US2683492A

US2683492A - Subsurface well tool

Info

Publication number: US2683492A
Application number: US246106A
Authority: US
Inventors: Reuben C Baker
Original assignee: Baker Oil Tools Inc
Current assignee: Baker Hughes Oilfield Operations LLC
Priority date: 1950-07-10
Filing date: 1951-09-11
Publication date: 1954-07-13
Anticipated expiration: 1971-07-13
Also published as: US2687775A

Description

y 3, 1954 R. c. BAKER 2,683,492

SUBSURFACE WELL TOOL Original Filed July 10,- 1950 3 Sheets-Sheet 2 INVEVTOR. REUBEN 6. BAKER,

A rraezvsxf y 1954 R. c. BAKER 2,683,492

SUBSURFACE WELL TOOL Original Filed July 10, 1950 3 Sheets-Sheet 3 IN VEN TOR.

REUB N C. BAKEQ,

Ar ram/5Y5 Patented July 13, 1954 UITED STAT TENT OFFICE SUBSURFACE WELL TOOL Reuben C. Baker, Coalinga, Calif., assignor to Baker Gil Tools, Inc., Vernon, Calif., a corporation of California 11 Claims.

initially retracted well tool slip segments between their retracted and expanded positions.

Yet a further object of the invention is to provide a slip arrangement for a well tool that insures maintenance of the slips in retracted position while the tool is being run in the well bore,

and which resists premature outward expansion of the slips.

lhis invention possesses many other advan tages, 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:

Figures 1a lb together constitute a longitudinal section through a well apparatus, with the parts arranged for running the equipment in a well bore, Fig. lb being a lower continuation of Fig. in;

Fig. 2 is an enlarged longitudinal section through a portion of the apparatus;

Fig. 3 is a cross-section taken along the line 3-3 on Fig. 2;

a view similar to Fig. 1b, disclosing the packer portion of the apparatus anchored in packed-eff condition within a well casing;

5 is a cross-section taken along the line 5-5 on Fig. lb;

Fig. 6 is a cross-section taken along the line G-t on Fig. l;

Fig. 7 is a section taken along the line 7-! on Fig. 5;

Fig. 8 is a fragmentary side elevation taken along the curved line 8-8 on Fig. 5;

Fig. 9 is a cross-section taken along the line 9-9 on Fig. 113;

Fig. 10 is a view similar to Fig. 9 of the slip member expanded against the casing;

Fig. 11 is a section taken along the line ll-ll on Fig. 9;

Fig. 12 is a side elevation taken along the curved line l2l2 on Fig. 9; and

Fig. 13 is an enlarged fragmentary longitudinal section of the lower slip guide arrangement.

In the form of the invention disclosed in the drawings, it is desired to run a well packer A to a desired location in a well casing B disposed within a bore hole. The packer is then anchored in packed-off condition against the well casing through use of a setting tool C connected to it. This setting tool is attached to the lower end of a running-in string D, such as a wire line, extending to the top of the well bore.

The general organization of setting tool C and well packer A is described and claimed in my application for Apparatus for Operating Tools in Well Bores, Serial No. 80,851, filed March 11, 1349, now Patent No. 2,640,546.

The packer A includes a tubular body it having a body abutment ll threaded on its lower end, and an enlarged head l2 at its upper end, along which the skirt 13 of a cylinder M is slidably mounted. A cylinder head [5 extends inwardly from the lower end of the skirt and slide.- bly engages the external cylindrical surface of the body It. Body ports is provide communication between the interior of the body and the cylinder 14, leakage between the body and cylinder being prevented by the side seal rings ll. The packer disclosed can be run on a tubing string if desired. and set hydraulically, which necessitates the use of the ports I 6 and seal rings ll. When the present setting tool C is used, however, the ports [6 and rings l'l may be omitted, although such omission is not essential.

A set of upper segmented slips N3 is disposed around the body It immediately below the cylinder head 65. These slips are held initially in retracted position by shear screws i9, attaching them to an upper conical expander 28 initially se cured to the body by one or more shear screws 2 I. The converging surfaces of the upper set of slips :8 and upper expander 29 are so disposed with respect to one another as to secure the packer A against movement in an upward direction within the casing B, following outward expansion of the slips l8 into engagement with the casing.

A set of lower segmental slips 22 is provided adjacent the body abutment II, and these slips are also secured by shear screws 23 to a lower tapered expander 24 attached initially to the body ill by one or more shear screws 25. The direction of taper on the exterior of the lower expander 24 and the taper on the cooperable surfaces of the lower slips 22 are such as to hold the well packer A against movement in a downward direction, following expansion of the slips 22 outwardly against the casing B.

A suitable lock is provided between the body i and the upper expander 20 to permit upward movement of the body [0 within this expander, but to preclude its downward movement. Such lock may be of any suitable form. It is illustrated as including a split ring 26 received within a groove 21 in the upper expander and engageable with the downwardly facing ratchet teeth 23 on the body.

A suitable packing 29, such as a packing sleeve, of rubber or similar pliant, elastic material, is disposed around the body l0 between the upper and

lower expanders

20, 24. The ends of the packing sleeve are received within annular pockets formed between the expander skirts 30 and the exterior of the body.

In setting the packer A, a downward force is exerted on the cylinder sleeve M of sufficient extent to shear the screws 19 attaching the upper slips 18 to the upper expander 20. These slips are then moved downwardly along the upper expander and radially outward into anchoring engagement with the well casing. Such outward expansion of the upper slips It can occur, since their retaining shear screws l9 have a lesser combined shear value than the shear screws 2! attaching the upper expander 20 to the packer body l0. These last-mentioned screws have a lesser shear value than the screws 25, 23 holding the lower expander 26. to the body and the lower slips 22 to the lower expander.

After the upper slips I3 have been engaged with the well casing, an upward strain or pull is im parted to the packer body 10, which shears the screws 2| holding the upper expander 20 to the body, and moves the lower expander 24 and lower slips 22 with the body toward the upper expander. This action foreshortens the packing sleeve 29 and effects its outward expansion into firm sealing engagement with the wall of the casing B.

Thereafter, an increase in the upward pull or force on the packer body Iii substantially simul taneously shears the screws 25, 23 holding the lower expander 2 to the body and the lower slips 22 to the lower expander, causing the lower body abutment H to shift the lower slips 22 upwardly along the lower expander and radially outward into anchoring engagement with the wall of the casing. The split, contractible lock ring 26 then engages the ratchet teeth 28 formed on the body to lock the latter against downward movement, since such downward movement is transmitted through the upper expander 20, packing 29, lower expander 24 and lower slips 22 to the well casing B. Upward movement of the body is resisted by the engagement of the lower abutment II with the lower slips 22, the upward force being transmitted from the latter through the lower expander 24, packing sleeve 29, upper expander 20 and upper slips [8 to the well casing 13 (see Fig. 4).

In the manner just described, the well packer A is anchored in packed-oil condition against longitudinal movement in both directions within the wall casing B.

The well packer disclosed is designed primarily for use in producing oil and gas wells. It has a central bore or passage 3|, which can be closed by a flapper valve head 32 pivoted on the abutment II and urged by a spring 33 to closed position against a body abutment valve seat 34. A slotted junk pusher and feeler 35 may be attached to the abutment I I to prevent premature setting of the packer during its descent in the well casing.

It is desired to provide an arrangement which will enable the well packer A to be run in the well casing B in a rapid manner. Such expeditious lowering of the well packer in the well casing can be accomplished through use of a wire line D. It is desired to set the packer fully and firmly against the casing without imposing a strain on the wire line. A substantially large strain or pull on the packer parts may be required, and, for this reason, the mechanism for setting the packer must be capable of transmitting a large force and of automatically releasing itself from the well packer when the desired maximum force has been exceeded. Moreover, it is desired to set a type of packer which is used primarily in the production of oil, gas, and the like, and which has the un obstructed central passage 3| therethrough, in order to permit subsequent movement of production equipment into or through the packer.

The above purposes are effectuated with the equipment disclosed in the drawings. As shown therein, setting of the well packer is dependent upon the development of a gas pressure within the setting tool C secured initially to the well packer. This gas pressure is developed within the upper portion of a cylinder 38, consisting of a generally cylindrical sleeve 3?, an upper head 32 threaded into the sleeve, and also a lower head 39 threaded into the sleeve.

A motivating gas under pressure is generated in the cylinder, and this force is imposed upon a piston 46 slidably mounted in the cylinder. This piston 36 has one or more ring grooves ll in its periphery for the accommodation of seal rings 53, to prevent leakage between the piston it and cylinder sleeve 31. As disclosed, these rings 41; may consist of rubber, round in cross-section, to guard against leakage in both directions.

The upper end of a piston rod 49 is threadedly connected to the piston 46, the rod extending downwardly through the lower cylinder head 39 to a point therebelow, where an anvil or crosspiece 50 is mounted within a transverse slot 5| in the rod. Leakage between the rod 49 and lower cylinder head 39 is prevented by suitable rod packing 52, in the form of one or more round rubber or rubber-like seals, engaging the periphery of the rod and disposed within suitable ring grooves 53 in the head. The packing or seal rings 52 prevent leakage of liquids from the well casing into the cylinder below the piston 46, insuring that air under atmospheric pressure is present below the piston 43 when the apparatus is assembled and lowered in the well casing.

It is desired to transfer the downward movement of, or force imposed upon, the piston 56 and the piston rod 49 to the upper slips it? of the packer, and the relative upward movement of the cylinder 36 to the packer body it, in order to obtain the desired anchoring of the packer in the well c sing, in the manner described above. To accomplish this purpose, a tubular actuating mandrel 54 is threadedly connected to the lower cylinder head 39. The lower end of this mandrel 54 is coupled to the packer body i0 through the agency of a frangible connecting device. As specifically disclosed, the lower end of the mandrel 54 is threaded into an adjuster sub 54a, which is threaded onto the upper end of a tension rod 55 extending downwardly within the packer body Ill. The lower end of this rod is threaded into a tension head 55 screwed onto the upper end of a releasing stud 5? having an intermediate portion 51 of reduced diameter. The lower end of this stud is threaded into a depending shank 58, that is, in turn, secured to a latch retaining abutment as having an upward and inwardly inclined face iii). The cylindrical portion 61 of the abutment engages the packer valve head 32, to hold it in open position.

Any upward force imposed upon the tension rod 55, tension head 5", releasing stud 5?, shank 55 and retaining abutment 59 is adapted to be imparted to the packer body Hi. This force is transferred from the inclined face 69 of the retaining abutment onto companion inclined, inner faces 52 on latch feet 63 integral with springlike leg members 5:? forming the lower portion of a latch sleeve 65, which extends upwardly to a point along the tension head 56. At this point, the sleeve is provided with an inturned shoulder 55 that can be spaced upwardly from a lower flange or shoulder 61 on the tension head 55. The outer inclined faces 63 of the latch feet engage the valve seat M on the body abutment ii, and serve to transmit any upward force imposed on the retaining abutment 59 directly to the packer abutment l i, which forms part of the packer body Hi.

When the parts forming the mechanism for coupling or looking the tension rod 55 and tension head 55 to the packer abutment H occupy the position shown in Figs. lb and 4, the latch sleeve shoulder 55 is disposed a substantial distance above the tension head shoulder 61. The inclined face 65 of the retaining abutment 59 bears upon the inclined faces 62 of the latch feet 63 and tends to urge and hold them out wardly against the valve seat 34. Such outward movement may be limited by engagement of the lower portions 65 of the spring legs 84 with the inner surface iii of the packer abutment.

Upon the exertion of sufficient tension on the releasing stud 5? to pull it apart, the shank 5% and retaining abutment 59 may drop downwardly, as explained in my above-identified application, to remove the abutment 59 from its retaining position behind the latch feet 63, and allow the latter to be disen aged from the packer abutment ii, The latch retaining abutment 55 and its shank 58 can drop to the extent limited by the engagement of its shoulder H with an inwardly directed flange 12 on a retrieving sleeve it threaded onto the lower end of the tension head 55.

Following disruption of the releasing stud 5? and dropping of the latch retaining abutment upward movement on the tension rod 55 will lift the tension head 56 with it, causing the shoulder 51 on the latter to engage the upper shoulder 65 on the latch sleeve 65, pulling the latch legs 5d and their foot portions 63 upwardly and inwardly within the packer body 10.. Such upward movement of the tension rod 55 and tension head 55 also causes the retrieving sleeve shoulder 12 to engage the shoulder H on the shank 58 and elevate the retaining abutment 55 through the packer. It is to be noted that all of the locking elements, with the exception of the spring-like foot portions 53 on the latch sleeve 65, are smaller in diameter than the internal diameter of the passage 3| through the packer body 10. Since the spring-like feet 53 and legs 5d can flex inwardly, the entire locking mechanism may be removed from a set well packer A, and removed with the remaining portions of the setting tool C to the top of the well bore. It is also to be noted that the initial distance between the latch sleeve shoulder 65 and tension head shoulder 56 is substantially less than the distance between the shank shoulder H and retrieving sleeve shoulder 12. This disparity in distance insures against the abutment 59 again moving within the latch feet 63 during elevation of the setting tool after disruption of the stud 51.

The piston rod 19 is movable downwardly within the bore '15 of the actuating mandrel 54, the cross-piece 50 projecting in opposite directions from the rod 4a through diametrically opposed longitudinally extending slots 15 formed through the mandrel wall. The cross-piece 5! also extends into opposed slots 71 formed through a setting ring or sleeve 18 slidably mounted on the actuating mandrel 54, to form a connection between the piston rod and the setting ring 18. A setting sleeve or skirt 19 is adjustably threaded on the setting ring 18, the lower portion of the skirt being secured to a ring resting on top of the packer cylinder sleeve [3.

As indicated above, a gaseous force or pressure is imposed upon the piston 46. This force moves the piston and piston rod 49 downwardly and the cylinder 36 in a relative upward direction. The downward movement of the rod 49 is transmitted to the ring through the anvil 50, setting ring 78, and sleeve 19; whereas, the upward movement of the cylinder 36 is transmitted to the packer body It through the actuating mandrel 54, sub 5 2a, tension rod 55, tension head 55, stud 51, shank 58, abutment 59, latch feet 63 and body abutment H. Accordingly, it is apparent that the development of suflicient pressure in the cylinder 36 acting upon the piston is will eventually shear the screws i9 holding the upper slips i8 to the expander 20, and move the slips outwardly against the casing. Thereafter, the cylinder 36 will move upwardly to move the body it) in the same direction for the purpose of expanding the packing sleeve 25 against the casing B, and the lower slips 22 against the casing, in the manner described above.

In order to obtain the desired operational sequence, a combustible fuel or power charge 8:! may be contained within the upper end of the cylinder 35. The combustion charge, such as a railway flare of cylindrical or stick form, is placed in the upper head end 38 0f the cylinder 36 within a combustion chamber 82 formed therein. The charge is ignited by a blank cartridge 83 contained within a gun barrel 84 inserted within the upper end of the upper cylinder head 33. Leakage between the barrel and head is prcvented by suitable side seals 85 on the barrel engaging the wall of the head.

The barrel 84 is threaded into a cable head 86, which, in turn, is threadedly secured to the upper end of the cylinder head 38. The wire line running-in string D is suitably secured to the cable head 85, in a known manner, and has the lower end of its electrically conductive wire or core 8i connected electrically to a heating filament 88 contained within the cartridge 83.

The apparatus is lowered in the well bore with the parts in the position shown in Figs. 1a, and lb. When the depth in the casing B is reached at which the well packer A is to be set, the electrical circuit through the cartridge filament 88 is completed, which fires the cartridge 83. The flame issuing therefrom ignites the upper end of the power charge 8!, initiating its combustion. This charge contains its own source of oxygen to support combustion. As combustion proceeds, a gaseous pressure is developed within the cylinder 35 above the piston 45. As the pressure increases, the piston 46 is urged downwardly and the cylinder 36 relatively upwardly. The force imposed on the piston is transmitted through the rod 49, cross-piece 50, and setting ring 13 to the sleeve '19, ring 89 and cylinder Hi, which bears against the upper slips [8. Downward movement of the lower piston 46 takes place against the relatively slight resistance of the air in the cylinder 36 below the piston 45, which is initially at atmospheric pressure, and also against the hydrostatic head of fluid in the well casing acting upa wardly across the cross-sectional area of the piston rod 49. When sufficient pressure has been developed within the cylinder 36 by the gaseous medium, and has been transmitted to the slips it, to overcome the shear strength of the shear screws 19, and also the hydrostatic head of fluid acting upwardly on the piston rod 49, the slips it are released from the expander 20 and are pushed downwardly along the latter into outward engagement with the casing B.

As the combustible charge 8| continues to burn, the gas pressure within the cylinder 35 increases to a further extent, and this increased pressure or force is transmitted to the lower piston Q5. Since the upper slips is are wedged against the casing, the piston I16 cannot move downwardly to any further appreciable extent. Instead, the cylinder 36, actuating mandrel 54, sub 54a, tension rod 55, tension head 56, stud 51, shank 53, latch retaining abutment 59, latch feet 63, abutment i I and its packer body W are urged in an upward direction. When the pressure and force within the cylinder 36 has increased sufiiciently to overcome the shear strength of the screws 2| holding the upper expander 28 to the body it), such screws are disrupted and the packer body is moved upwardly within the upper expander 28 to compress the rubber packer sleeve 23 between the upper and

lower expanders

20, 24, forcing it into firm sealing engagement with the casing wall.

Further increase in the cylinder gas pressure, as a result of the continued combustion of the charge 8!, effects shearing of the screws 25, 23

attaching the lower expander 24 to the body It a and the lower slips 22 to the lower expander, allowing the cylinder 36 to move upwardly and carry the body it and lower slips 22 in an upward direction to shift the latter radially outward into engagement with the casing.

The pressure in the cylinder 36 continues to increase, as combustion of the charge 81 proceeds, and all of the packer elements are engaged more firmly with the casing B. When the pressure exceeds the tensile strength of the reduced diameter portion 51a of the releasing stud '1 securing the actuating mandrel 5A indirectly to the body l0, this stud 57 is pulled apart at its reduced diameter portion 51a to release automatically the setting tool C from the well packer.

As indicated above, such release of the setting tool occurs as a result of dropping of the latch retaining abutment 59 and the shank 5S tothe extent limited by engagement of the shank shoulder H with theflange 12 of the retrieving sleeve 13. This dropping removes the latch retaining abutment 59 from its holding position behind the latch feet 63 and allows the latter to be pulled upwardly with the remainder of the setting tool C during elevation of the latter. This upward pulling occurs because of engagement of the tension rod shoulder 61 with the inturned shoulder 88 on the latch sleeve 65. Of course, the shank 58 and latch retaining abutment 59, as well as the lower broken portion of the releasing stud 51, are also elevated through the well packer A with the remainder of the setting tool, since these elements are supported by the retrieving sleeve flange '52.

Accordingly, it is apparent that all of the setting tool mechanism C is released irom the set and anchored well packer A, and the entire mechanism elevated by means of the wire line D to the top of the well bore.

After the setting tool has been removed from the well casing, production equipment (not shown) may then be run in the well casing for suitable coaction with the well packer A in producing the well from one or more zones below the well packer. The central passage 3| through the packer body ID is unobstructed, except for the lower back pressure valve head 32, which is readily displaced to one side, allowing the production tubing and other equipment to be placed in leakproof engagement with the packer body [0 and also allowing such equipment to extend completely through the packer body, if desired, to a point therebelow.

During lowering of the setting tool 0 and well packer A organization in the well bore by means of the wire line D, there may be a tendency for relative rotation to occur between the well packer and the setting tool, or between parts of the setting tool itself. As an example, relative rotation may occur between the tension rod 55 and the adjuster sub 54a attached to the lower end of the setting mandrel 54. The threaded connection between the tension rod 55 and adjuster sub 54a is preferably a right-hand one.

; If relative rotation between the adjuster sub and tension rod is in such a direction as to screw the rod 55 further into the sub, nothing detrimental to the equipment can occur. However, if the direction of rotation is such as to unthread the tension rod 55 from the adjuster sub 54a, and if such unthreading or unscrewing is sufficient in extent, the result may be a complete disconnection between the tension rod and the adjuster sub, which has the elfect of disconnecting or detaching all parts of the setting tool above the tension rod 55 from the coupling portion of the setting tool within the packer A, and of eiTectively disconnecting the setting tool C from the well packer.

Were the foregoing undesirable action to oc-- cur, the well packer A would drop down the easing B and would be lost in the hole.

In order to guard against such undesired re lease of the major portion of the setting tool from the tension rod 55, a locking device is provided between the tension rod and the adjuster sub. This locking device does not interfere with the threading of the tension rod 55 upwardly into the sub 54a, but it does prevent rotation of the tension rod with respect to the sub in the opposite direction.

The locking device illustrated in the drawings consists of a helical left-hand spring 9E: having its lower end 9! fitting within an end groove slot 92 in the upper end'of the tension rod 55. This spring is wound left-hand or opposite to the right-hand threads on the tension rod and adjuster sub. The peripheral portions of the spring turns snugly and frictionally engage the inner cylindrical wall 93 of the adjuster sub 54a.

In the event that the tension rod 55 is threaded upwardly into the adjuster sub, such action is not resisted one bit by the lock spring 90, since such right-hand turning of the tension rod twists the spring in the proper direction, to release its periphery from frictional engagement with the wall 93 of the adjuster sub. However, should the tension rod 55 tend to turn in the opposite or lefthand direction, such action would tend to expand the lock spring 55 and urge it more firmly against the wall of the adjuster sub. Thus, the lock spring 95 functions in the nature of a one-way brake, preventing unscrewing of the tension rod 55 in a downward direction from the adjuster sub 5541, but readily permitting its upward threading into the adjuster sub. Accordingly, the lock sprnig 59 prevents relative rotation between the adjuster sub and the tension rod in a direction which would cause the latter to unthread from the adjuster sub 55a, and allow the well packer A and the lower adapter portion of the setting tool C to drop off the setting mechanism, and be lost in the well bore.

The lock spring 95 is readily inserted in the adjuster sub during assembly of the apparatus, before the tension rod 55 is threaded into the sub. The lock spring need merely be twisted in the proper direction, as to the right, and forced into the sub bore through its upper end until it engages the bottom of the smooth portion 93 of the bore. The tension rod 55 is then threaded into the adjuster sub 55a, its slot 92 receiving the lower end 9! of the lock spring. Thereafter, upward threading of the tension rod can continue, the lock spring merely retracting or releasing itself from the wall 53 of the adjuster sub. Thus, the lock spring does not interfere or offer any material resistance to threading of the tension rod into the adjuster sub to the desired extent. It does, however, as described above, prevent unthreading of the tension rod from the adjuster sub.

When the parts are to be dismantled, the lock spring 55 would prevent unscrewing of the tension rod 55 from the adjuster sub 2a. However, the setting mandrel 55 can be unthreaded from the adjuster sub 54a and the latter then threaded downwardly along the tension rod 55, which action is not interfered with by the lock spring 99, since turning of the adjuster sub to the right releases the spring from the adjuster sub wall 95. The sub is turned until it is fed downwardly along the tension rod to the extent in which the lock spring 55 is positioned out of the cylindrical bore or passages 93 of the sub, whereupon the lock spring may be lifted out of connecting relation with the tension rod. With the removal of the lock spring, the adjuster sub 5511 may then be turned in the opposite direction to unthread it completely from the tension rod 55.

As described above, the latch retaining abutment 59 is held initially in an upward position, with its inclined face 55 engaging the latch feet 53, and thereby coupling the setting tool C to the well packer A. In the event that the abutment 59 were to move downwardly, the latch feet 63 would be released and the well packer might drcp downwardly to a position in which the latch feet were retracted and the entire packer disconnected froin the setting tool. Such action could occur, for example, in the event that the piston 45 were not at the uppermost end of its stroke, which might allow the cylinder 36 to shift downwardly, this downward motion being transmitted through the setting mandrel 54, tension rod 55, tension head 56, release stud 51 and shank 58 to the retaining abutment 59, shifting it downwardly of the latches 63.

To preclude the aforementioned possibility, a locking plate 95 is disposed over the tension rod 55 and engages a shoulder 95 in the packer body it at the lower end of its threaded box 9'1. This plate is held in this position by a suitable lock nut 83 threaded on the tension rod and engaging the plate 95, the nut having a plurality of radial pins 99 extending outwardly therefrom for cooperation with a suitable tool (not shown). The lock nut 98 is tightened against the lock plate 95 to the extent necessary to hold the latch retaining abutment 59 in its uppermost position and with its inclined face 60 securing the latch feet 53 outwardly in appropriate engagement with the body valve seat 34.

With the locking plate 95 and lock nut 98 arrangement, any downward forces imposed on the tension rod 55 cannot effect downward shifting of the latch retaining abutment 59, sincethe downward force is transmitted through the lock nut 98 and plate 95 to the packer body l0. However, the nut and plate do not interfere with the disruption of the release stud 51 after the packer A has been fully set, and the consequent dropping down and release of the latch retaining abutment 59 from the latches 63, which effectively disconnects the entire setting tool C from the well packer A and allows the setting tool to e withdrawn to the top of the well bore.

The locking plate 95 and lock nut 98 arrangement also has the function of preventing the tension mandrel 55 from rotating with respect to the packer A, which might tend to effect disconnection of some of the other threaded connections therebelow, as the various threaded connections in the tension head 56, release stud 5i, shank 58 and retaining abutment 59.

The locking nut and plate arrangement also permit the

lower adapter portion

55, 56, 57, 58, 59, etc. of the setting tool to be assembled in a shop or warehouse before the equipment is transported to the well location, all of which adds to the convenience and ease of relating the various parts of the apparatus to one another. The entire coupling device secured to the lower end of the tension rod 55, and the tension rod itself, can be mounted in the packer A in the shop, the locking plate 95 and lock nut 98 then being properly mounted in place, together with the adjuster sub 54a and lock spring 95. At the well location, it is merely necessary to secure the setting mandrel 54 in the adjuster sub 5 1a, and bring the ring attached to the lower end of the setting sleeve 19 into contact with the upper end of the cylinder sleeve l3.

The well packer employs an upper and lower arrangement which insures proper location and spacing of the slip segments when they are shifted outwardly into engagement with the wall of the well casing. The upper slips l8 consists of a plurality of arcuate segments Hill preferably having weakenin longitudinal inner grooves lill which are in alignment with longitudinal peri heral outer grooves or notches 52. The aligned inner and outer grooves llll, H32 form weakened sections along which each segment can break when being wedged against the casing B by the tapered upper expander 20, in order that the smaller segments, into which the slips are broken, can conform more closely to the curvature of the casing wall, and thereby provide a greater anchoring force of the slips [8 in the casing.

When the slips are in a retracted position, they are located in proper spaced relationship by the shear screws 19. However, once these shear screws [9 are disrupted, the slips I3 may not retain their spaced relation in being expanded outwardly against the casing. To insure main tenance of this relationship, each segment i'ilil is provided with a radial end guide groove IE3 in its upper portion, in which a locatin pin lo l, secured to the cylinder head I5, is slidably received. When the cylinder [4 is moved downwardly to shift the upper slips I8 along the upper expander 20, the shear screws I9 are disrupted and the guiding grooves I03 slide along the locating pins EM, in order to hold the slip segments [00 uniformly spaced with respect to each other, to the full extent of their outward expansion into engagement with the well casing B. Thereafter, the exertion of an adequate wedging force between the expander 29 and slips ill will break each segment liifi into smaller segments, as described above, with the wickers $95 of the slips firmly embedded into the wall of the well casing, and with all of the slip segments I00 disposed substantially uniformly around the upper expander 20 and well casing B.

A similar arrangement is provided with respect to the lower slip assemblage 22, in which the lower slips also have the longitudinal inner and outer aligned peripheral weakened grooves Ulla, lli2a. These slips also have the end guide grooves |03a in their large or lower portion receiving the locating pins 164a, which, in this instance, are secured to a washer or disc I86 resting upon the body abutment l 1.

During lowering of the equipment in the well bore, the lower slips 22 might encounter some foreign object and become prematurely tripped or expanded. To minimize this possibility, the shear screws 23 securing the slips to the lower expander 24 are supplemented by actually integrating each slip segment liilla to its neighboring slip segment. As a matter of fact, the lower slips 22 are at first integral with one an other, the slip assembly being formed from an integral piece of metal having the weakening and guide grooves referred to above. In addition, preferably spaced equi-angularly apart, the slip ring or sleeve has additional weakening internal grooves I01. This deeper groove H11, in conjunction with an external aligned weakenin groove 102a leaves a relatively small metallic bridge H18 between the adjacent segments lflfla, holding the segments to one another, and, of course, resisting their outward expansion, since the slip member 22 is at first a solid ring. Assuming that three main Slip segments lfllla are to be used, the deeper weakening grooves l9! and their aligned external peripheral grooves lBZa will be spaced 120 degrees apart.

When the packer body ID is pulled upwardly, in order to set the lower slips 22 against the casing, the first action is to shear the lower screws 23. Almost simultaneously, the metallic bridges 998 between the main segment portions Hlfia of the slip sleeve are disrupted by the wedging action of the expander 24, which breaks the sleeve into three main segments 108a, or places them in essentially the same condition as the upper slip segments I00. Thereafter, each lower slip segment Iilfla is guided outwardly, until it engages the well casing B, by the locating and guide pins I841; extending upwardly from the washer or disc I66. When sufficient wedgin force is exerted on each slip segment lOlla, it will break at its other weakened portions into a plurality of smaller segments.

It is unnecessary for the upper segments I80 to be initially formed as a solid integral sleeve, inasmuch as any foreign particles or substances that might engage the upper slips, durin lowering of the equipment in the well casing, could not urge such slips outwardly toward the well casing. Instead, the tendency is for such slips to be urged and maintained in their retracted position. This is not true of the lower slips 22, however, since any upward force imposed upon them tends to shift them upwardly along the lower expander 24 and radially outward against the well casing B.

The upper slips [8 are held in retracted position by the shear screws l9 alone, which can be made to disrupt at a predetermined force within relatively close limits. The metallic bridges I93, however, may have a great variation in the force required to disrupt them, but this is of no 1naterial importance in connection with the lower slips 22, since the upward movement of the packer body H3 will, in any event, effect a disruption and expansion of the slips 22, and with a force which is much less than the force required to dis rupt the release stud 51. The parts may be so related in strength as to insure that the upper slips I8 will first be anchored against the well casing E, the packing sleeve 29 expanded against the well casing, and the lower slips 22 then moved upwardly along the lower expander 24 and outwardly into engagement with the well casing.

The inventor claims:

1. In well apparatus: a body; an expander on said body having a circumferentially continuous external expander surface; slip means engageable with said expander surface for anchoring said body in a well bore; frangible means initially securing said slip means in retracted position with respect to said body and expander; means for relatively moving said slip means and expander to disrupt said frangible means and shift said slip means outwardly; and means for guiding said slip means generally radially during its entire outward expansion to its fullest extent.

2. In well apparatus: body means; expander means on said body means having a circumferentially continuous frusto-conical external surface; a device providing segment-a1 slips engageable with said surface of said expander means for anchoring said body means in a well bore; frangible means initially securing said slips in retracted position; instrumentalities for relatively moving said slips and expander means to disrupt said frangible means and shift said slips outwardly; and coengaging means on said slips and one of said means for guiding said slips during their entire outward expansion to their fullest extent.

3. In well apparatus: a body; an expander on said body having a cir-cumferentially continuous frusto-conical external surface; a device providing segmental slips engageable with said expander surface for anchoring said body in a well bore; frangible means initially securing said slips in retracted position; instrumentalities for relatively moving said slips and expander to disrupt said frangible means and shift said slips outwardly;

and coengaging means on said slips and body for guiding said slips during their entire outward expansion to their fullest extent.

4. In well apparatus: a body; an expander on said body having a circumferentially continuous frusto-conical external surface; a device providing segmental slips engagea'ble with said expander surface for anchoring said body in a well bore; frangible means initially securing said slips in retracted position; instrumentalities for relatively moving said slips and expand-er to disrupt said frangible means and shift said slips outwardly; and pin and groove means on said body and the end portions of said slips for guiding said slips during their entire outward expansion to their fullest extent.

5. In well apparatus: a body; an expander on said body having a circumf-erentially continuous external expander surface; a device providing segmental slips engageable with said expander sur face for anchoring said body in a well bore: frangible means initially securing said slips in retracted position; instrumentalities for relatively moving said slips and expander to disrupt said frangible means and shift said slips outwardly; the ends of said slips having generally radial grooves therein; and pin means on said body in said grooves for guiding said slips during their entire outward expansion to their fullest extent.

6. In well apparatus: a body; an expander on said body; a slip member cooperable with said expander for anchoring said body in a well bore; said slip member being initially a solid circumferentially continuous annulus when placed in aposition cooperable with said expander and having longitudinally extending arcuately spaced weakened sections therein; additional longitudinal weakened sections between said first-neutioned sections and substantially stronger than said first-mentioned sections; and means for shifting said expander and slip member with respect to each other to break said member at said first-mentioned weakened sections into a plurality of segments and expand said segments outwardly.

'7. In an anchoring device for a well tool: a solid circumferentially continuous annular slip member having longitudinally extending arcuately spaced weakened sections therein; and additional longitudinal weakened sections between said first-mentioned sections but substantially stronger than said first-mentioned sections.

8. In well apparatus: a body; an expander on said body; a slip member cooperable with said expander for anchoring said body in a well bore; said slip member being initially a solid circumferentially continuous annulus and having longitudinally extending arcuately spaced weakened sections therein; additional longitudinal weakened sections between said first-mentioned sections and substantially stronger than said first-mentioned sections; means for shifting said expander and slip member with respect to each other to break said member at said firstmentioned weakened sections into a plurality of segments and expand said segments outwardly; the ends of said segments having generally radial grooves therein; and pin means on said body extending into said grooves.

9. In well apparatus: a body; an upper expander on said body; upper segmental slips cooperable with said upper expander for anchoring said body in a well bore again-st upward movement; a lower expander on said body; a lower slip member cooperable with said lower expander for anchoring said body in a well bore against downward movement; said lower slip member being initially a solid circumferentially continuous annulus and having longitudinally extending arcuately spaced weakened sections therein; means for shifting said expanders, upper slips and slip members with respect to each other to expand said upper slips outwardly and to break said slip member at said weakened sections into a plurality of segments and expand said segments outwardly; said upper slips and segments having generally radial end grooves therein; and pin means on said body disposed in said grooves to guide said upper slips and lower segments during their outward expansion.

10. In well apparatus: a body; an expander on said body; a slip member cooperable with said expander for anchoring said body in a Well bore; said slip member having external wickers thereon; said slip member being initially a solid circumferentially continuous annulus and having longitudinally extending arcuately spaced weakened sections therein, each weakened section being provided by a longitudinally extending internal groove in said member and a longitudinally extending groove in said member radially aligned with said internal groove; additional longitudinal weakened sections between said first-mentioned sections and substantially stronger than said first-mentioned sections, each additional weakened section being provided by a longitudinally extending internal groove in said member of lesser radial extent than said other internal groove and a longitudinally extending external groove in said member radially aligned with said internal groove of lesser radial extent; and means for shifting said expander and slip member with respect to each other to break said member at said first-mentioned weakened sections into a plurality of segments and expand said segments outwardly.

11. In an anchoring device for a well tool: a solid circumferentially continuous annular slip member having external wickers thereon and longitudinally extending arcuately spaced weakened sections therein, each weakened section being provided by a longitudinally extending internal groove in said member and a longitudinally extending external groove in said member radially aligned with said internal groove; additional longitudinal weakened sections between said firstmentioned sections but substantially stronger than said first-mentioned sections, each additional weakened section being provided by longitudinally extending internal grooves in said member of lesser radial extent than said other internal groove and a longitudinally extending external groove in said member radially aligned with said internal groove of lesser radial extent.

References Cited in the file of this patent UNITED STATES PATENTS Number Name Date 2,153,035 Burt Apr. 4, 1939 2,204,659 Burt June 18, 1940 2,368,409 Burt Jan. 30, 1945 2,399,766 Steward May '7, 1946 2,467,801 Baker Apr. 19, 1949