US3252517A

US3252517A - Compression and tension set packer

Info

Publication number: US3252517A
Application number: US308972A
Authority: US
Inventors: William R Lewis; Willie W Farrar; James R Lindley
Original assignee: KIVA CORP
Current assignee: KIVA CORP
Priority date: 1963-09-16
Filing date: 1963-09-16
Publication date: 1966-05-24
Anticipated expiration: 1983-05-24

Description

W. R. LEWIS ETAL COMPRESSION AND TENSION SET PACKER 2 Sh@ets-Shea?l 1 Filed Sept. 16, 1965 INVENTORS 2 Sheets-Sheet 2 May 24, 966 w. R. LEWIS ETAL COMPRESSION AND TENSION SET PACKER Filed Sept. 16, 1963 .Mfr .mer www iw 5 Z3 MW@ f. m 4.5 r UMH Mw, oMnMM Www v.. B

FUE-'4 fjELE FjE-E United States Patent O 3,252,517 COMPRESSHON AND TENSION SET PACKER William R. Lewis, Willie W. Farrar, and .lames R. Lindley, Wichita Falls, Tex., assignors to Kiva Corporation, Wichita Falls, Tex., a corporation of Texas Filed Sept. 16, 1963, Ser. No. 308,972 13 Claims. (Cl. 166-134.)

This invention relates generally to improvements in subsurface tools useful in connection with operations performed in oil and gas wells or the like. More particularly, this invention relates to an improved retrievable `subsurface tool that can be used as a tension or compression-actuated packer and as a tubing anchor.

As is well known to those skilled in the art of drilling wells, -many different operations are performed in wells involving the use of subsurface well tools. During the drilling, completion and improvement of wells, operations such as cementing, fracturing, and acid'izing may require the use of a well packer. After the drilling of the well has been completed and the well cased, a production tubing will most often be suspended therein, generally requiring the use of a tool known as a tubing anchor. Of course, packers and anchors are used in other operations, but those listed above are believed to be exemplary.`

Sometimes, where a very small bore or slim-hole well is drilled, or where the well is extremely deep and requires the use of lightweight tubing, it is desirable to be able to set or actuate a packer by letting the weight of the tubing down on4 the packer rather than pulling up on the tubing to set the packer. This is particularly true when the stress in a tubing is very close to its rated tensile strength due to the weight of the tubing alone.

Compression and tension-set packers are both old and well known in the packer art, but it was not believed possible heretofore toV provide a relatively simply constructed packer that can be set by either method. Furthermore, since most packers now available incorporate the packing member as a part of the apparatus necessary to set the slips for mechanically holding the packer compressed and in place, it has not been practical to use the identical tool for a tubing' anchor simply by removing the packing elements.

In many operations performed in wells wherein packers are utilized, foreign materials, such as sand or cement, are introduced into the well. These foreign materials may enter the small `ports and passageways present in many types of packers, resulting in the packer sticking in the set position and requiring that it be drilled out. One type of packer in which this frequently occurs is in those set by hydraulic pressure.

One problem that sometimes occurs during the backwashing or reverse circulating associated with squeeze cementing, aciding, or fracturing operations is that fluids nd their way under the packer rubbers of an unset packer and expand the packer rubbers into sealing engagement with the casing. When this happens, backwashing is stopped, often leaving large amounts of unwanted cement, acid or sand in the well below the packer. Such a situation will then require that the packer be removed from the well and an expensive and time consuming cleanout job be performed.

One object of the invention is to provide a relatively simple subsurface tool that can be utilized as a tension' or compression-set packer and, by removing the packing means, be utilized as an anchor.

Another object of the invention is to provide an improved subsurface well tool that is mechanically actuated and positively locked in the unset position so that it cannot be inadvertently set.

Still another object of the invention is to provide a subsurface tool having an improved slip arrangement.

'ice

A further object of the invention is to provide an irnproved subsurface tool that incorporates features for jarring the tool loose should it become inadvertently locked in the set position.

A still further object of the invention is to provide an improved packer that cannot be inadvertently expanded during backwash or reverse circulating operations.

One aspect of the invention generally contemplates an improved retrievable well tool for use in a well casing or the like including a tubular mandrel and an expander means carried by the mandrel. v First and second slip means connected together slidingly encircle the tubular mandrel and are disposed above and below said expander means, respectively, and are adapted for coaction with the expander means and well casing to prevent movement of the tool either upwardly or downwardly through the casing. The tool also includes means connected with the `slip means adapted to frictionally engage the well casing, and control means interposed between the tubular mandrel and one of the slip means moveable between a first position and a second position. When in the fir-st position, the control means is adapted to prevent the coaction of the slip means with the expander means. When in the second position, the control means is adapted to permit coaction of the rst slip means and expander means or of the second slip means and expander means.

Another aspect of the invention generally contemplates a packer for use in a well casing or the like which is structurally similar to the well tool. The packer, in addition to the `structure already set out, includes a flange on one end portion of the tubular mandrel, packing means encircling the tubular mandrel above the flange, and expander means including a sleeve encircling said mandrel and having its lower end adapted for engagement with the packing means. The arrangement is such that upward movement of the mandrel relative to the sleeve compresses the packing means between the ange and the lower end of the sleeve, expanding the packing means into sealingsengagement with the well casing.

Other, further, and additional objects and advantages of the invention will become more apparent as the following description is read in conjunction with the attached drawings wherein .like reference `characters denote like parts in all views and wherein:

FIG. 1 is a cross sectional view of a well packer, constructed in accordance with the invention, shown in a well casing with the part-s in t-he positions they occupy while the packer is being moved through the casing;

FIG. 2 is an elevation View of the packer of FIG. 1, but showing the upper slips set and the packing means engaged with the casing;

FIG. 3 is a cross sectional View similar to FIG. 1, but showing the lower slips set and the packing means engaged with the well casing;

FIG. 4 is a cross sectional View similar to FIG. 1, but showing the parts in the positions they would occupy during a reverse circulation operation;

FiG. 5 is a cross sectional View of the packer, but showing it in the inverted position for use as a compression-set packer; and,

FG. 6 is an elevation view similar to FIG. 2, but having the packing means removed and illustrating its use as a tubing anchor.

Referring to the drawings, and to FIG. 1 in particular,

- shown therein is a well packer, generally designated by the portion 22, and a lower portion 24. The upper end 26 and the lowe-r end 28 of the upper portion 20; the upper end 30 and lower end 32 of the medial portion 22, and the upper end 34 and lower end 36 of the lower port-ion 24 are provided with male threads. The upper end 26 of the upper portion is secured to the coupling 14. The threads on the lower end 28 of the upper portion 20 are left-handed for purposes which will be explained more fully hereinafter.

A coupling 38 having interior threads is connected with the lower end 28 of the upper portion 20 and the upper end of the medial portion 22. Coupling 38 provides an upwardly facing shoulder 40 on the upper end thereof. A pin 42 extends radially outwardly from the coupling 38.

The lower end 32 of the medial portion 22 is secured in a threaded coupling 44. The upper end 34 of the lower portion 24 is likewise secured in the coupling 44. The coupling 44 provides a downwardly facing shoulder 46 that can be clearly seen in FIG. 3.

A flange member 48 is threadedly attached to the lower end 36 of the lower portion 24. The threads are formed in a left-hand fashion for purposes which will be described hereinafter.

Packing elements

50 and 52 are `shown encircling the tubular mandrel 18 just above the fiange member 48. The

packing elements

50 and 52 are separated by a spacer mem-ber 54. Just above the packing element 50 is a compression member 56 which also encircles the tubular mandrel 18. An O-ring seal 58 is located in a groove 60 in the compression member 56. The seal 58 engages the tubular mandrel 18, forming a fluidtight seal between the mandrel 18 and the compression member 56.

An abutment 62 is fixed to the lower portion 24 of the tubular mandrel 18 just above the compression member 56. The abutment is provided to prevent upward movement of the

packer elements

50 and 52 relative to the tubular mandrel 18. The abutment 62 also serves another purpose which will ybe explained in the description of the use of the tool as a tubing anchor.

An inner sleeve 64 slidingly encircles t-he lower portion 24 of the tubular mandrel 18. The lower end 65 thereof is provided with a horizontally extending flange portion 66 having a depending peripheral portions 68 adapted to engage the compresssion member 56. The ange portion 66 is constructed as shown and described to prevent wedging of objects between the flange portion 66 and well casing 16 as sometimes occurs when a downw-ardly tapering surface is utilized.

The inner sleeve 64 is also provided with an expander 70 near its upper end portion. As illustrated, the expander 70 includes `an upper surface 72 tapering upwardly, and inwardly, and a lower surface 74 tapering downwardly and inwardly. The expander 70 also has an inner diameter 76 for slidably encircling the coupling 44 and forming an upwardly facing shoulder 78 (see FIG. 3) adapted to engage the downwardly facing shoulder 46 on the coupling 44. A plurality of longitudinally extending grooves 80 are formed in the exterior of the expander 70. The purpose of the grooves S0 will become apparent as the description proceeds.

An upper slip assembly 82 slidingly encircles the upper and

medial portions

20 and 22, respectively, of the tubular mandrel 18 andthe coupling 38. The upper slip assembly 82 includes an upper sleeve 84 having an inside diameter 86 slightly larger than the outside diameter of the coupling 38. Attached to the upper end of sleeve 84, as by screws 88, is an annular spacer member 90 which provides a downwardly facing surface 92. An abutment 94 `attached to the upper portion 20 of the tubular mandrel 18 is enclosed by the upper sleeve 84 and is adapted for engagement with the downwardly facing surface 92 of the annular spacer member 90.

Depend-ing from and attached to the upper sleeve 84 are resilient springs 96 carrying slip members 98. As

illustrated, spring 96 are attached to the upper sleeve 84 by screws 100 and to the slip members 98 by screws 102. Springs 96 are biased to keep the slip members 98 out of contact with the well casing 16. Slip members 98 have casing-engaging teeth 104 formed in the exterior thereof and a tapered inner surface 106 adapted for coaction with the upper surface 72 of the expander 70.

A lower slip assembly 108 slidingly encircles the inner sleeve 64 and is connected with the upper slip assembly 82. The connection `between the upper and

lower slip assemblies

82 and 108 is accomplished by drag members 1.10 in the form of bow springs which are biased outwardly into frictional engagement with the well casing 16. Members 1110 are connected with the upper slip assembly 82 by screws or rivets 112 and with the lower slip assembly 188 by screws or rivets 114.

The preferred embodiment is provided with three radially-spaced drag members 118, but the exact number is insignificant so long as such members provide the centering and drag effects required, as hereinafter described. Grooves 80 which are aligned with the drag members 118, are provided to eliminate possible interference between the drag members 110 and the expander 70 during operation of the packer 10.

Lower slip assembly 108 includes an outer sleeve member 116 from which resilient springs 118 extend upwardly carrying lower slip members 120. Springs 118 are attached to the outer sleeve member 116 by screws V122 and to the lower slip members 120 by screws 124.

As clearly shown in FIG. 1, springs 118 bias the slip members away from the well casing 16.

The outer sleeve member 116 has `a longitudinal slot 126 extending upwardly from the bottom thereof. The slot 126 cooperates with a guide lug 128 attached to the inner sleeve 64 to prevent the outer sleeve member 116 from rotating relative to the inner sleeve 64. The arrangement of the lug 128 and slot 126 assures that the drag members 118 will remain aligned with the longitudinal grooves 80 on the expander 70.

Means for controlling the position of the upper slip assembly 82 and the lower slip assembly 188 relative to v the tubular mandrel 18 and the expander 70 is provided by a slot 130 in the upper sleeve 84 in which the pin 42 operates. While only one slot 130 is shown in any view, one or more additional slots may be provided if desired. Slot 130, as illustrated, is generally T shaped. With the pin 42 in `a horizontal leg portion 132 of the T, orAin the first position (portion 132 is best seen in FIG. l), the upper and lower slip assemblies 82 and 188 are prevented from engaging the expander 70 carried by the tubular mandrel 18. With the pin 42 in a vertical top portion 134 of the T, or in the second position, the upper slip assembly 82 or the lower slip assembly 188 can be engaged with the expander 70.

Operation As previously mentioned, a subsurface well tool, constructed -in accordance with the invention, can be utilized either as a tension-set packer, a compression-set packer, or as a tubing anchor. The operation of the tool will be described in the foregoing order.

When used as a tension-set packer, the packer 10 is attached by the coupling 14 to the tubing 12 and lowered into the well casing 16. During the lowering thereof into the well, the pin 42 is located in the horizontal leg portion 132 of the slot 138. Even though the drag members 110 are in frictional engagement with the casing 16, the upper sleeve 84 and outer sleeve 116 cannot move relative to the expander 70; therefore, the slip members cannot engage the expander 70 and are biased away from the well casing 16 by the

resilient springs

96 and 118. The

packing elements

50 and 52 cannot be expanded into engagement with the well casing 16 until either the upper slip assembly 82 or the lower slip assembly 108 coacts with the expander 70 and the l casing 16 to prevent the movement of the packer 1t) in the wellv casing. It should be apparent that when the pin 42 is in the horizontal leg portion 132 or the rst position of the slot 130, the packer is positively restrained from becoming inadvertently set while moving through the well casing 16.

Upon reaching the location in the casing 16 where the packer 18 is to be set, the tubing 12 is rotated and through the -coupling 14 also rotates the tubular mandrel 18. Relative rotation between the tubular mandrel 18, which carries the pin .42, and the upper and lower slip assemblies 82 and 188 is accomplished due to the frictional engagement of the drag members 111D with the casing 16. When the pin 42 enters the vertical leg portion 134 or second position of the slot 130, rotation of the tubing 12' and tubular mandrel 18 is stopped. An upward pull is then imparted to the mandrel 13 through the tubing 12. The drag members 110, which are in frictional engagement with the casing 16, restrain the upper slip assembly 82 and lower slip assembly 108 against the upward movement. The flange member 48, attached to the lower end of the tubular mandrel 18, moves upwardly carrying the packing elements S0 and 52, the compression member 56, and the inner sleeve 64 therewith.

The relative movement between the inner sleeve 64, which has the expander 7l) thereon, and the upper slip assembly 82, results in the upper surface 72 of the expander 7l) engaging the -tapered inner surfaces 186 of the -upper slip members 98. Coaction between the sur- `faces 72 and 186 drives the slip members 98 into hold'- ing engagement with the well casing 16. The teeth 104 on the slip members 98 are provided to enhance the holding engagement of the slip members 98 with the casing 16 After the slip members 98 have firmly engaged the casing 16, additional upward movement of the mandrel 18 compresses the

packingelements

50 and 52, the spacer member "54, and the compression member 56 between the depending peripheral portion 68 of the ange portion 66 carried by the inner sleeve 64. Such compression results in the expansion of the

packing elements

50 and 52 into sealing engagement with the well casing 16, as shown in FIG. 2.

The packer 10 is released by moving the tubing 12 and tubular mandrel 18 downwardly. Such downward movement releases the compression forces exerted on the

packing elements

58 and 52, whereupon they return to their original shape and out of engagement with the casing 16. The expander 78 is driven out from under the slip members 98 by the engagement ofthe downwardly facing shoulder 46 on the coupling 44 with the upwardly facing shoulder '78 formed by the inner diameter 76 of the expander '78.

After the packer 18 has been unseated, the tubing 12 is rotated, moving the pin 42 into the horizontal leg portion 132 of the slot 138. As previously pointed out, movement of the pin 42 in the slot 130 is possible due to the resistance to rotation of the drag members 110 which are in frictional engagement with the casing 16. The upper sleeve 84, in which the4 slot 131) is formed, is attached to the drag members 110 and therefore remains substantially stationary while the tubular mandrel 18 carrying the pin 42 is liiree to rotate with the tubing 12. The various parts of the packer 10 are again mechanically locked so that they cannot become inadvertently iset during remo-val of the packer 10 `from the casing 16.

Sometimes during operations performed in wells utilizing the packer 10 set therein as previously described, pressure is applied above the packer 18. As a result of the pressure applied above the packer 10, the tubing 12 will stretch longitudinally permitting the packer 10 to slip down in the casing 16. FIG. 3 illustrates the positions of the various parts when the packer 10 is forced down the well by pressure applied as described. As shown therein, the

packing elements

50 and 52 remain in sealing engagement with the casing 16. With pressure applied from above the tiange portion 66 of the inner sleeve 64, the compression member 56 and the

packing elements

50 and 52 are subjected to the downwardly exerted hydraulic pressure and to the upward force exerted by the flange member 48 as the tubing 12 resists stretching. Consequently, the inner sleeve 64 and the expander 70 carried thereby are moved downwardly out of engagement with the upper slip members 98 and into engagement with the lower slip members 128. The slip members 98 and 12) remain in a relatively xed position due to the frictional engagement of the drag members 110 with the casing 16, thereby providing the Irelative movement required to permit the engagement of the lower slip members 128 with the expander 70. Upon such engagement, the slip members 120 a-re forced into holding engagement with the casing 16, preventing further downward movement of the packer 10 therein.

Fracturing, acidizing, and squeeze cementing operations require that excess uids, eng., acid, sand-oil, and cement slur-ries be removed from within the casing 16 be- .low the packer 10 after completion of the operation.

The removal of such fluids is :accomplished by backwashing or reverse circulation. This process involves pumping a clean-out lluid down the casing 16 outside of the tubing 12 and packer 10 and then up through the interior of the tubing 12. '.[lhe packer of this invention is utilized in such a process by unseating the packer 10, als previously described, but keeping the pin 42 in the vertical top portion 134 of the slot 130.

After thel packer 10 is unseated, the tubing 12 is low-V ered in the casing 16, moving the downwardly facing shoulder 46 on the coupling 44 into engagement with the upwardly facing shoulder 78 in the inner sleeve 64. Further downward movement of the tubing 12 forces the expander 70 into engagement with the lower slip member 120, causing it t-o move into holding engagement with the casing 16. It should be noted that the

packing elements

50 and 52 are not compressed in the foregoing manipulation. Wit-h the various parts in this position, as illustrated in FIG. 4, the packer 10 and tubing 12 are centered and restrained in the casing 16 and the loleanout fluid can be cinculated as required.

One -pnoblem that sometimes occurs in the reverse cir culation or backwashing operation is that the cleanout iuids tend to become entrapped between the packing elements 50 'and 52 and the outside of the tubular mandrel 18, as was previously pointed out. If such were to occur, the

packing elements

50 and 52 would expand into engagement with'the casing 16 or yat least severely restrict the flow area between the elements and the casing 16. To prevent such encroachment of the oleanout uids, the compression member 56 has been provided with a groove 60 which carries an O-ring seal 58. The seal 58'cooperates with the compression member 56 and the tubular mandrel 18 to prevent the ilow of fluids therebetween. The provision off the iseal 58 has proven to be 'an effective means of preventing the expansion of the

packing elements

50 and 52 during reverse circulation.

Should the tool of this invention become stuck in the casing 16, apparatus constituting a jarring mechanism is built into the tool. When the tool has become stuck, the tubing 12 ils rotated to the right, loosening the left-hand thread on the lower end 28 of the upper portion 20 of the tubular mandrel 18. Once the upper portion 20 is disengaged from the coupling 38, the tubing 12 and the upper portion 20 can be moved vertically a small distance independent of the packer 10. As previously described, an abutment 94 is xed to the upper portion 2) of the mandrel 18. Raising the tubing 12 brings the abutment 94 into contact wit-h the downwardly facing shoulder 92 otf the annular spacer member which is fastened to the upper sleeve 84. A -force applied to the tubing 12 will be transmitted through the abutment 94 to the upper sleeve 84 thence to the upper slip members 98, disengaging them from the casing 16 and expander 70. With such an arrangement, it should be aparent that la steady pull can be applied to release the tool or that short jerks can be applied to jar the tool loose.

When used as a compression-set packer, no changes or modifications are requiredv in the tool. As shown in FIG. 5, the packer 10 is simply inverted and the tubing 12 attached to the ange member 48. The threads joining the lower end 36 of the lower portion 24 are left-handed to prevent the loosening thereof while positioning the pin 42 in the slot 130.

The packer 10 is run into the casing 16 on the tubing 12 with the pin 42 in the horizontal leg portion 132 of the slot 130. Upon reaching the desired position in the casing 16, the tubing 12 and tubular mandrel 18 are rotated to move the pin 42 into the vertical top portion 134 of the slot `13G). The tubing 12 is then lowered so that the mandrel 18, ange member 48, packing

elements

50 and 52, compression member S6, and inner sleeve 64 move downwardly. The expander 70, carried by the inner sleeve 64, moves relative to the upper slip members 98 (now below the expander 70), until the slip members 98 are engaged by the expander 70. The engagement of the slip members 98 with the expander 70 forces the slip members 98 into holding engagement with the well casing 16. Additional weight is permitted to rest on the packer 10. The additional weight forces the flange member 48 and the tubular mandrel 18 downwardly, compressing the packing element-

s

50 and 52, the spacer member 54, and the compression member S6 against the end 65 of the inner sleeve 64. As the weight is applied, the compression of the

packing elements

50 and 52 expands them outwardly into sealing engagement with the well casing 16.

Release of the packer 10 is accomplished by raising the tubing 12. Upward movement of the tubing 12 raises the tubular mandrel 18, bringing the shoulder 46 on the coupling 44 into' contact with the shoulder 78 in the expander 70 and then forcing the expander 70 out of engagement with the slip members 98. The tubing 12 is then rotated to move the pin 42 into the horizontal leg portion 132 of the slot 130.

The packer 10, when set by compression, is arranged to hold against pressures applied from above. It should be apparent that pressures applied below the packer 10 may result in the upward movement of the packer 10 in the casing 16. Should such movement occur, the expander 70 will move into engagement with the lower slip members 120, thus preventing any additional upward movement.

Another important aspect of the invention is the use of the tool as an anchor by removing only the packing means therefrom. It can be observed by comparing FIG. 2 with FIG. 6 that the only difference is that the ange member 48, the packing elements t) and 52, the spacer member 54, compression member 56, and the liange portion 66 have been removed. The ange portion 66 does not have to be removed, but with it removed less protrusions are present that might hang in the casing 16 `as the tool is lowered therein.

The operation of the anchor is identical to that of the tension-set packer, except that the abutment 62 engages the lower end 65 of the inner sleeve 64 to move the expander 70 into engagement with upper slip member 98. For all practical purposes, the difference in operation is insignicant.

One other feature of the invention, not previously mentioned, is that should the tubing 12 part above the t-ool, the lower slip assembly 108 will coact with the expander 70 to keep the tool from falling. This feature is available, however, only when the pin 42 is in the vertical top portion 134 of the slot 130. It is important to note that failure of the tubing 12 usually occurs after 8 the tool is set, i.e., when the pin 42 is in the vertical top portion 134 of the slot 130.

It should be apparent from the foregoing description that a tool, constructed in accordance with the invention, provides novel features not heretofore available in a single tool.

It should also be apparent from the foregoing that the invention provides a unique construction permitting the tool to be utilized as a tension-set packer or a compression-set packer with no modifications or changes, and as an anchor by the simple removal of the packing means from the tool.

The foregoing detailed description of one embodiment of the invention is by way of example and it should be realized that many changes and modiiications may be made therein without departing from the spirit of the invention or from the scope of the annexed claims.

What we claim is:

1. A well tool for use in a well casing or the like including:

a tubular mandrel;

expander means carried by said tubular mandrel for vertical movement therewith; iirst slip means slidingly encircling said tubular mandrel above said expander means adapted to coact with said expander means and the well casing to prevent upward movement of the tool through the well casing; second slip means slidingly encircling said tubular mandrel below said expander means connected with said lirst slip means and adapted to coact with said expander means and the well casing to prevent downward movement of the tool through the well casing;

means connected with said slip means adapted for frictional engagement with the well casing; and,

control means moveable between a first and second position interposed between said tubular mandrel and one of said slip means adapted to prevent coaction of said slip means with said expander means when in the first position and to permit coaction of either first slip means and expander means or Said second slip means and said expander means when in the second position.

2. A well tool for use in a well casing or the like including:

a tubular mandrel having abutment means on thc lower end thereof;

yan inner sleeve member slidingly encircling said mandrel above said abutment;

expander means on the upper end portion of said inner sleeve member;

upper slip means slidingly encircling said mandrel above the expander means adapted to coact with said expander means and the well casing to prevent upward movement of the tool through the well caslower slip means slidingly encircling said inner sleeve member below the expander means connected with said upper slip means and `adapted to coact with said expander means and the well casing to prevent `downward movement of the tool through the well casing;

means connected with said upper and lower slip means adapted for frictional engagement with the well casing; and,

control means moveable between a first and second position interposed between said upper slip means and tubular mandrel adapted to prevent coaction of said upper and lower slip means with said expander means when in the rst position and to permit coaction of either the upper or lower slip means with the expander means when in the second position. 3. A well tool for use in a well casing or the like including:

a tubular mandrel having abutment means on the lower end thereof;

an inner sleeve member slidingly encircling said mandrel above said abutment;

upper and lower expander means on the upper end portion of said inner sleeve member;

an upper sleeve member slidingly encircling said mandrel above the upper expander means;

an outer sleeve member slidingly encircling the inner sleeve member below the lower expander means;

means connecting said upper and outer sleeve members adapted for frictional engagement with the well casing;

upper slip members downw-ardly pendent from said upper sleeve member adapted to coact with said upper expander means and the well casing to prevent upward movement of the tool through the well casing;

lower slip members upwardly pendent fromsaid outer sleeve member and adapted to coact with said lower expander means and the well casing to prevent downward movement of the tool through the well casing; and,

control -means moveable between a first and second position interposed between said upper sleeve member and tubular mandrel adapted to prevent coaction of said slip means with said expander means when in the first position and to permit coaction of either the upper expander means and upper slip means or said lower slip means and lower expander means when in the second position.

4. A well tool for for use in a well casing or the like including:

a tubular mandrel having an upper end and a lower end, means forming a downwardly facing shoulder near the medial portion thereof, and abutment means on the lower end thereof;

an inner sleeve member slidingly encircling said mandrel between said downwardly facing shoulder and said abutment means;

expander means on the upper end of said inner vsleeve member including means forming an upwardly facing shoulder adapted to engage said downwardly facing shoulder, and having an upwardly and inwardly tapering upper surface and a downwardly and inwardly tapering lower surface;

an upper sleeve member slidingly encircling said tubular-mandrel above said expander means and having a slot formed therein;

upper sl-ip members resiliently connected to said upper sleeve member adapted to coact with the upwardly and inwardly tapering surface on said expander means and with the well casing to prevent upward movement of said tool in the well casing;

an outer sleeve member slidingly encircling said inner sleeve member below said expander means and connected with said upper sleeve member;

lower slip members resiliently connected to said outer sleeve member adapted adapted to coact with said downwardly and inwardly tapering surface on said expander means and well casing to prevent downward movement of the tool in the well casing;

resilient means connected with said upper sleeve member and said outer sleeve member adapted to frictionally engage the well casing; and,

control means including a pin fixed to said tubular mandrel and operable in said slot whereby movement of said pin into `one portion of said slot prevents coaction between the upper and lower slip members and said expander means and movement of said pin into another portion of said slot permits coaction between either said lower slip members and said expander means or between said upper slip members and said expander means.

5. A well tool for use in a well'casing or the like including:

expander means carried by said lower portion for vertical movement therewith;

upper slip means slidinglyencircling said upper porti-on of said tubular mandrel above said expander means adapted to coact with said expander means and the well casing to prevent upward movement of the tool through the well casing and having a downwardly facing shoulder therein adapted to engage said rst abutment means;

lower slip means slidingly encircling said lower portion of said tubular mandrel below said expander means connected with said upper slip means and adapted to coact with said expander means and the well casing to prevent downward movement of the tool through the well casing;

means connected with said slip means adapted for fric tional engagement with `the well casing; and,

control means moveable between a first and second position interposed between said tubular mandrel and said upper slip means adapted to prevent coaction of said slip means with said expander means when in the rst position and to permit coaction between either said upper slip means with said expander means lor said lower slip means with said expander means.

6. A packer for use in a well casing or the like including a tubular mandrel having a radially extending flange member on one end portion thereof; g

packing means encircling said mandrel above said flange member;

an inner sleeve member slidingly encircling said tubular mandrel above said packing means and having the lower end thereof adapted for engagement with said packing means;

expander means on the upper end portion of said inner sleeve member;

upper slip means slidingly encircling said tubular mandrel adapted to coact with said expander means and the well casing to prevent upward movement of the packer through the well casing;

lower slip means slidingly encircling said inner sleeve member and connected with said upper slip means adapted to coact with said expander means and the well casing to prevent downward movement of the packer through the casing;

`means connected with said slip means adapted for frictional engagement with the well casing; and

control means moveable between a first and second position -interposed between said tubular mandrel and upper slip means adapted to prevent coaction of said includes:

a compression member slidingly encircling said tubular mandrel; and,

a resilient packing element encircling said tubular mandrel between said compression member and the -flange member on said tubular member.

8. The packer of claim 6 wherein said packing means includes:

a compression member slidingly encircling said tubular mandrel;

sealing means disposed between said compression member and tubular mandrel; and

a resilient packing element encircling said tubular member between said compression member and the flange member on said tubular member.

9. The packer of claim 6 wherein said packing means includes:

a compression member slidingly encircling said ytubular mandrel;

sealing means disposed between said compression member and tubular mandrel;

a plurality of resilient packing elements encircling said tubular mandrel between said compression member and the flange member on said tubular mandrel; and,

spacer means encircling said tubular mandrel disposed between said packing elements.

10. A packer for use in a well casing or the like including: V

a tubular mandrel having a ange member on the lower end thereof;

packing means encircling said mandrel above said ange member;

said packing means including a compression member slidingly encircling said -tubular mandrel, sealing means disposed 'between said compression member and tubular mandrel, and a resilient packing element encircling said tubular mandrel between said compression member and llange member;

an inner sleeve member slidingly encircling said mandrel above said packing means and having the lower end thereof adapted for engagement with said compression member;

an outer sleeve member slidingly encircling said inner sleeve member below the lower expander means;

`upper slip members downwardly pendent from said upper sleeve member adapted to coact with said expander means and the well casing to prevent upward movement of the tool through the well casing;

lower slip members upwardly pendent from said outer sleeve member and adapted to coact with said lower expander means and the well casing to prevent downward movement of the tool through the well casing; and,

control means moveable between a rst and second position interposed between said upper sleeve member and tubular mandrel adapted `to prevent coaction of said slip means with said expander means when in the Iirst position and to permit coaction of either the upper expander means and upper slip means or said lower expander means and lower slip means when in the second position;

the arrangement being such that upward movement of said mandrel and ange member relative to said inner sleeve member compresses said packing element between said compression member and flange member expanding said packing element into sealing engagement with the well casing.

11. A packer for use in a well casing or the like including;

a tubular mandrel having an upper end and a lower end, means forming a downwardly facing shoulder near the medial portion thereof, and a flange member on the lower end thereof;

packing means encircling said tubular mandrel above said ange member;

an inner sleeve member slidingly encircling said mandrel between said downwardly facing shoulder and said flange member and having the lower end thereof adapted to for engaging said packing means;

expander means on the upper end of said inner sleeve member including means forming an upwardly facing shoulder adapted .to engage said downwardly facing shoulder, and having an upwardly and inwardly tapering upper surface and a downwardly and inwardly tapering lower surface;

an upper sleeve member slidingly encircling said tubular mandrel above said expander means and having a slot formed therein;

upper slip members resiliently connected to said up'- per sleeve member adapted to coact with the upwardly and inwardly tapering surface on said expander means and with the well casing to prevent upward movement of said packer in the well;

lower slip members resiliently connected to said outer sleeve member adapted to coact with said downwardly and inwardly tapering surface on said expander means and with the well casing to prevent downward ment of the packer in the well casing;

control means including a pin xed to said tubular mandrel and operable in said slot whereby movement of said pin into one portion of said slot prevents coaction between the upper and lower slip members and said expander means and movement of said pin into another portion of said slot permits co-action between either said lower slip members and said expander means or between said upper members and said expander means;

the arrangement being such that upward movement of said mandrel and iange member relative to said inner sleeve member compresses said packing means between said flange member and the lower end of said inner sleeve member expanding said packing means into sealing engagement with the well casing.

12. The packer of claim 11 wherein said packing means includes:

a compression member slidingly encircling said tu bular mandrel;

sealing means disposed between said compression member and tubular mandrel;

a plurality `of resilient packing elements encircling said tubular mandrel between said compression membe1 and the ange member on said tubular mandrel; an

13. A packer for use in a well casing or the like including:

a tubular mandrel having a radially extending ange member on one end portion thereof;

packing means encircling said mandrel above said flange member;

expander means on the upper end portion of said inner sleeve member;

upper and lower slip means slidingly encircling said mandrel and disposed above and below said expander means, slips being adapted to coact with said expander means and the casing to prevent movement of said packer either upwardly or downwardly through the casing; and,

control means moveable between a first and second position interposed between said slip means and said tubular mandrel and adapted to prevent coaction of said slip means with said expander means when in the lirst position and to permit coaction of said slip means With said expander means when in the second position;

the arrangement and construction being such that upward movement of said mandrel and ange member relative to said inner sleeve member compresses said packing means between said ange member and the lower end of the inner sleeve member expanding said packing means into sealing engagement with the well casing.

References Cited by the Examiner UNITED STATES PATENTS CHARLES EOCONNELL, Primary Examiner. BENJAMIN HERSH, Examiner.

J. A. LEPPINK, Assistant Examiner.

Claims

1. A WELL TOOL FOR USE IN A WELL CASING OR THE LIKE INCLUDING: A TUBULAR MANDREL; EXPANDER MEANS CARRIED BY SAID TUBULAR MANDREL FOR VERTICAL MOVEMENT THEREWITH; FIRST SLIP MEANS SLIDINGLY ENCIRCLING SAID TUBULAR MANDREL ABOVE SAID EXPANDER MEANS ADAPTED TO COACT WITH SAID EXPANDER MEANS AND THE WELL CASING TO PREVENT UPWARD MOVEMENT OF THE TOOL THROUGH THE WELL CASING; SECOND SLIP MEANS SLIDINGLY ENCIRCLING SAID TUBULAR MANDREL BELOW SAID EXPANDER MEANS CONNECTED WITH SAID FIRST SLIP MEANS AND ADAPTED TO COACT WITH SAID EXPANDER MEANS AND THE WELL CASING TO PREVENT DOWNWARD MOVEMENT OF THE TOOL THROUGH THE WELL CASING; MEANS CONNECTED WITH SAID SLIP MEANS ADAPTED FOR FRICTIONAL ENGAGEMENT WITH THE WELL CASING; AND, CONTROL MEANS MOVABLE BETWEEN A FIRST AND SECOND POSITION INTERPOSED BETWEEN SAID TUBULAR MANDREL AND