which the packing sleeve 34 is deformed into sealing engagement between the opposing housing and hanger walls 15 and 16. As the packing sleeve 34 is being deformed, the lower ring 33 thereon engages and cams the casing hanger locking ring 24 outwardly into the locking groove 23.

With the apparatus in this condition a preliminary pressure check can be made by closing the blowout preventer on the running string R and supplying test pressure fluid to the wellhead housing H through the usual kill or choke line of the blowout preventer. This test pressure is applied to the packing while the initial pre-Ioad which deformed the packing is maintained by holding the pressure in the running string which is applicable to the packing actuator piston 66.

As the test pressure is increased, the pressure acts on the differential area of the locking actuator sleeve or piston 78 overcoming the pressure in chamber 86 acting upwardly on the piston area 89, and overcoming the shear pins 48 which connect the locking wedge or actuator ring 42 to the packing support sleeve 37. When the pins 48 are sheared, the locking wedge ring 42 is shifted downwardly to the position of FIG. 9, from the position of FIG. 8. The opposed wedge surfaces 44 and 45 onthe wedgering and the lock ring 39 deform the split lock ring circumferentially inwardly into the locking position in engagement with the locking shoulder or surface 40 on the casing hanger C, whereby the packing means P is securely locked in place by the locking means L.

Thereafter, the running tool T is disconnected from the casing hanger by right hand rotation of the running string R which will break left hand threaded connection 27, 31 between the casing hanger and the body of the tool. The running string and tool are then lifted. When the inner body neck 50 shoulders against and picks up the actuator piston 66, the outer cylinder sleeve 55 will be pulled free from the packing support sleeve 37, as the shear pins 77a are sheared.

.It may occur that, due to cement or other material being present in the annular space 14 between the casing hanger and the wellhead housing, the packing does not properly seal and resist pressure testing. Under these circumstances, itmay be desirable to pull the packing means free from the annulus 14, and possibly retrieve the running tool T with the packing thereon to allow remedial washing or cleaning operations.

To accomplish this a release dart 200 is provided, as shown in FIG. 10. The dart 200, like the dart 100, has a retrieving head adapted to land on the shoulder 69 in the bore of the tool body section 52. The release dart 200 is elongated so as to span the ports 61 and 65 in the body section 52. Above the ports 61, the dart 200 has upper side ring seals 201 sealingly engageable in the body in the body bore 62. Below the lower ports 65, the dart 200 has side ring seals 202 sealingly engaged in the body bore 62. Between the ports 61 and 65, the dart 200 has intermediate side ring seals 203 which sealingly engage in the body bore 62. An annulus 204 in the dart 200 communicates with the lower body ports 65, and a passage 205 leads from the annulus 204 to the top of the dart, whereby pressure fluid supplied through the running string is applicable to the piston chamber 63 below the actuator piston 66 of the cylinder sleeve 55. To enable the exhaust of fluid from the chamber 63 above the piston 66, the dart 200 has another annulus 206 communicating with the upper body ports 61, and a discharge passage 207 leads from the annulus 206 downwardly to the bottom of the dart.

Upon completion of remedial or washing work, the tool T is again operable, upon removal of the dart 200 and seating of the dart 100, to set and lock the packing means in place in the annulus 14, after pressure testing.

It will be recognized that the threaded joint 27, 31 between the running tool lower body 30 and the casing hanger C is a connection which is easily released by rotation of the running string R. In FIG. 11 a modified connector means 300 is shown for connecting the tool T with the casing hanger C. This connection means 300 is releasable without requiring rotation of the running string R.

In FIG. 11 the casing hanger C is landed in the wellhead housing. The connector means 300 includes a lower conical nose 301 threadedly connected at 302 to a reduced section 303 extending downwardly from the setting tool body. The lower nose 301 has an upstanding hollow body 34 which carries the side ring seals 305 sealingly engageable in the bore 26 of the casing hanger C. At its upper end, the body section 304 has one or more longitudinally extended keys 306 engageable in a key way 307 extending through the internal threads 27 of the casing hanger. Above the seals 305 the body section 304 has a number of circumferentially spaced radial windows or openings 308 in which are reciprocable a corresponding number of latching dogs 309. These latching dogs are adapted, upon outward movement, to engage in a locking groove 310 formed in the casing hanger body. The locking groove 310 would b'ewused for the locking ring or lockdown dogs of a tubing hanger, as is well known, to lock it to the casing hanger or such groove may be used when running the hanger on the running tools. A piston sleeve 311 is disposed about the tool body section 303 and has a central flange 312 engageable with the dogs 309 to hold them outwardly in the locking position of FIG. 11.

A lower piston chamber 313 is formed below the piston sleeve 311 by a side ring seal 314, engaged between the outer periphery of the piston sleeve and the body 304 of the connector, and a seal 315 in the threaded connection 302. The tool body section 303 has a lower plurality of circumferentially spaced ports 316 leading from the tool body bore 62 to the annular clearance 317 between the piston sleeve 311 and the tool body section 303. An upper piston chamber 318 is formed by an upper seal ring 319 between the bodies 303 and 304, a lower seal ring 320, between-the body 304 and the piston sleeve 311, and another seal ring 321 between the body 303 and the inside diameter of the piston sleeve 311. An upper plurality of circumferentially spaced ports 322 lead from the body bore 62 to the upper chamber 318.

During the running and cementing operations previously described, the ports 316 and 322 are closed by a downward extension 368 of the protector sleeve 68. When the protector sleeve 68 is pulled, the ports 316 and 322 are open. Since the piston sleeve 311 is a balanced piston, its position is not affected by fluid entering both piston chambers 313 and 318.

As is apparent, without requiring further description or illustration, when it is desired that the running tool T be released from the casing hanger c following setting and locking of the packing P in the annulus 14, a dart (not shown) can be landed on a seating shoulder 323, such dart having suitable seals and porting to allow discharge from the upper piston chamber 318 and to enable the application of operating fluid pressure to the lower chamber 313, so that the piston sleeve 311 will be shifted to an upper position at which the dogs 309 are free to be shifted inwardly by camming surface 324 when the tool is pulled upwardly.

I claim:

1. Apparatus for effecting a seal between a wellhead and a hanger disposed in the wellhead for supporting a tubular pipe string extending into the well bore comprising; a running tool having a body structure connectable to a running pipe string; means for releasably connecting said body structure to said hanger; packing means; means releasably connecting said packing means to said body structure to enable said packing means to be set in sealing relation to said hanger; locking means for locking said packing means in sealing relation to said hanger including a locking member actuat'able longitudinally to lock said locking means; said body structure having means responsive to fluid pressure supplied through said running pipe string to set said packing means in sealing relation to said hanger; and said body structure having means responsive to fluid pressure outside of said running pipe string for actuating said locking member longitudinally.

2. Apparatus as defined in claim 1, wherein said means for releasably connecting said body structure to said hanger includes a threaded connection.

3. Apparatus as defined in claim 1, wherein said means for releasably connecting said body structure to said hanger includes latch means carried by said body structure including latch elements engageable with said hanger, and means for releasing said latch elements.

4. Apparatus as defined in claim 1, wherein said means for relaeasably connecting said body structure to said hanger includes latch means carried by said body structure including latch elements engage latch elements engageable with said hanger, and means for releasing said latch elements in response to fluid pressure supplied through said running pipe string.

5. Apparatus as defined in claim 1, wherein said locking means comprises a resiliently deformable locking ring engageable with a downwardly facing surface of said hanger upon deformation of said locking ring to lock said packing means to place.

6. Apparatus as defined in claim 1, wherein said locking means comprises a resiliently deformable locking ring engageable with a downwardly facing surface of said hanger upon deformation of said locking ring to lock said packing means in place, said locking member and said locking ring having means for deforming said locking ring upon longitudinal movement of said locking member.

7. Apparatus as defined in claim 1, wherein said locking means comprises a resiliently deformable locking ring engageable with a downwardly facing surface of said hanger upon deformation of said locking ring to lock said packing means in place, said locking member being in the form of a wedge shaped ring for deforming said locking ring upon longitudinal movement of said locking member.

8. Apparatus as defined in claim 1, wherein said locking means comprisesa resiliently deformable locking ring engageable with a downwardly facing surface of said hanger upon deformation of said locking ring to lock said packing means in place, said locking member being in the form of a wedge shaped ring for deforming said locking ring upon longitudinal movement of said locking member, said locking ring and said locking member having coengageable locking wedge surfaces.

9. Apparatus as defined in claim 1, said packing means comprising a support sleeve, a resilient elastomeric' packing element supported on said support sleeve, means releasably connecting said locking member to said support sleeve, and said locking means including a resiliently deformable lock ring carried by said support sleeve and engageable by said locking member to be deformed thereby.

10. Apparatus as defined in claim 1, said packing means comprising a support sleeve, a resilient elastomeric packing element supported on said support sleeve, means releasably connecting said locking member to said support sleeve, and said locking means including a resiliently deformable lock ring carried by said support sleeve and engageable by said locking member to be deformed thereby, said locking member and said lock ring having companion wedge surfaces formed on locking wedge angles for deforming said lock ring upon longitudinal movement of said locking member.

11. Apparatus as defined in claim 1, wherein said means responsive to fluid pressure supplied through said running pipe string to set said packing means in sealing relation to said hanger includes piston means longitudinally shiftable in said body structure.

12. Apparatus as defined in claim 1, wherein said meansresponsive to fluid pressure supplied through said running pipe string to set said packing means in sealing relation to said hanger includes piston means longitudinally shiftable in said body structure, and means initially holding said piston means against movement relative to said body structure.

13. Apparatus as defined in claim 1, wherein said means responsive to fluid pressure supplied through said running pipe string to set said packing means in sealing relation to said hanger includes a cylinder sleeve carried by said body structure, said cylinder sleeve and said body structure having means defining a piston chamber, a piston on said cylinder sleeve exposed to the pressure of fluid in said piston chamber,

and passage means for establishing communication between said piston chamber and said running pipe string.

14. Apparatus as defined in claim 1, wherein said means responsive to fluid pressure supplied through said running pipe string to set said packing means in sealing relation to said hanger includes a cylinder sleeve carried by said body structure, said cylinder sleeve and said body structure having means defining a piston chamber, a piston on said cylinder sleeve exposed to the pressure of fluid in said piston chamber, and passage means for establishing communication between said piston chamber and said running pipe string, said means responsive to fluid pressure outside said running pipe string for actuating said locking member longitudinally including an actuator piston engageable with said locking member.

15. Apparatus as defined in claim 1, wherein said means responsive to fluid pressure supplied through said running pipe string to set said packing means in sealing relation to said hanger includes a cylinder sleeve carried by said body structure, said cylinder sleeve and said body structure having means defining a piston chamber, a piston on said cylinder sleeve exposed to the pressure of fluid in said piston chamber, and passage means for establishing communication between said piston chamber and said running pipe string said means responsive to fluid pressure outside said running pipe string for actuating said locking member longitudinally including an actuator piston engageable with said locking member, said cylinder sleeve having means supporting said actuator piston for longitudinal movement relative to said cylinder sleeve.

16. Apparatus as defined in claim 1, wherein said means responsive to fluid pressure supplied through said running pipe string to set said packing means in sealing relation to said hanger includes a cylinder sleeve carried by said body structure, said cylinder sleeve and said body structure having means defining a piston chamber, a piston on said cylinder sleeve exposed to the pressure of fluid in said piston chamber, and passage means for establishing communication between said piston chamber and said running pipe string, said means responsive to fluid pressure outside said running pipe string for actuating said locking member longitudinally including an actuator piston engageable with said locking member, said cylinder sleeve having means supporting said actuator piston for longitudinal movement relative to said cylinder sleeve, and means for normally holding said actuator piston against such longitudinal movement.

17. Apparatus as defined in claim 1, wherein said means responsive to fluid pressure supplied through said running pipe string to set said packing means in 1 1 sealing relation to said hanger includes a cylinder sleeve carried by said body structure, said cylinder sleeve and said body structure having means defining a piston chamber, a piston on said cylinder sleeve exposed to the pressure of fluid in said piston chamber, and passage means for establishing communication between said piston chamber and said running pipe string, said means responsive to fluid pressure outside said running pipe string for actuating said locking member longitudinally including an actuator piston engageable with said locking member, said cylinder sleeve having means supporting said actuator piston for longitudinal movement relative to said cylinder sleeve, said cylinder sleeve and said actuator piston having means defining a chamber containing a compressible fluid for normally holding said actuator piston against such longitudinal movement.

18. Apparatus as defined in claim 1, wherein said means responsive to fluid pressure outside said running pipe string for actuating said locking member longitudinally including an actuator piston engageable with said locking member.

19. Apparatus as defined in claim 1, wherein said means responsive to fluid pressure supplied through said running pipe string to set said packing in sealing relation to said hanger including piston means carried by said body structure, said body structure having passage means for controlling the application of fluid pressure to said piston means.

20. Apparatus as defined in claim 1, said means responsive to fluid pressure in said running pipe string to set said packing in sealing relation to said hanger including a cylinder sleeve shiftably carried by said body Structure, said packing means including a support sleeve, said means releasably connecting said packing means to said body structure connecting said support sleeve to said cylinder sleeve.

21. Apparatus as defined in claim 1, said means responsive to fluid pressure in said running pipe string to set said packing in sealing relation to said hanger including a cylinder sleeve shiftably carried by said body structure, said packing means including a support sleeve, said means releasably connecting said packing means to said body structure connecting said support sleeve to said cylinder sleeve annd including shear pins shearable upon removal of said body structure from said hanger.

'22. Apparatus as defined in claim 1, wherein said body structure comprises an inner body having seal means engageable in said casing hanger.

23. Apparatus as defined in claim 1, wherein said means responsive to fluid pressure supplied through said running pipe string to set said packing means in sealing relation to said hanger includes means responsive to pressure fluid supplied through said running pipe string to pull said packing means from sealing relation to said hanger.

24. A running and operating tool for setting a packing and locking assembly between a wellhead housing and a hanger for a tubular well conduit comprising: a body having means at its upper end connectable to a running pipe string; means at the lower end of said body; means adapted to releasably connect said lastmentioned means to the hanger; a cylinder sleeve reciprocable relative to said body; said cylinder sleeve and said body having means defining a piston chamber; a piston on said cylinder sleeve and in said piston chamber; passage means for admitting fluid under pressure to said piston chamber; said cylinder sleeve having means enabling releasable connection with said packing means; and actuator means responsive to fluid pressure outside of said too] including an actuator member shiftable longitudinally of said cylinder sleeve.

25. A running and operating tool as defined in claim 24, including means for initially holding said actuator member against movement relative to said cylinder sleeve.

26. A running and operating tool as defined in claim 24, including means for initially holding said actuator member against movement relative to said cylinder sleeve including means on said actuator member and said cylinder sleeve providing a pressure chamber, said actuator member having an area in said pressure chamber exposed to the pressure therein.

27. A running and operating tool as defined in claim 24, including means for initially holding said actuator member against movement relative to said cylinder sleeve including means on said actuator member and said cylinder sleeve providing a pressure chamber, said actuator member having an area in said pressure chamber exposed to the pressure therein, said cylinder sleeve having inlet means for supplying pressure to said pressure chamber.

28. A running and operating tool as defined in claim 24, wherein said body has inlet passages at both sides of said piston.

29. A running and operating tool as defined in claim 24, including shearable means releasably connecting said cylinder sleeve to said body.

30. A running and operating tool as defined in claim 29, wherein said means defining said piston chamber comprises a cylinder head threaded on said body, said cylinder sleeve and said body and cylinder being sealingly and slidably engaged at opposite sides of said piston, said actuator member including a differential area piston sleeve disposed about said cylinder sleeve, and an outer sleeve disposed about said cylinder sleeve and threaded thereon.

UNITED STATES PATENT OFFICE CERTIFICATE OF CORRECTION PATENT NQ. 3,924,678 D ED December 9, 1975 INVENTOR('S) ARTHUR G. AHLSTONE I s certified that error appears in the above-identified patent and that said Letters Patent are hereby corrected as shown below:

. Column 1., line 43: change "applied" to --suppl1ed--.

Column 2, line 55: change "form" to --from--.

line 57: cancel "in". 0

Column 5, line 7: change "64" to --65--.

Column 6, line 30: change "shore" to --bore--.

Column, 7, line 62: change "34" to --304-. 0

Signed and Scaled this Thirteenth Day of July 1976 EMI 6 Arrest.

Rum c. mson c. MARSHALL DANN Aflesling 0ffi'". Commissioner of Patents and Trademarks

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Referenced by
Citing PatentFiling datePublication dateApplicantTitle
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US8276671 *Apr 1, 2010Oct 2, 2012Vetco Gray Inc.Bridging hanger and seal running tool
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US8678093 *Apr 14, 2011Mar 25, 2014Aker Subsea LimitedInsertion of a pack-off into a wellhead
US8727025 *Sep 14, 2010May 20, 2014Baker Hughes IncorporatedDownhole tool seal arrangement and method of sealing a downhole tubular
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Classifications
U.S. Classification166/120, 285/84, 166/124, 285/18, 166/208
International ClassificationE21B33/043, E21B33/03
Cooperative ClassificationE21B33/043
European ClassificationE21B33/043
Legal Events
DateCodeEventDescription
Mar 16, 1987ASAssignment
Owner name: VETCO GRAY INC.,
Free format text: MERGER;ASSIGNORS:GRAY TOOL COMPANY, A TX. CORP. (INTO);VETCO OFFSHORE INDUSTRIES, INC., A CORP. (CHANGED TO);REEL/FRAME:004748/0332
Effective date: 19861217
Feb 5, 1987ASAssignment
Owner name: CITIBANK, N.A.,
Free format text: SECURITY INTEREST;ASSIGNOR:VETCO GRAY INC., A DE. CORP.;REEL/FRAME:004739/0780
Effective date: 19861124
May 1, 1986AS02Assignment of assignor's interest
Owner name: VETCO OFFSHORE INDUSTRIES, INC., 7135 ARDMORE ROAD
Owner name: VETCO OFFSHORE, INC., A CORP. OF DE.
Effective date: 19860421
May 1, 1986ASAssignment
Owner name: VETCO OFFSHORE INDUSTRIES, INC., 7135 ARDMORE ROAD
Free format text: ASSIGNMENT OF ASSIGNORS INTEREST.;ASSIGNOR:VETCO OFFSHORE, INC., A CORP. OF DE.;REEL/FRAME:004572/0533
Effective date: 19860421
Sep 29, 1982ASAssignment
Owner name: VETCO OFFSHORE, INC. 5740 RALSTON ST.VENTURA,CA.93
Free format text: ASSIGNMENT OF ASSIGNORS INTEREST.;ASSIGNOR:VETCO INC.;REEL/FRAME:004056/0858
Effective date: 19820922