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Publication numberUS3306363 A
Publication typeGrant
Publication dateFeb 28, 1967
Filing dateApr 22, 1964
Priority dateApr 22, 1964
Publication numberUS 3306363 A, US 3306363A, US-A-3306363, US3306363 A, US3306363A
InventorsMczilkey Jr Horace W
Original AssigneeBaker Oil Tools Inc
Export CitationBiBTeX, EndNote, RefMan
External Links: USPTO, USPTO Assignment, Espacenet
Valve controlled well packer apparatus
US 3306363 A
Abstract  available in
Images(3)
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Claims  available in
Description  (OCR text may contain errors)

Feb. 28, 1967 w. M ZILKEY, JR 3,306,363

VALVE CONTROLLED WELL PACKER APPARATUS Filed April 22, 1964 3 Sheets-Sheet 1 1&2. 4.

go INVENTOR.

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Feb. 28, 1967 H. w. M ZILKEY, JR

VALVE CONTROLLED WELL PAGKER APPARATUS Filed April 22, 1964 5 Sheets-Sheet 2 I INVENTOR.

IQTTOEA/EVSI 3 Sheets-Sheet 5' WV W flrroeuensf Feb. 28, 1967 H.-W. M ZILKEY, JR

VALVE CONTROLLED WELL PACKER APPARATUS Filed April 22, 1964 United States Patent Ofi ice 3,365,363 Patented Feb. 28, 1967 3,306,363 VALVE CONTRULLED WELL PACKER APPARATUS Horace W. McZilkey, J12, Los Angeles, Calif., assignor to Baker Oil Tools, Inc., Los Angeles, Calif., a corporation of California Filed Apr. 22, 1964, Ser. No. 361,783 9 Claims. (Cl. 166-152) The present invention relates to well packers adapted to be set in packed-off condition in well casing and similar conduit strings disposed in well bores.

An object of the invention is to provide a well packer apparatus having a passage and a valve for controlling fluid flow through the passage, the valve being selectively shiftable positively between open and closed positions, and being substantially pressure balanced so that fluid pressure imposed thereon either from above or below the well packer apparatus does not tend to shift the valve from closed to open position.

Another object of the invention is to provide a well packer apparatus having a passage and a valve for controlling flow of fluid through the passage in both directions, the valve being positively shiftable between open and closed positions in response to the strain imposed on a tubular string, or corresponding running-in string, extending from the valve to the top of the well bore, the valve being pressure balanced when in closed position so that fluid pressure from above or below the well packer does not tend to shift the valve to open position.

A further object of the invention is to provide a well packer apparatus having a passage and a valve for controlling fluid flow through the passage, the valve being shiftable between open and closed positions and positively locked in closed position against inadvertent shifting to open position, the valve also being pressure balanced when in closed position so that fluid pressure from above or below the well packer does not tend to shift the valve to open position.

An additional object of the invention is to provide a well packer having a passage and a valve for controlling fluid flow through the passage, in which a tubular string can be associated with the packer and subjected to fluid pressure to verify the fact of valve closing and absence of valve leakage, the valve being pressure balanced when in closed position so that pressure of the fluid in the tubular string does not tend to shift the valve to open position.

This invention possesses many other advantages, and has other objects which may be made more clearly apparent from a consideration of a form in which it may be embodied. This form is shown in the drawings accompanying and forming part of the present specification. It will now be described in detail, for the purpose of illustrating the general principles of the invention; but it is to be understood that such detailed description is not to be taken in a limiting sense, since the scope of the invention is best defined by the appended claims.

Referring to the drawings:

FIGURE 1 is a side elevational view of the well packer apparatus disposed in a well casing, the parts being conditioned for lowering the apparatus in the well casing;

FIGS. 2a and 2b together constitute a longitudinal section through the well packer apparatus prior to setting of the packer in the well casing, FIG. 217 being a lower continuation of FIG. 20.

FIGS. 30: and 3b are views corresponding to FIGS. 2a and 2b, disclosing the well packer apparatus after its setting in the well casing, FIG. 3b being a lower continua- FIG. 5 is a cross-section taken along the line 5-5 on FIG. 2a. I 4

As disclosed in the drawings, it is desired to run a subsurface well tool or packer A in a well casing B on a suitable setting tool C through use of a tubular running-in string D, such as a string of tubing or drill pipe, extending to the top of the well bore containing the casing. Initially, portions of the well packer A are in retracted position. When the packer has been lowered to the desired setting point in the well casing, such portions are released and expanded outwardly toward the well casing.

The well packer apparatus A includes a body 10, which may be tubular, the lower portion of which may be constituted as a guide 11 threaded on the main portion of the body and a valve body 11a threaded on the guide. The central passage through the tubular body may be open or may be closed by a valve device 81 that includes the body 11a. A plurality of segmental lower slips 12, having wickers or teeth 13 facing in a downward direction, are capable of anchoring the well packer against downward movement in the well casing and rest upon the lower guide 11. These lower slips 12 have inner surfaces 14 inclined in a downward and inward direction, engaging a companion external surface 15 on a lower expander 16 mounted on the body. The lower slips are held initially in retracted position by shear screws 17 securing them to the lower expander 16, the latter being secured initially to the body 10 by shear screws 18.

The upper end of the lower expander 16 engages the lower portion of a packing structure 23, such as a rubber or rubber-like packing sleeve, surrounding the body 10, the upper end of which engages an upper expander 24 initially releasably secured to the body by one or more shear screws 25 and having an external expander surface 26 in clined upwardly and inwardly, which is companion to corresponding inclined internal surfaces 27 on a plurality of upper segmental slips 28 surrounding the upper portion of the body '10.

For the purpose of holding the slips 12, 28 and packing 23 anchored and in packed-off condition against the well casing, a split lock ring 33 is provided, which has internal ratchet teeth 34 dacing in an upward direction and adapted to mesh with companion downwardly facing ratchet teeth 35 on the periphery of the body 10. The lock ring has external tapered cam surfaces 36 adapted to engage companion cam surfaces 37 in the expander 24, the cam surfaces tending to urge the ratchet teeth into mesh with one another. However, upward movement of the body 10 relative to the lock ring 33 can expand the ring outwardly, since there is sufficient lateral play between the cam surfaces 36, 37 when the lock ring is moved upwardly of the expander 28. The lock ring arrangement forms no part of the present invention and may be of any suitable construction. Its purpose is to allow upward movement of the body 10 relative -to the upper expander 24, but to prevent downward movement of the body relative thereto.

The upper segmental slips 28 have teeth 38 facing in an upward direction, the slips coacting with the upper expander 24 andbeing engageable with the casing B to anchor the well packer A against upward movement therewithin. These slips are held initially in a retracted position against the body 10, their upper ends initially engaging a body ring 39 threaded on the upper end of the body. A retainer ring 40 is mounted on the body between its upper ring 39 and an upwardly facing body shoulder 41, an external ring flange 42 being received within an internal groove 43 in the upper portion of the slips 28 to prevent them from dropping downwardly along the body .10 when the slips are in their fully retracted positions, such as disclosed in FIG. 2a. However, when the slips 28 are expanded outwardly, they are disconnected from the retainer tion, but which are assembled into the arcuate condition illustrated in FIG. 5. An end 46 of each spring length is received in one of a plurality of longitudinal internal weakening grooves 47 in a slip segment 28, such spring extending along the internal groove in the same slip segment and across the gap 48 between adjacent slip segments and substantially along the length of the circumferential groove 44 of the adjacent segment. The spring band members 45 are arranged in overlapping relation, as

shown, and by virtue of tending to straighten out, they are exerting a constant spring force urging the slips outwardly. Since they extend within the circumferential groove 44 from one slip segment 28 to an adjacent slip segment, they also collectively tend to hold the slips 28 in transverse alignment with respect to one another. The spring band elements 45 have a width corresponding to the longitudinal extent of the internal slip groove 44, having a working clearance with the sides of the groove to avoid interference with the freedom of the slips 28 to expand outwardly, when permitted to do so.

The setting tool C includes a tubular body, mandrel or inner tubular member 50 adapted to be threadedly secured at its upper end to a coupling 51 forming the lower end of the tubular running-in string D of drill pipe or tubing extending to the top of the hole. This body or mandrel has a lower section 52 threadedly secured to its upper section 50 and slidably keyed to a threaded nut 53 threaded into an upper threaded box 58 of the body member 10. The slidable key arrangement is provided by a key 85 fixed to the section 52 and slidable in a keyway 86 in the nut 53. Since the threaded interconnection between the nut 53 and body 10 is preferably a left-hand one, righthand rotation of the tubular string D and mandrel 50 relative to the body 10 will effect disconnection of the nut 53 from the packer body 10, the nut sliding upwardly on the mandrel section 52 during its unthreading from the body.

Surrounding the mandrel 50 is a device which retains the upper slips 28 in their initially retracted position, but which can be actuated through appropriate manipulation of the tubular string D and mandrel 50 to release the slips 28 for outward expansion under the influence of the springs 45, and in which inadvertent release cannot occur readily. The mechanism surrounding the mandrel can also assist in securing the anchoring engagement of the upper slips 28 with the wall of the well casing B.

As disclosed in the drawings, the slip retaining and slip setting mechanism surrounding the mandrel includes a lower portion or section 60 of a setting and retaining sleeve structure 61, which surrounds the upper body ring 39 and which also surrounds the upper portion of the body slips 28, the lower end 60a of the lower sleeve portion 60 terminating adjacent to a slip shoulder 28a, which can be provided by one of the upwardly facing wickers or teeth 38 of the upper slips. By virtue of initially surrounding the upper portion of the slips 28, the lower sleeve portion 60 holds the latter inwardly against the body 10, and in a position in which the upper internal circumferential groove 43 receives the external holding flange 42 of the retainer ring 40.

The lower section 60 of the setting sleeve structure 61 has its upper portion threadedly secured to the lower end of an upper section 65 of the setting sleeve, which surrounds the mandrel 50. The upper end of this upper section is threadedly or otherwise suitably secured to the dragportion 66 of the apparatus. As specifically disclosed, the upper setting sleeve section 65 is threaded onto a lower drag collar 67 which is slidable on the mandrel 50, this collar receiving the lower ends of circumferentially spaced, longitudinally extending outwardly bowed leaf springs 68 adapted to frictionally engage the wall of the well casing B. The lower ends of these springs are secured to the lower collar by an encompassing upper portion 69a of the upper sleeve section 65. The upper ends of the outwardly bowed springs 68 are secured to an upper drag collar 69 slidable on the mandrel by an encompassing retainer ring '70 secured to the upper collar by screws 71, or the like.

Initially, relative downward movement of the body member or mandrel 5i), and of the entire well packer A with respect to the setting sleeve structure 61 is prevented by a lock device. As shown, this lock device includes a control nut 72 having internal right-hand threads 73 threadedly connected to companion external threads 74 on the mandrel. When fully threaded on the mandrel, the lower end 75 of the control nut 72 engages an upwardly facing shoulder 76 on the upper sleeve section 65, so that any downward movement of the mandrel 50 is transmitted directly through the control nut 72 to the sleeve shoulder 76 in order to carry the retaining sleeve structure 61 downwardly with the mandrel and frictionally drag the springs 68 along the wall of the well casing. The control nut 72 is prevented from rotating relative to the control sleeve 61, but can partake of longitudinal movement therealong by the provision of a slidable spline connection therebetween. As shown,the slidable spline connection is provided by a key 77 suitably attached to the control nut and slidable within a longitudinal keyway 78 formed in the interior of the upper sleeve section 65.

It is apparent that the control nut 72 cannot move downwardly of the sleeve from the position illustrated in FIG. 2a, but that it can move upwardly along the sleeve. Because of the key and keyway connection 77, 78 between the control nut 72 and sleeve 65, rotation of the control nut is resisted by the frictional engagement of the drag springs 68 against the wall of the well casing B. Accordingly, right-hand rotation of the body or man drel 50 results in a relative upward feeding of the control nut 72 along the mandrel and along the control sleeve 61, until the control nut is completely unthreaded from the mandrel. Such unthreading will result from the fact that the external diameter 8% of the mandrel 50 above its externally threaded portion 74 is less than the inside diameter of the control nut. After the control not has been unthreaded from the mandrel 50, the latter is free to move downwardly relative to the setting sleeve structure 61.

Initially, the parts occupy the relative positions illus trated in FIGS. 2a and 2b, in which the lower slips 12 and packing structure 23 are in their initially retracted position and the upper slips are held retracted by being encompassed by the lower portion of the setting sleeve structure 61. At this time, the control nut 72 is in its lower position in full threaded mesh with the mandrel 50 and in engagement with the upwardly facing shoulder 76 in the upper setting sleeve section 65. The left-hand threaded nut 53 is in fully threaded engagement with the threaded box 58 of the packer body 10' with the lower end 52a of the mandrel section 52 engaging an upwardly facing body shoulder 10b. The apparatus is run in the well casing, the friction drag springs 68 resisting downward movement of the drag device 66 and of the setting or control sleeve structure 61. However, such resistance is overcome by the direct transmission of the thrust from the mandrel 50 and control nut 72 to the setting sleeve shoulder 76. In the event that the tubing string D and mandrel 50 were to be moved upwardly, the entire apparatus will move upwardly with it, since the mandrel section 52 is secured initially to the nut 53 by a shear screw 53a, the upward motion of the mandrel being transmitted to the packer body 10 and from the body through the retainer ring 40 to the upper slips 28, the shoulder 28a of the latter engaging the lower end 60a of the lower setting sleeve section and urging the entire setting sleeve structure and drag device in an upward direction.

When the location in the well casing is reached at which the well packer A is to be anchored in packed-off condition, the tubular running-in string D and mandrel 50 are rotated to the right a sufficient number of turns, which, for example, may be about ten turns, which will produce corresponding rotation of the entire well packer apparatus within the setting sleeve 61, the latter being prevented from rotating by the friction drag device 66, which also prevents the control nut 72 from rotating. As a result of such rotation, the control nut 72 feeds upwardly out of threaded engagement with the mandrel threads 74, thereby allowing the mandrel 50 to move downwardly relative to the setting sleeve structure 6'1, since downward movement of the latter is resisted by the friction drag springs 68. Downward movement of the mandrel, which. can be produced by moving the tubular running-in string D downwardly, will shift the packer A downwardly with it until the upper slips 28 are moved down below the lower end 60a of the setting sleeve structure, thereby freeing such slips and allowing the springs 45 to expand them outwardly against the wall of the well casing, at which time the slips are free from the retainer ring 40 secured to the body 10. The slips are now located below the setting sleeve 60, which is in a position immediately above the slips and capable of engaging the latter to resist their upward movement in the well casing.

The tubular running-in string D and mandrel 50 are now moved upwardly, the packer body 10- moving upwardly with it, as well as the upper expander 24 and the well packer parts therebelow, the upper expander shifting upwardly behind the upper slips and wedging them to a greater extent outwardly into firm anchoring engagement with the wall of the well casing B. upper slips tend to slide upwardly along the wall of the well casing B, they will move into engagement with the lower end 60a of the setting sleeve 60 (if they are not already in engagement with such lower end). Upward movement of this sleeve is resisted by the friction drag device 66, which results in resistance to upward movement of the upper slips 20. Accordingly, the upper expander 24 can wedge behind the slips and embed their wickers 38 into the wall of the well casing.

The taking of a sufficient upward strain on the mandrel 50 and the body 10 of the tool will then shear the screws securing the upper expander 24 to the body, the body 10 then moving upwardly and carrying the lower expander 16 and lower slips 12 upwardly with it to shorten the packing sleeve 23 and effect its lateral expansion into sealing engagement with the wall of the well casing as well as with the periphery of the body. Upward movement of the body 10 relative to the upper expander 24 is permitted by the one-way ratchet lock ring device 33. After the packing sleeve 23 has been expanded against the wall of the well casing, a continuation of the upward strain on the mandrel 50 and the body 10 will effect a shearing of the screws 18, 17 attaching the lower expander 16 to the body and the lower slips 12 to the lower expander, the body 10 shifting the lower slips upwardly along the lower expander and outwardly into anchoring engagement with the wall of the well casing. -As pointed out above, downward movement of the body 10 cannot occur since its downward force is transmitted through the ratchet ring 33 to the upper expander 24 and through the packing structure 23, lower expander 16 and lower slips 12 to the well casing B. Any tendency for the body 10 to move upwardly is transmitted through the lower slips 12, lower expander 16 and packing structure 23 to the upper expander 24 and through the latter to the upper slips 28 and to the well casing. During the taking of an upward strain on the mandrel in setting the packer, the shear screw 53a may be disrupted, the mandrel moving upward in the nut 53 until a mandrel stop shoulder 52b engages an upper shoulder 520 on the nut 53.

If the The well packer A has now been anchored in packedofl condition in the well casing B, as shown in FIGS. 3a and 3b. The mandrel 50 can be released, from the body by rotating the tubular running-in string D and the mandrel to the right, the threaded nut 53 unthreading completely from the threaded box 58 of the packer body 10. Following such disconnection of the mandrel from the packer body, the tubular running-in string D and mandrel are elevated, the upper thread turn 74 on the mandrel engaging the control nut 72 and moving the latter upwardly within the setting sleeve structure 61, until the nut 72 engages the lower drag collar 67, after which the entire drag device 66 and setting sleeve structure 61 move upwardly with the mandrel within the well casing. The tubular running-in string D and the setting tool C can now be elevated in the well casing B to the top of the well bore.

Flow of fluid through the well packer apparatus is controlled by the valve device 81 in the lower portion of the apparatus, which, as stated above, includes the valve body 1101 which has side ports extending through its wall, the lower portion 91 of the body being closed. The body has suitable upper and lower seal rings 92, 93 in inner grooves 94 on opposite sides of the ports 90 for coaction with a slidable sleeve valve 95 slidable along the wall 96 of the valve body and along the seal rings 92, 93. The sleeve valve can occupy a lower position in the valve body 11a as illustrated in FIG. 2b, in which the valve is open so that fluid can flow through the ports, and an upper position in which the solid lower portion 96a of the sleeve valve extends across the ports, with its peripherysealed against the upper and lower seal rings 92, 93, the valve then being closed as shown in FIG. 3b.

The upper portion of the valve sleeve is constituted as a latch device 97, such upper portion having circumferentially spaced longitudinally extending slots 98 forming latch arms 99 merging into latch dogs or members 100, each of which has an outer finger 101 and an inner finger 102. When the valve sleeve 95 is in its upper port closing position, such as disclosed in FIG. 3b, the arms 99 inherently shift outwardly and move the outer fingers 101 into a lock groove 103 in the body 10, 11 defined between a lower'downwardly tapering shoulder 104 in the body guide 11 and the lower upwardly tapering end 105 of the main portion of the body 10 thereabove. The lower ends 106 of the outer finger are tapered to conform with the taper 104 of the lower side of the groove. At the lower ends of the flexible arms 99, but above the lower ends of the slots 98, the valve sleeve has an upwardly facing shoulder 107 adapted to be engaged by the lower end 108 of a mandrel extension 109 threadedly secured to the lower end of the mandrel section 52 and having a suitable side seal ring 110 adapted to seal against the inner Wall of the packer body 10. When the lower end 108 of the mandrel extension engages the shoulder 107 of the valve sleeve 95, a peripheral groove or recess 111 in the mandrel extension is disposed opposite the dogs 100, the inner fingers 102 being shiftable laterally inwardly into the groove 111 so as to couple the inner fingers 102 to the mandrel extension 109.

As shown in FIG. 2b, when the valve sleeve 95 is in its lower port opening position within the valve body 11a, the inner wall 961) of the body guide 11 engages the outer fingers 101, shifting the dogs 100 inwardly and holds their fingers 102 inwardly within the mandrel groove 111. At this time, the lower end 108 of the mandrel extension can engage the upwardly facing valve sleeve shoulder 107. Upon upward movement of the mandrel 50 within the packer body passage 80, the lower tapered side 112 of the groove engages the inner fingers 102 and shifts the valve sleeve 95 upwardly until the dogs 100 are opposite the body lock groove 103, the lower tapered side of the mandrel engaging a companion tapered surface 113 at the lower end of each of the inner fingers to insure outward shifting and springing of the dogs to position their outer fingers 101 within the lock groove 103. At this time,

the eflective diameter of the inner fingers 102 has been increased to a valve exceeding the diameter of the mandrel extension 109, permitting the extension to be moved upwardly through the latch fingers 102, if desired. With the outer latch fingers 101 in the body lock groove 103, the valve sleeve 95 is disposed in closed position across the ports 90, as illustrated in FIG. 3b.

If reopening of the valve is desired, it is merely necessary to shift the mandrel extension 50 downwardly through the dogs 100, the extension engaging the sleeve shoulder 107, at which time the mandrel groove 111 is disposed opposite the dogs. Downward force imposed on the mandrel extension 50 by the tubular string D will now cam the dogs inwardly from the body lock groove 103, and then shift the valve sleeve 95 downwardly to the port opening position, as disclosed in FIG. 2b, the inner fingers 102 then being disposed in the mandrel groove 111 to recouple the mandrel to the latch sleeve, so that subsequent upward motion of the mandrel extension 109 can be transmitted to the valve sleeve.

As shown in the drawings, the valve sleeve 95 may be disposed initially in its lower position within the valve body 1101, opening the ports 90, the valve being retained in this open position by the shear screw 53a securing the mandrel section 52 to the threaded nut 53. Accordingly, during lowering of the packer apparatus through the fluid in the "well casing B, such fluid can enter the apparatus through the ports 90, flowing through the slots 98 of the valve sleeve and into the lower end of the mandrel 109, 50, proceeding upwardly through the mandrel and into the tubular string D. If desired, fluid may be pumped or circulated down through the tubular string .D and through the mandrel '50, 109, discharging from the latter into the valve sleeve 95 and exiting through its slots or ports 98 and the body ports 90 aligned therewith to the exterior of the body 11a.

As a result of anchoring the well packer in packed-off condition in the well casing, as disclosed in FIGS. 3a and 3b, the shear screw 53a may have been disrupted, or if not disrupted, the taking of a sufficient upward strain on the tubular string D and mandrel 50 will shear the screw and release the mandrel from the nut 53, allowing the mandrel and its extension 109 to shift upwardly within the packer body and valve body 11, 11a. Such upward shifting will carry the valve sleeve 95 upwardly with it 'until the dogs 100 are disposed opposite the lock groove 103, the outer fingers 101 being shifted inherently by the spring arms 99 outwardly into the lock groove 103, with the inner fingers 102 being freed from the mandrel groove 111, the parts then being in the position illustrated in FIG. 3b, .in which the ports 90 are closed. Upward movement of the mandrel within the packer body 10 is limited by engagement of the mandrel shoulder 52b with the nut shoulder 52c. However, the key is still disposed within the keyway 86 of the nut. If the setting tool C is now to be released and the mandrel 50, 109 withdrawn from the apparatus, it is only necessary to rotate the tubular string D and mandrel 50 a suflicient number of turns to unthread the nut 53 from the threaded box 58 of the well packer. The entire tubular string and setting tool may now, if desired, be elevated in the well casing B and removed entirely therefrom. If removal of the setting tool C is not desired, the mandrel 50 can again be lowered within the passage 80 in the event downward shifting of the valve sleeve to open position is desired. For that matter, following removal of the tubular string D and setting tool C from the apparatus, another tubular string, without the setting tool thereon, but with the mandrel extension 109 secured thereto may be lowered in the well casing and shifted into the body passage 80 until the lower end 108 of the mandrel extension engages the sleeve shoulder 107, which will transmit downward movement of the tubular string and mandrel to the sleeve 95 and release the latch fingers 101 [from the body lock groove 103, and shift the valve sleeve downwardly to the port opening position shown in FIG. 2b. Reclosing of the valve sleeve 95 occurs readily by the simple act of elevating the tubular string D and the mandrel 50, 109 attached thereto, which will shift the valve sleeve upwardly to the position disclosed in FIG. 3b, in which the inner latch fingers 102 are free from coupling engagement with the mandrel member 109.

With the valve 81 in the closed position, fluid under pressure is prevented from passing in both downward and upward directions through the packer body passage 80. The latch dogs releasably couple the valve sleeve to the body in its closed positon, and the valve sleeve 95 will remain in such position until purposely shifted to open position by the mandrel member. The imposition of pressure from below the well packer cannot produce pressure actuation or shifting of the valve sleeve 95 from its closed position since the sealing diameters of the upper and lower seals 92, 93 against the periphery of the valve sleeve are equal, the valve sleeve being pressure balanced. Similarly, the subjecting of the fluid in the packer passage to downwardly apply pressure cannot eflect shifting of the valve sleeve 95 downwardly to port opening position since the valve is pressure balanced. In this connection, it is to be noted that the lower end of the sleeve valve is open, there being an open passage therethrough, so that the fluid pressure within the valve body 11a acts in equal and opposite areas over the valve sleeve 95.

Testing of the valve against leakage when in its closed position can be undertaken readily merely by imposing pressure on the fluid in the tubular string D and in the mandrel 50, the latter being sealed within the passage of the packer body. Such subjecting of the fluid in the tubular string to fluid pressure also enables the tubular string itself to be tested for leaks.

It is, accordingly, apparent that a valve controlled well packer apparatus has been provided in which the valve is shifted by a running-in string positively from open to closed position, and also positively from closed to open position. A substantial 'force can be imposed on the valve sleeve to insure its upward and downward shifting within the body of the apparatus between open and closed positions. The motion of the running-in string is transmitted through the shifting mandrel 50, 109, disposed in the packer passage, directly to the valve sleeve 95. When the valve has been shifted to one of its positions, such as the closed position illustrated in FIG. 3b, it is automatically released from the shifting mandrel, allowing the latter to be elevated in the passage 80 and, if desired, withdrawn therefrom.

I claim:

1. A well packer apparatus adapted to be lowered and set in packed-oft" condition in a well bore, including a body having a fluid passage, a valve member movable upwardly and downwardly in said body passage between positions opening and closing said passage, shifting means connectible to a running-in string extending to the top of the well bore and movable upwardly and downwardly in said passage by the running-in string, means releasably coupling said shifting means to said valve member for transmitting the upward and downward movement of said shifting means to said valve member and shift said valve member to passage opening and closing positions, means engageable with said coupling means for locking said coupling means to said shifting means during upward movement of said shifting means and valve member in said passage, said valve member having a longitudinal passage therethrough to permit fluid pressure in said body, when said valve member is in closed position, to pass from one end of said valve member to its opposite end and act with equal force in opposite longitudinal directions on said valve member, precluding such fluid pressure from exerting a shifting force on said valve member.

2. A well packer apparatus adapted to be lowered and set in packed-off condition in a well bore, including a body having a fluid passage, a valve member movable upwardly and downwardly in said body passage between positions opening and closing said passage, shifting means connectible to a running-in string and extending to the top of the well bore and movable upwardly and downwardly in said passage by the running-in string; means for transmitting the upward and downward movement of said shifting means to said valve member to shift said valve member to passage opening and closing positions, said movement transmitting means including latch means on said valve member releasably coupled to said shifting means, said body engaging and holding said latch means coupled to said shifting means, said body having means thereon allowing release of said latch means from said shifting means upon movement of said valve member to one of said positions, said valve member having a longitudinal passage therethrough to permit fluid pressure in said body, when said valve member is in closed position, to pass from one end or" said valve member to its opposite end and act with equal force in opposite longitudinal directions on said valve member, precluding such fluid pressure from exerting a shifting force on said valve member.

3. A well packer apparatus adapted to be lowered and set in packed-off condition in a well bore, including a body having a fluid passage, a valve member movable upwardly in said body to passage closing position and downwardly in said body to passage openingposition, releasable latch means releasably coupling said valve member to said body in passage closing position, shifting means connectible to a running-in string extending to the top of the well bore and engageable with said valve member to release said latch means and shift said valve member downwardly to passage opening position, said body engaging said latch means and holding it coupled to said shifting means when said valve member is below its passage closing position to enable said shifting means to elevate said valve member to passage closing position at which said latch means is uncoupled from said shifting means and recoupled to said body, said valve member having a longitudinal passage therethrough to permit fluid pressure in said body, when said valve member is in closed position, to pass from one end of said valve member to its opposite end and act with equal force in opposite longitudinal directions on said valve member, precluding such fluid pressure from exerting a shifting force on said valve member.

4. A well packer apparatus adapted to be lowered and set in packed-ofl? condition in a well bore, including a body having a fluid passage, a valve member movable upwardly in said body to passage closing position and downwardly in said body to passage opening position, latch means on said valve member, said body having a groove receiving said latch means to couple said valve member to said body when said valve member is in passage closing position, shifting means having a coupling portion and connectible to a running-in string extending to the top of the well bore and engageable with said valve member to release said latch means from said body groove and shift said valve member downwardly to passage opening position, said body engaging said latch means upon such downward movement of said valve member to shift and hold said latch means coupled to said coupling portion, whereby elevation of said shifting means by the running-in string elevates the valve member to passage closing position allowing said latch means to release from said coupling portion and move into said body groove, said valve member having a longitudinal passage therethrough to permit fluid pressure in said body, when said valve member is in closed position, to pass from one end of said valve member to its opposite end and act with equal force in opposite longitudinal directions on said valve member, precluding such fluid pressure from exerting a shifting force on said valve member,

5. A well packer apparatus adapted to be lowered and set in packed-oft condition in a well bore, including a body having a fluid passage, a valve member movable upwardly in said body to passage closing position and downwardly in said body to passage opening position, said body having an internal circumferential groove, latch means on said valve member expandible into said groove when said valve member is in its upper passage closing position in said body to retain said valve member in such position, a tubular mandrel having a coupling portion and connectible to a tubular string extending to the top of the well bore and through which fluid can flow from the tubular string to the body passage, said mandrel extending into the passage and being engageable with said valve member to release said latch means from said body groove and shift said valve member to passage opening position, said body engaging said latch means during downward movement of said valve member to shift said latch means into coupling relation to said coupling portion, whereby subsequent elevation of said mandrel by said tubular string elevates the valve member to passage closing position and aligns said latch means with said body groove, allowing release of said latch means from said coupling portion and its expansion into said body groove, said valve member having a longitudinal passage therethrough to permit fluid pressure in said body, when said valve member is in close-d position, to pass from one end of said valve member to its opposite end and act with equal force in opposite longitudinal directions on said valve member, precluding such fluid pressure from exerting a shifting force on said valve member.

6. A well packer apparatus adapted to be lowered and set in packed-oil condition in a well bore, including a body having a longitudinal passage and a side port from said passage to the exterior of said body, said body being closed below said side port, a valve member movable upwardly and downwardly in said body passage between a closed position across said port and an open position allowing fluid flow through said passage and port, said valve member having a longitudinal passage establishing fluid pressure communication between said body above said member and said body below said member, shifting means connectible to a running-in string extending to the top of the well bore and movable upwardly and downwardly in said passage by the running-in string, means releasably coupling said shifting means to said valve means for transmitting the upward and downward move ment of said shifting means to said valve member and shift said valve member to passage opening and closing position, and means engageable with said coupling means for locking said coupling means to said shifting means during upward movement of said shifting means and valve member in said passage.

7. A well packer apparatus adapted to be lowered and set in packed-off condition in a well bore, including a body having a longitudinal passage and a side port from said passage to the exterior of said body, said body being closed below said side port, a valve member movable upwardly in said body passage to a closed position across said port and downwardly in said body passage to an open position below said port allowing fluid flow through said passage and port, said valve member having a longitudinal passage establishing fluid pressure communication between said body above said member and said body below said member, releasable latch means releasably coupling said valve member to said body in port closing position, shifting means connectible to a running-in string extending to the top of the well bore and engageable with said valve member to release said latch means and shift said valve member downwardly to port opening position, said body engaging said latch means and holding it coupled to said shifting means when said valve member is below its port closing position to enable said shifting means to elevate said valve member to port closing position in which said 1 1' latch means is uncoupled from said shifting means and recoupled to said body.

8. A well packer apparatus adapted to be lowered and set in packed-off condition in a well bore, including a body having a longitudinal passage and a side port from said passage to the exterior of said body, said body being closed below said side port, a valve member movable upwardly in said body passage to a closed position across said port and downwardly in said body passage to an open position below said port allowing fluid flow through said passage and port, said valve member having a longitudinal passage establishing fluid pressure communication between said body above said member and said body below said member, latch means on said valve member, said body having a groove receiving said latch means to couple said valve member to said body when said valve member is in port closing position, shifting means having a coupling portion connectible to a running-in string extending to the top of the well bore and engageable with said valve member to release said latch means from said body groove and shift said valve member downwardly to port opening position, said body engaging said latch means upon such downward movement of said valve member to shift and hold said latch means coupled to said coupling portion, whereby elevation of said shifting means by the running-in string elevates the valve member to port closing position allowing said latch means to release from said coupling portion and move into said body groove.

9. A well packer apparatus adapted to be lowered and set in packed-01f condition in a well bore, including a body having a longitudinal passage and a side port from said passage to the exterior of said body, said body being closed below said side port, a valve member movable upwardly in said body to closed position across said port and downwardly in said body to port opening position, said valve member having a longitudinal passage establishing fluid pressure communication between said body above said member and said body below said member, said body having an internal circumferential groove, latch means on said valve member expandible into said groove when said valve member is in its upper port closing position in said body to retain said valve member in such position, a tubular mandrel having a coupling portion and connectible to a tubular string extending to the top of the well bore through which fluid can flow from the tubular string to the body passage, said mandrel extending into said body passage and being engageable with said valve member to release said latch means from said body groove and shift said valve member downwardly to port opening position, said body engaging said latch means during downward movement of said valve member to shift said latch means into coupling relation to said coupling portion, whereby subsequent elevation of said mandrel by the tubular string elevates the valve member to port closing position and aligns said latch means with said body groove allowing release of said latch means from said coupling portion and its expansion into said body groove.

References Cited by the Examiner UNITED STATES PATENTS 3,094,307 6/1963 Alley l66224 3,100,537 8/1963 Crowe 166-192 3,163,225 12/1964 Perkins l66128 CHARLES E. OCONNELL, Primary Examiner.

I. A. LEPPINK, Assistant Examiner.

Patent Citations
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Referenced by
Citing PatentFiling datePublication dateApplicantTitle
US3356140 *Jul 13, 1965Dec 5, 1967Gearhart Owen IncSubsurface well bore fluid flow control apparatus
US3382928 *Aug 4, 1966May 14, 1968Halliburton CoApparatus for use in measuring the pressure of fluids in wells
US4212355 *Sep 11, 1978Jul 15, 1980Lynes, Inc.Tubing manipulated test valve and latch assembly
US4237979 *Jan 19, 1979Dec 9, 1980Dresser Industries, Inc.Valve for hydraulic setting packer setting tool and method of setting a hydraulically settable packer therewith
US4372388 *Nov 24, 1980Feb 8, 1983Halliburton CompanySubsurface control valve
US4415038 *Jul 10, 1981Nov 15, 1983Baker International CorporationFormation protection valve apparatus and method
US4441552 *Jun 18, 1982Apr 10, 1984Halliburton CompanyHydraulic setting tool with flapper valve
US4487221 *Nov 16, 1981Dec 11, 1984Klaas ZwartDevice for temporarily sealing a pipe
US4648445 *Dec 13, 1985Mar 10, 1987Halliburton CompanyRetrieving mechanism
US4651829 *Dec 13, 1985Mar 24, 1987Halliburton CompanySubsurface control valve
US5826652 *Apr 8, 1997Oct 27, 1998Baker Hughes IncorporatedHydraulic setting tool
US7467665 *Nov 8, 2005Dec 23, 2008Baker Hughes IncorporatedAutonomous circulation, fill-up, and equalization valve
US20070102164 *Nov 8, 2005May 10, 2007Baker Hughes IncorporatedAutonomous circulation, fill-up, and equalization valve
WO1982001736A1 *Nov 16, 1981May 27, 1982Klaas ZwartDevice for temporarily sealing a pipe
Classifications
U.S. Classification166/152, 166/334.4
International ClassificationE21B33/12, E21B33/129
Cooperative ClassificationE21B33/1294
European ClassificationE21B33/129N