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Publication numberUS3282342 A
Publication typeGrant
Publication dateNov 1, 1966
Filing dateNov 21, 1963
Priority dateNov 21, 1963
Publication numberUS 3282342 A, US 3282342A, US-A-3282342, US3282342 A, US3282342A
InventorsMott James D
Original AssigneeC C Brown
Export CitationBiBTeX, EndNote, RefMan
External Links: USPTO, USPTO Assignment, Espacenet
Well packer
US 3282342 A
Abstract  available in
Images(4)
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Claims  available in
Description  (OCR text may contain errors)

Nov. 1, 1966 J. D. MOTT 3,282,342

WELL PACKER Filed Nov. 21, 1963 4 Sheets-Sheet 1 MOTT R.

Nov. 1, 1966 J. D. MOTT 3,282,342

' WELL PACKER Filed Nov. 21, 1963 4 Sheets-Sheet 2 40 336 /Z& 33 c 42 4 Nov. 1, 1966 J. D. MOTT 3,282,342

WELL PACKER Filed Nov. 21, 1965 4 Sheets-Sheet 5 JAM/5 0. MOT7' IN VEN TOR.

J. D. MOTT WELL PACKER Nov. 1, 1966 Filed Nov. 21. 1963 4 Sheets-Sheet 4 JAMES D. 0

II yVZZfiR.

ATTORNE United States Patent 3,282,342 WELL PACKER James D. Mott, Houston, Tex., assignor to C. C. Brown Filed Nov. 21, 1963, Ser. No. 325,435 12 Claims. ((11. 166-120) This invention relates to new and useful improvements in well packer assemblies. More particularly the invention relates to improvements in a well packer assembly having dual anchoring means for anchoring the assembly movement in either direction within a well bore.

Well packer devices having means for locking the device within a well bore or casing and capable of anchoring said device against a pressure differential from either above or below the device have come into general use. These devices require the use of a dual anchoring means, one for anchoring against upward movement and the other for anchoring against downward movement; also, since the well packer device must be removable, problems are presented in connection with the provision of the necessary dual anchoring means which must be set for positive anchoring action and yet must be readily releasable.

Various types of dual anchor, releasable well packer devices have been employed and one example is illustrated in the co-pending application of Cicero C. Brown, Serial No. 784,503, filed January 2, 1959, now abandoned in favor of continuation-in-part application, Serial No. 69,118 which has matured into Patent No. 3,142,338, wherein release of the dual anchoring means is elfected mechanically by rotation of the tubing string on which the assembly is mounted. This is a satisfactory structure and normally accomplishes the purpose but because release is dependent upon the tubing rotation operating a threaded connection, rust and corrosion may jam the threaded connection and make release difficult.

Other types of dual anchor, releasable packer devices have been employed wherein the setting and release of the anchoring means and the sealing element of the device is accomplished hydraulically; one example of this type is shown in the co-pending application of Cicero C. Brown et al., Serial No. 69,168, filed November 14, 1960, now Patent No. 3,122,205. While eliminating the disadvantages inherent in the mechanically releasable type, the hydraulic releasable device, being dependent upon seals in the hydraulic system may give difficulty if the seals fail due to age or for other reasons.

It is therefore one object of this invention to provide a well packer assembly having upper and lower anchoring means which may be set by hydraulic pressure and which is adapted to be released by first releasing the lower anchoring means by hydraulic pressure followed by a direct upward movement of the tubing or pipe on which the assembly is mounted to effect a release of the upper anchoring means to permit removal of the device.

An important object of this invention is to provide a Well packer assembly having upper and lower anchoring means which are settable in response to pressure; the structure being arranged so that the lower anchoring means is adapted to be released responsive to hydraulic pressure but which includes a mechanical means for releasing the packer, the latter being operable in the event' that the hydraulic release fails to function properly, whereby removal of the assembly from the well is assured.

Another object of this invention is to provide a well packer assembly of the character described which may be hydraulically set and which includes a latch mechanism associated with release means for unsetting said assembly; said latch mechanism functioning to permit a mechanical release through manipulation of a well pipe on which the assembly is mounted in'the event the hydraulic unsetting means fails to function properly to unset the assembly.

A further object of the present invention is to provide a well packer assembly which may be hydraulically set and released wherein a latch mechanism is incorporated in the release system which maintains a direct mechanical connection between the assembly and the pipe string in the event the hydraulic release means fails to operate, whereby release may be accomplished mechanically by manipulation of the pipe string.

These and other objects of the present invention will be readily understood from the following explanation and description of the details of the device which are illustrated in the accompanying drawings wherein:

FIGURE 1 is a view partly in section and partly in elevation of a well packer assembly, constructed in accor-dance with the invention and illustrating the various parts in the positions they assume during lowering of the assembly into the well bore.

FIGURE 2 is a similar view showing the packer in the fully set and anchored position in the well bore.

FIGURE 3 is a similar view illustrating the packer in a partially unset position with the lower sealing and anchor elements released.

FIGURE 4 is a similar view showing the packer in fully released position.

FIGURE 5 is a similar view illustrating the packer in a partially unset position showing the anchor elements set and the sealing elements released by rotation of the tubing.

FIGURE 6 is a similar view illustrating the packer fully released by rotation of the tubing.

FIGURE 7 is a horizontal cross-sectional view taken on line 77 of FIGURE 1.

FIGURE 8 is a horizontal cross-sectional view taken on line 8-8 of FIGURE 1.

FIGURE 9 is a horizontal cross-sectional view taken on line 99 of FIGURE 1.

FIGURE 10 is a horizontal cross-sectional view taken on line 1010 of FIGURE 3.

FIGURE 11 is a fragmentary sectional view enlarged from FIGURE 1.

In the drawings the letter T designates the usual well tubing or pipe string which extends downwardly through a well casing 10 within a well bore W. The improved well tool assembly which is herein shown and described as a well packer assembly is generally indicated by the letter P, FIGURE 1, and is connected at the desired point in the tubing or pipe string T. Tubing T is suspended from the usual tubing head which forms part of the surface control equipment (not shown) and the usual flow control valve is disposed in the upper end of the tubing T to control flow therethrough.

The packer assembly P is adapted to be lowered into proper position within the well casing 10 by means of the tubing T and during such lowening the packer is in the unset position. After reaching the desired elevation within the casing, the control head equipment is properly mounted to close in the upper end of said casing and at this time the well is under control. Then the well fluids may be circulated to bring the well in. Thereafter, the packer assembly P may be moved into set or sealing position by blocking off the lower end of the tubing string and by the application of :a hydraulic pres-sure through the bore of the tubing T. After the packer assembly is set, flow of the well fluids from the producing formation below said assembly is upwardly through the tubing T.

When it is desired to remove the packer assembly P and the tubing T, the packer assembly P is moved into a released or unset position by the application of a fluid pressure through the bore of the tubing T. As will be described, the packer assembly is one which can be set by hydraulic pressure and can be released or unset by hydraulic pressure, whereby no movement or manipulation of the tubing T is required to: efiect said release. This provides the very decided advantage of permitting the control head equipment to remain in place at all times so that the well is completely under control both during setting or releasing of the assembly. Additionally, the invention prov-ides a mechanical release means which may be actuated in case the hydraulic release mechanism fails. The arrangement is such that the mechanical rerelease means is actuated by manipulating the tubing T, such manipulation preferably being a right-hand rotation of said tubing.

The well packer assembly includes :a central support or mandrel 12 which comprises an upper tubular section 12a and a lower tubular section 12b. The sections 12a and 12b are connected together in telescoping relationship by relatively coarse buttress thread 13 which are preferably left-hand threads. With such arrangement, when the lower tubular section 121) is held against rotation, a right-hand rotation of upper tubular section 12a will result in moving the sections axially in a direction to separate said sections. The upper section 12a is provided with spaced external upwardly facing shoulders 14 and 14a which are above the threaded area 13 while the section 12b is formed with spaced external downwardly facing shoulders 15 and 15a which are on the lower portion of said section. These shoulders properly locate the units and elements which are mounted on the central support, a will hereinafter be explained.

The threaded connection between the upper tubular section 12a and the lower tubular section 1212 is formed by the male thread 13a on upper tubular section 12a and the female thread 13b formed in arcuate segment members 16 which are confined in windows 17 cut through the upper portion of lower tubular section 12b (FIGURES 8 and 11). There is shown three segment members 16 and three corresponding confining windows 17 to hold them, although any number of segment members and a corresponding number of windows might be used. The segment members 16 are held in threaded engagement with the male thread 13a on upper tubular section 12a by a cylindrical releasing ring 18. Spaced projections 18a on the wall of the bore of releasing ring 18 (FIG. 11) register with opposing spaced projections 16a on the exterior of arcuate segment members 16 and hold the segmented members in threaded engagement with threads 13a on upper tubular section 12a. Spaced grooves 13b formed in the bore of releasing ring 18 are adapted, when ring 18 and segment members 16 are moved relative to each other, to register with the spaced projections 16a on segment members 16 whereby segment members may undergo radially outward movement and disengage their threads 13b from threads 13a of said upper tubular section 12a. FIGURE 10 illustrates the disengagement of the threads. while the engaged position is shown in FIGURE 8.

Releasing ring 18 is connected by a shear pin 19 to each segment member 16 and prevents relative movement of the ring with respect to the segments to maintain the threads 1311 on segment members 16 in engagement with threads 13a on upper tubular section 12a. Shear pin 19 in cooperation with segment members 16, windows 17 and releasing ring 18 comprise a latch mechanism which maintains the mechanical release mechanism in operating condition. As will be explained, shearing of pin 19 will occur when the hydraulic releasing system, which is hereinafter described, is actuated; if for any reason such as seal failure the hydraulic releasing system does not function properly, the ring 18 and segment members 16 remain connected so that the segments maintain threaded connection with the mandrel section to preserve the operability of the mechanical release mechanism. Sufficient space is provided between shoulder 13c on release ring 18 and shoulder 120 on the upper end of lower tubular section 12b to facilitate movement of release ring 18 from the engaged position to the released position. The O-ring seal 26 seals oif between releasing ring 18 and lower tubular section 12b.

Upper anchoring and sealing unit C surrounds upper tubular section 12a of mandrel 12 and comprises upper seal body 21, bearing retainer 22, packing member 24, upper cone member 25, upper slips 26 and upper slip holder 27. Upper seal body 21 is threadedly engaged with bearing retainer 22 and sealed therewith by seal 23 and has a lower depending tubular portion 21a in sliding relation to the exterior of upper tubular section 12a and downwardly facing shoulder 21b engaging the upper portion of packing element 24. The upper portion of upper cone member 25 engages the lower portion of packing element 24. Upper slips 26 and have T hangers 26a which engage T slots 27a in upper slip holder 2'7. Pins 28 extend through upper cone member 25 into slots 210 in portion 21a of upper seal body 21. Upper cone member 25 is provided with inclined surfaces 25a on which upper slips 26 will siide causing upper slips 26 to move outward when moved upward. Upward movement of upper slip holder 27 responsive to pressure as hereinafter more fully described, will cause upper slips 26 to move upward and because of inclined surfaces 25a on upper cone member 25 to move outward to engage the interior of well casing 18. Such movement will also cause upper cone member 25 to move upward thereby compressing packing element 24 between the upper portion of upper cone member 25' and shoulder 21b on upper seal body 21. The exterior of portion 21a of upper seal body 21 will support packing member 24 when compressed whereby compression of packing element 24 will provide a seal against the interior of well casing 113 as shown in FIGURE 2.

Lower anchoring and sealing unit D surrounds lower tubular section 12b of mandrel 12 and comprises lower seal body 29, packing element St lower cone member 31, lower slips 32 and lower slip holder 33. Lower seal body 29 is held in position on lower tubular section 12b by lower connection 34 and ring 35 positioned in groove 36 in the exterior of lower tubular section 12b. Lower seal body 29 is provided with a recess having upward facing shoulder 29a which engages packing element 30. Lower cone member 31 engages the upper portion of packing element 30 and has inclined surfaces 31a engaging lower slips 32 in sliding engagement. Lower slips 32 are provided with T hangers 32a which engage T slots 33a in lower slip holder 33. Lower slip holder 33, as shown in FIGURE 1, is releasably connected to cylinder 3'? by shear pin 38 and has its upper portion 33b within cylinder 37 and sealed thereto by seal 39 for sliding engagement therewith.

Guide pins 49 extend through cylinder 37 into slots 3c in upper portion 33b of lower slip holder 33. Guide pins 41 extend through upper portion 33b of lower slip holder 33 into slots 42 in the exterior of lower tubular section 12b.

Upper anchoring and sealing unit C is restrained at its upper portion and can be actuated by pressure whereby upper slip holder 2'7 will be forced upward and lower anchoring and sealing unit C is restrained at its lower portion and can be actuated by pressure whereby lower slip holder 33 will be forced downward. The pressure causing such movement of the units C and D is transmitted from the interior of mandrel 12 through ports 43 in upper tubular section 12a and ports 44 in the lower tubular sec tion 1211. Since the pressure transmitted through both sets of ports will be the same the actuation of units C and D by hydraulic pressure will not disturb the latch mechanism which comprises segments 15 within windows 17 which are pinned to releasing ring 18 by shear pin 19.

When the latch mechanism remains undisturbed the mechanical release of Well packer assembly P is preserved. The latch mechanism will only be disturbed when the assembly is hydraulically released as hereinafter more fully explained. Such hydraulic release will release the latch mechanism only if the hydraulic release is functioning properly.

In operation the well packer assembly P is made up on tubing T and run to the depth within the casing where it is desired to be set. The usual tubing head equipment (not shown), is then installed at which time the packer is suspended unset Within the casing as in FIGURE 1. Next a setting plug or ball 45 is dropped into the tubing and pumped to its seat S as shown in FIGURE 2. Well fluids under pressure are pumped through tubing T and enter.

the packer through ports 43 and 44 into chambers 46 and 47. It can be seen that this fluid pressure acts on both sides of the releasing ring 18 so that there is no differential or tendency to shear the piri 19. The pressure acts in both chambers 46 and 47 to move the anchor and seal units C and D into set position as shown in FIGURE 2 and as hereinafter more fully explained.

The fluid pressure will be retained within chamber 46 by seal 48 against the exterior surface of upper tubular section 12a and seal 49 which seals the threaded connection between upper slip holder 27 and cylinder 37. The fluid pressure will be retained within chamber 47 by seal 39 against the interior of cylinder 37 and by seal 55 against the exterior of lower tubular section 1211. The fluid pressure contained within chamber 46 and 47 will be suflicient to shear frangible shear pin 38, cause upper slip holder 27 and cylinder 37 to move upward and cause lower slip holder 33 to move downward. The upward movement of upper slip holder 27 forces upper slips 26 upward on upper cone member 25 whereby slips 26 are forced outward into engagement with the interior of casing by inclined surfaces 25a. Slips 26 are constructed to slide upward even though engaged with casing 1th but to resist a downward force. Thus continued upward movement of slip holder 27 will move upper cone member 25 upward thereby compressing packing element 24 against shoulder 21b of upper seal body 21 whereby a packing seal is provided against the interior of well casing 10. The downward movement of lower slip holder 33 forces lower slips 32 downward on lower cone member 31 whereby slips 32 are forced outward into engagement with the interior of wall casing 16 by inclined surfaces 31a. Slips 32 are constructed to slide downward even though engaged with casing 10 but to resist an upward force. Therefore continued downward movement of lower slip holder 33 will move lower cone member 31 downward thereby compressing packing element 30 against shoulder 29a of lower seal body 29 whereby a packing seal is rovided against the interior of well casing 10'. When well packer assembly P is set the release of pressure within chambers 46 and 47 will not release the units C and D as depending tubular portion 21a of upper seal body 21 and shoulder 29a are fixed to slips 26 and 32 which because of their tooth construction will not move when they have been set. Therefore, the units C and D will remain set even after pressure is released. Thereafter ball 45 will be pumped to the surface with the well production through tubing T.

With well packer assembly P being thus set, it will hold a differential pressure exerted either from above or below. If the higher pressure is below well packer assembly P lower anchoring and packing unit D will hold the pressure and maintain the position and if the higher pressure is above well packer assembly P upper anchoring and packing unit C will hold the pressure and maintain the position of the device. Any differential pressure will act against the seals which will transmit the force to the cones further urging the slips into tighter engagement.

If it is desired to release we'll packer assembly P, it may be done hydraulically or mechanically but for any 6 release the production will of necessity have to be ceased. To release the packer hydraulically a special plug F is dropped into the tubing T and pumped into engagement with seat S as shown in FIGURES 4 and 5. Seal 50 on plug F seals against the interior of tubular section 12a. This seal is between the ports 43 and 44 so that fluid under pressure pumped down tubing T above plug F will flow through port 43 into chamber 46. The fluid pressure in chamber 46 will be exerted downward on releasing ring 18 and with no balancing pressure in chamber 47 shear pin 19 will shear because segment members 16 are restrained by threads 13. Release ring 18 will be pumped to the released position where the grooves 18b will register with projections 16a on segment members 16 allowing threads 13b on segment members 16 to disengage from threads 13a on tubular section 12a. The fluid pressure in chamber 46 will force lower tubular section 1212 downward relative to tubular section 12a causing packing member 30 to release. With continued downward movement of tubular section 12b shoulder 15 abuts the end of lower cone member 31 and causes it to be moved from the gripping elements or slips 32 thus releasing the lower anchor and seal unit D. Since pin 19 will not shear unless the hydraulic release mechanism is operating properly the loss of the mechanical release mechanism by the unlatching will not be of con-.

cern as the unlatching assures that the hydraulic release mechanism has operated properly.

With lower anchor and seal unit D in released position, tubing T is lifted at the surface to provide release of upper anchor and seal unit C. This lift is assisted by an upward force due to pressure acting on the difference in areas of seals 48 and 51 on upper tubular sections 12a. The lifting of upper tubular section 12a will cause shoulder 14 on the upper exterior portion of section 12a to engage bearing ring 52 which will lift bearing rings 52 and 53, bearing retainer 22 and upper seal body 21. As upper seal body 21 is lifted packing element 24 will be relieved of compression and will return to its unset position shown in FIGURE 4. Further lifting of upper seal body 21 will cause pins 28 to engage the lower end of slots 21c whereby upper cone member 25 is pulled from "under upper slips 26. This will cause slips 26 to retract thereby completing the release of upper anchor and seal unit C and allow tubing T to be pulled from the hole with well packer assembly P suspended therefrom.

It should be noted that when the well packer assembly P has been completely released that seal 51 will be positioned opposite 'by-pass groove 54. In this position seal 51 will no longer seal between the lower end of upper tubular section 12a and lower tubular section 12b and therefore fluid within chamber 46 and fluid within well tubing T above ports 43 will drain through the bypass thereby created. This provides a bypass for the fluids to drain into the hole below well packer assembly P while the tubing T is being pulled. This by-pass is uncovered whenever well packer assembly P is completely released whether it is done hydraulically or mechanically.

If for any reason, such as the clogging of ports 43 or failure of seals 29, 48, 49, 51 or 56, well packer assembly P cannot be released hydraulically or if it is desired to be released mechanically then this may be accomplished by rotation of tubing T to the right. Lower tubular section 12b is held stationary in reference to rotational movement by pin 41 held by lower slip holder 33 in groove 42. Lower slip holder 33 is in turn held against rotational movement by connection with the set slips 32 and also by pin 40 through cylinder 37 projecting into groove 330, as cylinder 37 is connected through upper slip holder 27 to the set slips. 26. When tubing T is rotated to the right, left-hand threads 13a and 13!: cause lower tubular section 12b to move downward. This downward movement will first move lower seal body 29 downward by ring 35 engaging the lower seal body 29 and the movement of lower seal body 29 will be away from lower cone member 31 allowing packing element 30 to be relieved and return to its uncompressed position as shown in FIGURE 5. Additional movement of lower tubular section 121) will cause shoulder 15 to engage lower cone member 31 pushing it downward and thereby retracting slips 32. In this position lower anchor and seal unit D is fully released. Release of upper anchor and seal unit C is accomplished thereafter by continuing the right-hand rotation of tubing T. Lower tubular section 12b will be held against rotation by its connection (pins 40 and 41) with upper slips 26 which remain set. After unit D is released, the upper end of slot 330 will engage .pin 40 and further downward movement of lower tubular section 12a will be prevented by slips 26. Therefore continued rotation of tubing T will cause upper tubular section 1211 and tubing T to move upward. This upward movement will release packing element 3%) and further upward movement will release upper slips 26 in the same manner as herein'before described in relation to the release of upper anchor and seal unit C subsequent to the hydraulic release of lower anchor and seal unit D. With well packer assembly P completely released tubing T may be pulled from the hole with well packer assembly suspended therefrom.

From the foregoing it may be seen that the present invention provides a well packer assembly having upper and lower anchoring and sealing units, both of which may be set hydraulically responsive to tubing pressure in position within a well bore. The packer assembly provides a latching mechanism with a shear pin which has to be sheared responsive to tubing pressure to unlatch and allow a hydraulic release. The packer assembly further provides the shear pin for the latching mechanism which will prevent release of the latching mechanism in the event of a failure which will prevent proper operation of the hydraulic release. Such latching mechanism will preserve the mechanical release of the well packer device allowing ready removal of the device from the well bore.

The foregoing disclosure and description of the inven tion is illustrative and explanatory thereof and various changes in the size, shape, and materials, as well as in the details of the illustrated construction, may be made within the scope of the appended claims without departing from the spirit of the invention.

1 claim:

1. A well packer assembly for connection in a well bore including,

an upper tubular section,

an upper abutment secured to said upper tubular section,

a lower tubular section,

a lower abutment secured to said lower tubular section,

said upper and said lower tubular sections connected by hydraulically releasable threaded means,

an upper anchor and seal unit mounted below said upper abutment,

a lower anchor and seal unit mounted above said lower abutment,

hydraulically-actuated setting means between said upper and said lower anchor and seal units, and

means supplying fluid pressure to said hydraulicallyactuated means for setting said upper and said lower anchor and seal units,

said hydraulically releasable threaded means being responsive to fluid pressure for disengagement of the threads and to unset said lower anchor and seal unit,

2. A well packer assembly for connection in a well bore according to claim 1 including,

means releasably locking said hydraulically-actuated setting means whereby setting of said upper and said lower anchor and seal units is prevented until said locking means is released,

3. A well packer assembly for connection in a well bore according to claim 1 including,

means releasably locking said hydraulically releasable threaded means preventing disengagement of the threads until said locking means is released.

4. A well packer assembly for connection in a well bore according to claim 1 including,

a by-pass communication and means sealing said by-pass communication until said assembly has been competely released.

5. A well packer assembly for connection in a well bore as set forth in claim 1, together with means nonrotatably connecting the lower anchor and seal unit to said lower tubular section so that when said unit is in set position, the lower tubular section is restrained against rotational movement,

a conduit secured to the upper tubular section and extending to the surface of the well bore whereby rotation may be imparted to said upper tubular section relative to the lower tubular section when the lower anchor and seal section is in set position, and

said relative rotation operating through said threaded means prior to hydraulic release of the threaded means to cause the tubular sections to move in an axial direction which moves the lower abutment away from the upper abutment to thereby release the lower anchor and seal unit from its set position.

6. A well packer assembly adapted to be lowered on a tubing and anchored within a well bore including,

an upper tubular section connected to the tubing and having external threads at its lower portion,

an upper external abutment on the upper portion of the upper section,

an upper anchor and seal unit surrounding the upper section and disposed immediately below the upper abutment,

a lower tubular section, a lower external abutment on said lower sectiton,

a lower anchor and seal unit surrounding said lower section and disposed immediately above said lower abutment,

threaded means engageable with the lower tubular section and having threaded connection with the threads on the upper tubular section,

a piston and cylinder means surrounding the tubular sections and positioned between the upper and lower anchor and seal units and coacting therewith to set the units when said piston and cylinder means is actuated,

communication means through each tubular section establishing communication between the bore of the sections and said piston and cylinder means whereby fluid under pressure from the tubing string and bores of the tubular sections is conducted to the piston and cylinder means to actuate the same to thereby set the anchor and seal units,

means releasably securing said threaded means in its position in threaded connection with the upper tubular section and engageable with the lower tubular section, and

means nonrotatably connecting the lower section to the lower anchor and seal unit to restrain the lower section against rotation when the lower anchor and seal unit is in set position, whereby a rotation of the tubmg and upper section will actuate the threaded connectron between said upper section and the threaded means to move the upper and lower sections axially of each other in a direction to move the lower abutment in a direction to release the lower anchor and seal unit from its set position.

7. A well packer assembly as set forth in claim 6,

0 together with seal means positioned between the lower external portion of the upper tubular section and the upper internal portion of the lower tubular section to direct the fluid under pressure through the communication means during setting, and

by-pass means comprising registering parts on the two tubular section-s when said sections have been moved to a position unsetting the anchor and seal units for by-passing said seal means.

8. A well tool assembly adapted to be lowered on a tubing string and anchored Within a well bore including,

an upper tubular section secured to the tubing string and having an upper external abutment at its upper end,

a lower tubular section having a lower external abutment at its lower end,

threaded means connecting said upper and lower sections against movement in an axial direction with respect to each other,

an upper anchor unit mounted on the upper section and confined against upward movement by the upper abutment,

a lower anchor unit mounted on the lower section and confined against downward movement by the lower abutment,

hydraulically-actuated setting means between said upper and lower anchor units for moving said units in directions toward the abutments to set said units into anchoring position,

mean-s for directing fluid pressure to said hydraulicallyactuated setting means to actuate the same and set the anchor units, and

means for releasably mounting the threadedmeans in a position connecting said upper and lower sections whereby the sections remain in connected position during the setting of said anchor units.

9. A well packer assembly as set forth in claim 8,

together with hydraulically-actuated means for releasing said threaded means from a position connecting the upper and lower sections whereby said sections may thereafter undergo axial movement in a direction moving the upper and lower abutments away from each other to thereby release the lower anchor unit from its respective set position and permit subsequent limited upward movement of the tubing string relative to the upper anchor to release the same.

10. A well packer assembly as set forth in claim 8,

together with hydraulically-actuated means for releasing said threaded means from a position connecting the upper and lower sections whereby said sections may thereafter undergo axial movement in a direction moving the upper and lower abutments away from each other to thereby release the lower anchor unit from its respective set position and permit subsequent limited upward movement of the tubing string relative to the upper anchor to release the same,

means for nonrotatably connecting the lower anchor unit to the lower tubular section to restrain said lower section against rotation when the lower anchor unit is set,

the upper tubular section and the tubing string thereabove being rotatable relative to the lower section to actuate the threaded means to move the upper and lower sections axially with respect to each other in a direction which moves the lower abutment downwardly to unset the lower anchor unit, said rotation of the upper section and tubing being employed for release in the event that there is a malfunction of the hydraulically-actuated releasing means for said threaded means.

11. A well packer assembly as set forth in claim 8,

together with hydraulically-actuated means for releasing and threaded means from a position connecting the upper and lower sections whereby said sections may thereafter undergo axial movement in a direction moving the upper and lower abutments away from each other to thereby release the lower anchor unit from its respective set position and permit subsequent limited upward movement of the tubing string relative to the upper anchor to release the same,

means for nonrotatably connecting both the lower anchor unit and the upper anchor unit to the lower tubular section to restrain said lower section against rotation when either or both of said anchor units are set,

the upper tubular section and the tubing thereabove being rotatable relative to the lower section to actuate the threaded means to move the upper and lower sections in an axial direction which moves the upper and lower abutments away from each other and effects an unsetting of both anchor units, said rotation of the upper section and tubing being employed in the event that there is a malfunction of the hydraulically-actuated releasing means for said threaded means.

12. A well packer assembly as set forth in claim 8,

35 together with hydraulically-actuated means for releasing said threaded means from a position connecting the upper and lower sections whereby said sections may thereafter undergo axial movement in a direction moving the upper and lower abutments away from each other to thereby release the lower anchor unit from its respective set position and permit subsequent limited upward movement of the tubing string relative to the upper anchor to release the same,

a bore-closing element lowerable into the bores of the tubular sections and positioned to direct pressure fluid from the tubing string against said hydraulicallyactuated release means and thereafter against one part of the hydraulically-actuated setting means in a direction to unset said lower anchor unit.

References Cited by the Examiner UNITED STATES PATENTS 2/1964 Brown et al 166--120 X 7/1964 Brown 166120

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Classifications
U.S. Classification166/120, 166/134, 166/212
International ClassificationE21B33/1295, E21B33/12
Cooperative ClassificationE21B33/1295
European ClassificationE21B33/1295
Legal Events
DateCodeEventDescription
Apr 5, 1982ASAssignment
Owner name: HUGHES TOOL COMPANY A CORP. OF DE
Free format text: MERGER;ASSIGNOR:BROWN OIL TOOLS, INC. A TX CORP.;REEL/FRAME:003967/0348
Effective date: 19811214