Downhole force generator

Abstract: A hydraulic well tool (50;200;300) is provided for running into a flow conduit (24) of a well on a handling string (60), such as reeled tubing or jointed pipe, for generating and applying an axial force to an object in the well. The tool is anchored in the flow conduit by an anchoring mechanism (75) actuatable by fluid pressure in the handling string and it also includes a piston/cylinder arrangement (80,104) that is actuatable by fluid pressure in the handling string for moving the object. The tool may be provided with means to permit increasing the fluid pressure for actuation of the anchoring mechanism and the piston/cylinder arrangement. Such means including flow restrictors (117) ball valves (120), velocity check valves (92) and plugs. The displacement of the object is achieved hydraulically while the well tool is anchored in the flow conduit and without axially stressing the handling strip. The anchoring mechanism may have piston-type anchor members (510) each formed with a sinusoidal seal ring recess (520) at its inner end for increasing its stroke, and with retraction springs (526) to avoid obstructing the longitudinal body bore.

Description: BACKGROUND OF THE INVENTION Field of the Invention This invention relates to downhole well tools and more particularly to devices for running into and out of a well on a handling string for generating a force for moving an object in the well bore after temporarily anchoring the lower portion of such handling string in the well. Related Art and Information It has been common practice to use hydraulically actuated piston/cylinder arrangements for applying a force to accomplish a remote task. Well packers, well safety valves, well pumps, and the like have been actuated at downhole locations by supplying pressurized fluid thereto from the surface through a fluid conduit, or control line. Oftentimes it is desirable to slide a sleeve valve which is stuck, or move an object which is lodged in the well. This may involve moving the sliding sleeve valve up or down, or both; and may involve moving the lodged object up or down, or both. Such work may ordinarily require an expensive rig and a sturdy handling string. Wire line and wireline tools have been used only for light work of this type, and reeled tubing has been used also. Rigs for wire line and reeled tubing are more highly mobile than are larger rigs, and they are much less expensive. However, wire line is of limited tensile strength, it is very flexible and cannot transmit a pushing force, and requires jars for moving objects which do not move easily. Similarly, reeled tubing is of limited weight and tensile strength, and since it is relatively flexible it can apply only light pulling or pushing forces. Therefore, wireline equipment cannot be used effectively for many such jobs, and neither can reeled tubing. Wireline equipment cannot be used in horizontal wells since it is dependent upon the force of gravity not only for moving the tools and wire into the well, but for operating the jars for generating impacts downhole in response to manipulation of the wire line at the surface. Reeled tubing, while having greater strength and rigidity than wire line, and can be used in horizontal well operations, is nevertheless very limited in both pulling and pushing, particularly the latter, since it is subject to great drag which hastens its failure in column loading. It, therefore, has been desirable to be able to perform such push or pull operations using reeled tubing. It has been especially desirable to perform such push and pull operations in horizontal and slanted or curved well bores. Reeled tubing can carry considerable fluid pressure. The present invention provides hydraulic devices which can be attached to a reeled tubing, run into a well, even a horizontal well until the object to be moved is engaged. The reeled tubing is then pressurized to anchor the hydraulic device in the well and is further pressurized to generate an axial force which is applied to the object, tending to move the same. Examples of hydraulically actuated anchoring devices as well as piston/cylinder arrangements are found in the U.S. patents listed below. There is also found patents teaching use of reeled tubing for shifting sleeve valves. Patents of the United States RE. 25,381 2,765,853 2,989,121 3,096,824 3,142,339 3,221,227 3,223,169 3,233,675 3,276,793 3,277,965 3,326,292 3,329,210 3,338,308 3,356,145 3,376,927 3,381,752 3,422,899 3,425,489 3,454,090 3,497,001 3,599,712 3,658,127 3,701,382 3,893,512 4,274,486 4,453,599 4,862,958 4,928,770 4,928,772 Patent 2,765,853 and its reissue, Patent Re. 25,381 teach use of pressure responsive hold-down members for preventing the upward displacement of a packer by a fluid pressure therebelow greater than that thereabove. These hold-down members 16 are slidable in lateral bores and are forced outward by the greater pressure below the packer. The teeth 16b of these members bitingly engage the pipe exterior of the packer and, the greater the differential pressure tending to lift the packer, the greater these members anchor the packer. (Col. 3, lines 32-60 and Col. 5, lines 43-64.) Other patents showing hold-down members activated by fluid pressure from below a packer are Patents 2,989,121; 3,096,824; 3,142,339; 3,211,227; 3,223,169; 3,233,675; 3,276,793; 3,277,965; 3,326,292; 3,329,210; 3,338,308; 3,381,752; 3,422,899; 3,425,489; 3,454,090; and 3,701,382. Other similar hold-down teachings are found in the following patents. Patent 3,497,001 which issued February 24, 1970 to Cicero C. Brown shows use of hold-down members 32 in a tubing anchor A used in a pumping well. The column of liquid in the well tubing T forces the hold-down members outward into biting engagement with the surrounding casing (col. 3, line 75, et seq.). Patent 3,376,927 which issued to Joe R. Brown on April 9, 1968 teaches use of hold-down members 63 for anchoring a cutting tool in axial position by pressurizing the pipe string 13. (See col. 3, lines 56-67.) Patent 3,599,712 which issued on August 17, 1971, to Charles W. Magill discloses use of hold-down slips 28 energized by pressurized fluids in bore 22 for holding a tubing fixed in the well bore. (See col. 2, lines 67-75.) Patent 3,658,127 which issued to Chudleigh B. Cochran and Phillip H. Manderscheid on April 25, 1972, teaches again the well-known practice of pumping a ball (B) down a well tubing T-2 and allowing it to become seated below a packer, then pressuring up the tubing to actuate the hydraulically set packer to its set condition. (See col. 5 beginning at line 69.) Patent 4,862,958 which issued to Ronald E. Pringle on September 5, 1989 discloses a fluid power actuated actuating tool, this tool being run on the end of reeled tubing through which a small flexible tubing 14 passes. Fluid pressure is supplied from the surface to this actuating tool 10 to actuate the slips 28 and maintain them engaged to retain the tool anchored in the tubing. Nitrogen is supplied from the surface through the bore of the reeled tubing 12 to actuate power actuating means 54. The tool can deliver jarring impacts (col. 4, lines 20-33) or can provide a constant pressure stroke (col. 4, line 62 through col. 5, line 2). Patent 4,274,486 issued on June 23, 1981 to John V. Fredd and discloses a piston 26 slidable in the bore (cylinder) of member 28 of telescoping joint 23. Pressure in the annulus 29 can move the piston upward if the difference between the annulus and the tubing pressure is sufficient. Thus, this piston/cylinder can be operated remotely from the surface by controlling the differential pressure. (Col. 4, lines 21-35.) Patent 4,453,599 which issued to John V. Fredd on June 12, 1984 discloses in Figure 1 the use of a piston/cylinder 35 downhole in a well to actuate a sleeve valve 14 located just above the packer 13. The valve is controlled by tubing pressure. Pressuring the tubing 36 causes the piston 41 to move upward and open the valve to permit well fluids to flow into the annulus surrounding the tubing. Reducing the tubing pressure allows weight of the piston and a length of pipe attached thereto to move down and close the valve. Other forms of valves are disclosed, all using a similar valve and utilizing a differential pressure across the piston for its operation, this differential may involve changes in tubing or casing pressure. Patent 4,862,958 (mentioned earlier) also discloses as a part of its power actuating means 54 a piston 80, Figure 2, which is moved downward in housing 18 by pressurized nitrogen supplied through flexible tubing reeled tubing 12. A similar piston/cylinder, actuator 54a is illustrated in Figures 5 and 6. Patent 3,356,145 which issued to John V. Fredd on December 5, 1967 discloses in Figure 2 a piston/cylinder 31 which utilizes pressure in the well annulus 442 to lift a floating portion of pipe 32 to an upper position to hold the safety valve 35 open. When pressure in the annulus falls below a predetermined level the floating pipe will be allowed to move down and close the valve. (See col. 15, line 72 to col. 16, line 48.) Patent 4,928,770 which issued on May 29, 1990 to Douglas J. Murray discloses use of reeled tubing apparatus 10b for shifting sliding sleeves 101 in wells. Also disclosed is the use of a piston 10a on the reeled tubing near the shifting tool. When the shifting tool is engaged with the sliding sleeve the piston will be in a close-fitting portion PT-1 of the tubing. The sleeve is shifted up or down by moving the reeled tubing 11. When attempting to shift the sleeve down and it cannot be moved by the reeled tubing alone, the tubing pressure above the piston can be increased to cause the piston to aid in the down shifting of the sleeve. This procedure can be used only for down shifting (Col. lines 58-62). Patent 4,928,772 which issued to Mark E. Hopmann on May 29, 1990, also contains approximately the same subject matter as does Patent 4,928,770 just mentioned, but does not disclose the piston. Patent 3,893,512 which issued to Albert W. Carroll and Phillip S. Sizer on July 8, 1975 discloses a sleeve valve near the production zone in a well which will close should the tubing be severed thereabove. In certain embodiments, the system is resettable to make possible periodic testing to assure their operability. Piston/cylinder arrangements are disclosed for such resetting. In Figure 9, casing pressure acting beneath piston 101 holds it up in the cylinder to permit production. Loss of pressure below the piston permits gravity to move the piston down. If the piston and its tubing section TS has dropped, pressuring the casing will lift them back to their upper position. In Figure 10, which is similar to Figure 9, the piston is lifted by pressure conducted to the lower end of the cylinder through small conduit CFL. In Figures 14 and 15, a piston/cylinder arrangement is illustrated wherein the tubing is plugged at 250 by a plug 251 between the valve V and the cylinder 221, and a port 234 is provided just below piston 232. Pressure applied to the upper portion T of the tubing passes through this port and lifts the piston in the cylinder to, thus, open valve V. There was not found in the prior art a force generator for use with a handling string of reeled tubing or light jointed pipe which can apply an axial force to an object in a well flow conductor for pushing or pulling such object to dislodge and/or retrieve the same while the handling string is anchored in the well flow conductor, the anchoring and the force generating being accomplished by fluid pressure conducted to the force generator through the handling string. US-A-2915126 discloses a well tool for running into a well on a handling string for generating an axial force and applying it to an object at a subsurface location in a well flow conductor the said well tool comprising: (a) an upper tubular body member having a longitudinal bore extending therethrough and having means at its upper end for attachment to a handling string, said upper body member further including: (i) piston means intermediate its ends, and (ii) pressure activated anchor means for anchoring the body member in said well flow conductor; (b) a second tubular body member formed with an upper cylinder which receives the said piston, the said piston dividing the upper cylinder into power chamber connected by passage means to the said bore and a vented exhaust chamber; and (c) means at the lower end of the tool for attachment to an engaging tool. In that patent, the tool can only exert an upward pull on a down-hole object. The present invention is characterised in that the said second tubular body member constitutes an intermediate body member formed with a lower cylinder which receives a piston carried at the upper end of a third, lower tubular member, the lower end of which is provided with the said attachment means and wherein both pistons have limited strokes within the respective cylinders. With this construction, the tool can be operated, at will, either to apply an upward, pulling force or a downward, pushing force to the down-hole object. One form of well tool and some possible modifications thereof, all in accordance with the invention are described below with reference to the accompanying drawings, wherein: Figure 1 is a schematical view showing a well and a well tool suspended therein on a reeled tubing; Figure 2 is a schematic axial section of a well tool of the invention; Figure 3 is a longitudinal schematical view partly in elevation and partly in section showing one form of prior art velocity check valve; Figure 4 is a schematical view in longitudinal section showing another form of prior art velocity check valve; Figure 5 is a schematical view, partly in section, partly in elevation, showing a disconnect device which may be included in certain embodiments of this invention; Figure 6 is a fragmentary longitudinal view in elevation showing a pressure-actuated anchoring device which may be included in certain embodiments of this invention; Figure 7 is a cross-sectional view taken along line 10-10 of Figure 6; Figure 8 is a development view showing the sinusoidal seal ring recess of the piston slips seen in Figure 7; Figure 9 is a full-face view (in reduced scale) of an alternate form of teeth on a piston slip; and Figure 10 is a sectional view showing the profile of the pyramidal teeth on the piston slip of Figure 9. Referring now to Figure 1, it will be seen that a well 20 includes a casing 22 having a tubing 24 disposed therein and a wellhead 26 closing the upper end of the casing about the tubing. Above the wellhead is a representation of a tree as at 28 and a blowout preventer or stuffing box 30 atop thereof through which a handling string such as reeled tubing 32 may be forced into and out of the well as by well-known injection means (not shown). The reeled tubing 32 is wound on and off the reel 34 by drive means (not shown) and suitable liquid from tank 36 is received by pump 38 and forced into reeled tubing 32 as desired and in the usual manner. The device 300 is adapted to be anchored by pressure actuated slip means 75 and to utilize pressure to generate an axial force through an engaging tool 340 for moving an object (not shown) in the well. Such object to be moved may be a sliding sleeve valve, drill, washing tool, stuck tool, setting tool, pulling tool, fishing tool, impression block, or other tools or devices which might require axial force for their operation, dislodgement, or other purpose. While Figure 1 shows the device of this invention being run on reeled tubing, it could also be run on a jointed pipe string; and while the well 20 is shown to have a vertical bore, the device of this invention can be used in deviated well bores and in horizontal wells. The force generating device 300 shown in Fig. 2 has an upper portion including a piston 304 near its midsection, a thread at its upper end, at 306, for attachment to a handling string 60 and anchoring means 75. The upper tubular body 302 has an axial bore 56, suitable connection means such as a thread as at 306 for attachment to a handling string 60, which may be any suitable tubular handling string such as reeled tubing or jointed pipe. The upper tubular body is enlarged in outside diameter as at 62 and is provided with two pairs of opposed passages 64, and these passages are enlarged to form opposed pairs of larger bores 66 in which respective pairs of piston slips 68 are slidable between a retracted position in which their teeth 70 do not protrude beyond the periphery of the enlargement 62 and an expanded position in which their teeth bitingly engage the inner wall of the surrounding well flow conductor, such as the well tubing 24 seen in Figure 1. Each piston slip 68 is provided with a circumferential groove 72 close to its inward end in which a resilient seal ring such as o-ring 74 is installed for preventing leakage of fluids about the slip. It will be understood that fluid pressure in the handling string 60 and, therefore, in bore 56 of the upper tubular body will be communicated through lateral passages 64 into the opposed bores 66 and there will act against the inner end faces of the slips 68 to apply an outward bias thereto. In this manner, pressurization of the handling string will pressurize the force generator and this will result in the slips being expanded into biting engagement with the surrounding well conduit to lock the force generator at that location in the conduit. It follows that bleeding the pressure from the force generator will release this anchoring mechanism 75 since, for lack of pressure holding them expanded, the slips 68 will relax and springs (not shown in Figure 1, but shown in Figure 7) will retract them fully. An intermediate tubular member 320 has an axial through bore 322 enlarged at its upper end to form a cylinder bore 324 in which the upper piston 304 is received, and is similarly enlarged at its lower end to form a cylinder bore 330 to receive a lower piston 312 integral with the upper end of a lower tubular member 310 having an axial throughbore 102. The piston 304 divides the bore 324 into a power chamber 306, above the piston and an exhaust chamber 308 below it. The chamber 306 communicates with the axial bore 56 through lateral ports 84 and the exhaust chamber is vented by ports 110 in the intermediate tubular member. The upper tubular member 302 runs through seals 112 and 114 in the intermediate member and terminates within the bore 322. The lower tubular member 310 extends downwardly with clearance through a vent 317 in the intermediate member and is provided near its lower end with an orifice 117 summounted by a conical valve seat 118 for a valve ball 120. This ball 120 can be run in the force generator, but may preferably be dropped into the handling string later and allowed to fall by gravity or to be pumped down until it becomes seated and closes the passage 117 through seat 118. When fluids are pumped down the handling string, such fluids may be allowed to return around the exterior of the handling string but within the well tubing 24 (Figure 1). Before the ball 120 is engaged on seat 118, such fluids may be circulated as just described. However, if the differential pressure created by the restricted bore 117 exceeds a predetermined value, the piston slips 68 will be expanded to anchoring position. Of course, when the ball 120 closes bore 117 through the seat 118, pressure may be readily built up in the handling string for expanding the piston slips and then actuating the piston/cylinder arrangement. When the combination force generator 300 is required to apply an axial pulling force to an object, the upper piston and cylinder is actuated while the lower piston and cylinder do nothing. Conversely, when the combination device is required to apply an axial pushing force to an object, the upper piston and cylinder do nothing. This, then, renders the combination device simple and easy to operate. To apply a pushing force, the weight of the handling string is used to collapse both cylinders. The handling string and device 300 are pressurised (with the valve orifice 117 closed) to activate the anchor means 75 and then to move the lower piston 312 down to push the object to be moved. The upper piston/cylinder 304/324 remains collapsed as seen in Figure 2. On the other hand, to apply an axial pulling force, the object to be moved is engaged and the handling string is lifted to extend both cylinders. Then, pressurization of the handling string is effected to actuate the upper piston cylinder 304. The lower piston/cylinder 312/330 will remain extended while the upper piston/cylinder retracts to exert the pulling force. In Figure 3 there is illustrated a simple form of prior art velocity check valve which could be used in device 300 in place of the seat 118 and ball 120. In Figure 3, the velocity-type check valve is indicated generally by the reference numeral 92. This device comprises a sub 92a having a reeled spring 93 with its lower end pressed into a snugly fitting bore to retain it in position, as shown. The spring holds a ball 94 high above the annular seat 95, as shown. Fluids may be forced downward through the check valve, but such flow creates a differential pressure across the ball, tending to force the ball down and compress the spring. When the rate of flow reaches a predetermined value the ball will become seated and will stop all such flow through the seat. When the ball becomes thus seated pressure builds quickly thereabove. When, however, pressure above the ball is reduced below a predetermined pressure, the spring will force it upward and from the seat. In this form of velocity check valve, the ball may be dropped when needed, or it may be placed in the force generator at the surface before it is run into the well. An alternate modified form of velocity check valve is seen in Figure 4 and is indicated generally by reference numeral 150. When the downward flow rate through this check valve increases to a value at which the drop in pressure across the ball 152 is sufficient to compress the spring 154 the ball will be moved down to engage the seat surface 156 of seat 157 and will prevent further flow. Of course, when such pressure difference subsides, the spring will unseat the ball and permit further flow through the seat. The housing 158 may be provided with a thread 160 for receiving a retainer 162 having a bore 164 and with prongs or other means for preventing the ball from plugging the bore 164 by seating against the lower end of the retainer. If desired, the retainer may be omitted, in which case the ball may be dropped into the handling string later when needed. Figure 5 illustrates a remotely operated disconnect device 400 which is useful as a safety joint when the engaging tool attached to the lower end of a force generator is gripping an object that will not pull free or release therefrom. The device 400 has an upper sub 402 having threads 404 at its upper end and has its lower reduced end 406 telescoped into the upwardly opening socket or receptacle 410 at the upper end of lower sub 412. This sub has a thread 414 on its lower end for attachment to the engaging tool. The upper sub 402 carries a lug 416 in a lateral window 418, and this lug is supported by a shiftable sleeve 420 against disengagement from the internal lock recess 422 of the lower sub. The lug can move inwardly only when sleeve 420 is shifted down as by dropping a ball 424 and applying enough pressure thereabove to break the shear pin 426. When this sleeve is then moved down, its recess 428 becomes aligned with the lug which then moves freely inwardly thereinto to unlock the connection. The upper sub can then be pulled free of the lower sub. An o-ring 430 seals the connection. A pair of o-rings 432 bridge the shear pin hole 433. The enlarged upper portion 434 of the sleeve will engage the upwardly facing shoulder 436 to assure that the sleeve will be retrieved with the upper sub. The snap ring 440 aids in installing the shear pin 426 by helping to align the shear pin recess 422 of sleeve 420 with the shear pin hole 433. Figures 6-8, illustrate a modified anchoring device 500, comprising a tubular body 502 having a bore 504 and which may be formed integral with the force generator 300 just described, but is preferably made separately and then attached to the upper end of the device 300 by suitable means such as by threads, or by a weld. The anchor device 500 would be formed with suitable connection means at its upper end for attachment to a handling string by which it would be run into and withdrawn from a well. Such connection means would generally be a thread, which could also be used for attaching the force generator to a string of heavy-wall pipe, such as jointed pipe. However, the force generators will likely be used extensively with reeled tubing, in which case a special connector (not shown) is recommended for use on the reeled tubing in order to secure it firmly to the force generator. The anchor device 500, as shown, is provided with four anchor members such as opposed piston slips 510 and 512. Anchor members 510 and 512 are in a common horizontal plane and are spaced 180 degrees apart. Another pair of identical anchor members are spaced below the anchor members 510, 512 as seen in Figure 9. Any desired number of such anchor members may be provided, and they may be arranged with 2, 3 or 4 of them in a single horizontal plane. As can be seen, it is convenient to align them in vertical rows, as shown, to simplify manufacture and assembly or disassembly. The body 502 is bored laterally for each anchor member as at 516 and the bore wall is made smooth to provide a good surface on which a seal ring is to slide while in sealing engagement therewith. For instance, the anchor member 510 is slidably received in lateral bore 516 and a seal ring, such as 0-ring 518, is carried in a suitable external recess 520 where it is in continuous sealing contact with the inner wall of lateral bore 516. The bore 510, groove 520, and 0-ring 518 in particular should be suitably lubricated. Lateral bore 516 communicates with longitudinal bore 504 of the anchor body 502 as shown. The diameter of the lateral bore in device 500 is shown to approximately equal the diameter of the longitudinal bore 504 and deep enough to intersect it. The anchor members each are slidable in their respective bores between an initial retracted position and an expanded anchoring position. The anchor members are generally provided with opposing recesses such as recesses 524 and 524a formed in their exterior face, and similar recesses are formed in the external surface of body 502. (It may be desirable to continue the recess across the face of the slip.) Retaining springs 526 and 526a of the flat type are installed as shown and secured with screws 528 and 528a. These springs serve to maintain the anchor members fully retracted as shown until such time that anchoring is to take place. At that time, pressurization of the force generator is brought about. Pressure at that time acts against the inner side of the anchor members, each of which is, in effect, a piston, and forces them outward in opposition to the bias of the flat springs which tend to retract them. The outer faces of the anchor members are provided with teeth 70 for bitingly engaging the inner wall of the flow conduit in which the force generator is used. Since anchor device 500 may be used in flow conduits having bores considerably larger than the outside diameter of body 502, the anchor members must be provided with a relatively long stroke, yet they must be fully retractable to avoid dulling of their teeth which would otherwise occur should they protrude from the housing as they are run into or out of the well. Also, it may be preferable to provide anchor members having toothed areas which are large. But large anchor members have shorter strokes, generally. In order to provide large anchor members with a greater stroke, the inward portion of the anchor member is formed as shown in Figure 10. It is readily seen that the inner end portion of anchor member 510 has been cut away arcuately as at 530 so that although the anchor member is fully retracted its inner end does not interfere with bore 504 of body 502. The seal ring recess 520 is also curved, as seen in Figure 9, if a maximum stroke is to be provided. When this seal ring recess 520 is seen in a development view, see Figure 11, it is seen to be sinusoidal. Thus, the t stroke of anchor member is increased appreciably. It is noted that the sinusoidal wave of Figure 11 makes two complete cycles in 360 degrees. As seen in Figure 11, at 0 degrees, 180 degrees, and, of course, 360 degrees, the seal recess 520 is at its minimum height in the illustration, and at 90 degrees and 270 degrees the seal recess is at its maximum height. The difference in the maximum and minimum height represents the increase in stroke length. It will be understood that each anchor member must be oriented with respect to the longitudinal axis of body 502. It is noted that the recesses 524 and 524a are located parallel to the vertical axis of the anchor member and also parallel to the longitudinal axis of the body, while perpendicular to the teeth 70. The retaining springs 526 and 526a being engaged in the spring recesses of the body and in the recesses in the anchor members will definitely maintain the anchor members in proper orientation. In the case of the combination force generator 300 of Figure 2, which can be used to pull or to push, the teeth of the anchor members may be formed as shown in Figures 9 and 10. In Figure 9, the anchor member 68a is provided with pyramidal teeth 68b having symmetrical faces 68c as shown. Thus, anchor members such as anchor member 68a will anchor against forces tending to displace them in either axial direction.

Claims: A well tool for running into a well on a handling string for generating an axial force and applying it to an object at a subsurface location in a well flow conductor (22), the said well tool (300) comprising: (a) an upper tubular body member (302) having a longitudinal bore (56) extending therethrough and having means (306) at its upper end for attachment to a handling string (60), said upper body member (302) further including: (i) piston means (304) intermediate its ends, and (ii) pressure activated anchor means (75) for anchoring the body member (302) in said well flow conductor; (b) a second tubular body member (320) formed with an upper cylinder (324) which receives the said piston (304), the said piston dividing the upper cylinder (324) into power chamber (306) connected by passage means (84) to the said bore (56) and a vented exhaust chamber (308); and (c) means (335) at the lower end of the tool for attachment to an engaging tool (340); characterised in that the said second tubular body member (320) constitutes an intermediate body member formed with a lower cylinder (330) which receives a piston carried at the upper end of a third, lower tubular member (310), the lower end of which is provided with the said attachment means (335), and wherein both pistons (304,312) have limited strokes within the respective cylinders (324,330). The well tool of claim 1, wherein the said anchor means (75) includes piston slip means (68) movable radially outwardly by fluid pressure, passage means (64) for conducting power fluid to said piston slip means for activating the same, said piston slip means each having an external annular seal recess (72) formed therein, and a resilient seal (74) carried in said recess. The well tool of claim 1 or 2, wherein means (120) are provided for closing the bore (102) of said lower body member (310) to permit pressurization of said handling string for activation of the well tool. The well tool of claim 3, wherein the means for closing the said bore (102) comprises a seat (118) engageable by a valve member (120) to permit pressurizing the handling string to actuate said anchor means and to move at least one of said upper and lower pistons (304,312) in its respective cylinder (324,330). The well tool of claim 3, wherein said means for closing said bore of said lower body member to permit pressurization of said handling string for activation of the well tool comprises a removable closure device secured at a location below said lower piston.

Inventors: KILGORE MARION DEWEY, KILGORE, MARION DEWEY
Applicants: HALLIBURTON CO, HALLIBURTON COMPANY
Application year: 1990
Main classification: E21B23
IPC codes: E21B23, E21B31