US3012611A - Well treating tool - Google Patents

Description

Dec. l2, 1961 M. w. HAINEs WELL TREATING TOOL '7 Sheets-Sheet 1 Filed Nov. 30, 1953 INVENToR. MARCUS W HAM/Es,

ATTORNEY.

DeC- 12, 1951 M. w. HAlNEs.

WELL TREATING Toor.

7 Sheets-Sheet 2 Filed NOV. 30, 1955 IN VEN TOR. MAECI/.s W HMA/Es,

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Dec. 12, 1961 M. w. HAINES WELL TR1-:Anm: Toor.

7 Sheets-Sheet 3 Filed Nov. 30, 1955 n. e e

M. w. HAINEs 3,012,611

WELL TREATING TooL 7 Sheets-Sheet 4 Dec. l2, 1961 Filed Nov. 30, 1953 A .o m mw W www@ I N VEN TOR MARC/1s I/l/ Ham/Es,

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Dec. 12, 1961 M. w. HAINEs 3,012,611

WELL TREATING Toon.

Filed Nov. 30, 1953 7 Sheets-Sheet 5 ,27;7 12. 142 pfff.

1754 JNVENTOR.

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"45 l 175W .144cv TTOQNEY.

Dec. l2, 1961 M. w. HAINEs WELL TREATING Toor.

Filed Nov. $50, 1953 fT Sheets-Sheet 6 INVENTOR. MA1/@cus W LLI/NES,

TroQ/VEY I.. H: ....l

Dec- 12, 1961 M. w. HAINEs WELL TREATING Toor.

7 Sheets-Sheet 7 Filed NOV. 30, 1953 JNVENToR. MAQca/s W [J4/N55,

Arrone/wax iiieasal United States Patent ()ffiee 3,012,611 Patented Dec. 12, 1961 3,012,611 WELL TREATING TOOL Marcus W. Haines, Long Beach, Calif., assignor to Mc- Gaffey-Taylor Corporation, Long Beach, Calif., a corporation of California Filed Nov. 30, 1953, Ser. No. 394,928 16 Claims. (Cl. 166--147) This invention has for an object thereof the provision of a Well tool which is adapted to ybe anchored to the casing of a Well and operated in a highly efficient manner to perform useful work in the open formation below the casing.

Accordingly, a well -tool embodying this invention may include one or more packers that may be set and released in the open formation responsive to relative movement between the tool mem-bers, or it may include means operable responsive to such relative movement for acidizing or otherwise treating the open formation.

Thus the accompanying drawings and specification illustrate and describe as embodiments of this invention, packers of the straddle type for use in Cementing, acidizing or other treatment of well bores, as well as an acidizing tool operable without the use of packers for forming drain holes in the open formation of a well. This acidizing tool is illustrative of the use of the novel tool embodying the present invention for performing use ful work in the open formation below the casing other than the setting and releasing of packers.

A further object of this invention is the provision in tools such as described, of anchoring means which anchors one member of the tool to the well casing on the initial downward movement of the run-in string and maintains this member anchored in the casing upon continued downward movement of the string and a second tool member connected with the string, whereby portions of said members will coact upon such continued downward movement to expand packers thereon or to operate tool elements for performing useful work in the formation below the casing.

In conventional packer assemblies wherein a plurality of axially spaced packer elements are set in engagement with well casing upon axial movement of the packer body or mandrel, motion is transmitted through one packer element to the other, with the result that one or more of the packers is caused to shift longitudinally of the casing for a substantial distance.

An additional object of this invention therefore, is the provision of tools such as described wherein no bodily movement of packers forming parts of the tools is required while the packers are expanded into contact with the wall of the well bore, thereby preventing impairment of the packers.

Further, it is an object of this invention to provide a tool such as described whereby advantages herein noted are achieved by having portions of the tool engage the ends of the sleeve packers and causing these portions to be relatively moved for placing the packers under compression or tension according to the manipulation of the run-in string.

The present invention contemplates the provision, among other features which will hereinafter be described or become apparent to those skilled in the art, of an assembly including independently operated slip and eX- pander means for securing the tool in a well casing and packer or other device-operating means, combined with independent supporting structures and independent lock mechanisms for releasably locking the slips to the mandrel or body and for locking the packer or other tool to the mandrel or body, whereby the device may be secured in a well independently of whether the packer or other tool be set or not set.

This invention possesses many other advantages and has other objects which may be made more easily apparent from a consideration of several embodiments of the invention. For this purpose there are shown several forms in the drawings accompanying and forming part of the present specification. These forms will now be described in detail, illustrating the general principles of the invention; but it is to be understood that this 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:

FIG. l is a fragmentary vertical sectional view partly in elevation of the upper portion of a well tool embodying the present invention, showing the parts of this p0rtion as they would appear while positioning the tool in or removing it from the well;

FIG. 1a is a fragmentary vertical half sectional view of the middle portion of the tool of this invention;

FIG. lb is a fragmentary vertical half sectional view of the lowermost portion of the tool;

FIG. 2 is a vertical half sectional and partly schematic view of the complete tool shown in FIGS. l, la and lb, as when anchored to the well casing with one of the sleeve packers expanded into sealing position while the other packer is in inoperative position;

FIG. 3 is a fragmentary vertical sectional and partly schematic view partly in elevation of the tool shown in FIG. 2 with both packers expanded to seal against the well wall;

FIG. 4 is 4 4 of FIG.

FIG. 5 is 5 5 of FIG.

FIG. 6 is a cross sectional view taken on the line 6 6 of FIG. lb;

FIG. 7 is a fragmentary vertical sectional view partly in elevation of the upper portion of a modified form of the present invention;

FIG. 7a is a fragmentary vertical sectional view partly in elevation of the middle portion of this modified form;

FIG. 7b is a view similar to FIG. 7a of the lower portion of the modified form shown in FIGS. 7 and 7a;

FIG. 8 is a fragmentary vertical half sectionnal view of the complete tool shown in FIGS. 7, 7a and 7b;

FIG. 9 is an enlarged fragmentary vertical sectional view taken at right angles to FIGS. 7a and 7b on the line 9 9 of FIGS. 7a and 7b;

FIG. 10 is an enlarged cross sectional view taken on the line 1(1 10 of FIG. 7a;

FIG. 11 is an enlarged cross sectional view taken on the -line 111-11 of FIG. 7b as Well as on the line 11 11 of FIG. 9;

FIG. 12 is a fragmentary vertical sectional view partly in elevation of the upper portion of a second modified form of this invention;

FIG. 12a is a fragmentary vertical half sectional View of the middle portion of the second modified form of this invention;

FIG. 12b is a vertical half sectional view of the lower portion of the second modified form of this invention;

FIG. 13 is a fragmentary vertical half sectional view of the complete tool embodying the second modied form of this invention, as shown in FIGS. l2, 12a and 12b;

FIG. 14 is a fragmentary vertical sectional view similar to FIG. 12b on an enlarged scale;

FIG. 15 is a cross sectional view taken on the line 15 15 of FIG. 14;

FIG. 16 is a cross sectional view taken on the line 16 16 of FIG. 14;

a cross sectional view taken on the line 1, on an enlarged scale;

a cross sectional view taken on the line la;

FIG. 17 is a fragmentary vertical sectional view, partly in elevation, of another modiiied form of tool of this invention as it would appear when in use;

FIG. 18 is a view similar to FIG. 17, on an enlarged scale, showing the tool of FIG. 18 with the acidizing nozzle retracted;

FIG. 19 is a cross sectional view taken on the line 19-19 of FIG. 18; and

FIG. 20 is a cross sectional view taken on the line .20--20` of FIG. 18.

One form of well tool embodying the present invention, as shown in FIGS. 1-6, includes a tubular body 1 adapted to be connected to a tubular run-in string 2 for positioning in a well. A coupling member 3 for connecting the body 1 with the tubing string is threadedly coupled to a collar 4 rotatably mounted on the upper end of the body 1. This collar is provided with an internal annular fiange 5 which is rotatably confined between an external flange 6 on the body 1 and a sealing ring 6 held in the collar by an annular nut 7 threaded into the inner end of the collar. This arrangement provides for rotation of the collar 4 relative to the body 1 responsive to rotation of the tubing string 2, for the purpose to be hereinafter described.

Surrounding the body 1 are resilient axially spaced sleeve packers 8 and 9 adapted to be mechanically moved into and from sealing contact with the wall 10 of the Well bore. When expanded as shown in FIG. 3 to seal against the well wall, these packers will form therebetween a pressure chamber C into which fluid under pressure may be introduced through ports 12 in the body 1 for the desired treatment of the formation, such fuid being pumped down the tubing string 2. The ports 12 are provided by a tubular member 13 extending transversely of the bore of the body 1 so as to close this bore below the ports whereby the working uid is prevented from flowing through the lower open end of the body 1.

Means are provided for mounting the sleeve packers 8 and 9 on the body 1 in a manner making it possible to mechanically compress and expand them into sealing contact with the well wall responsive to downward movement of the tubing string 2 and the body 1 relative to such mounting means. This means is also operable to retract the packers under tension responsive to lifting of the tubing string and body -1 relative to the mounting means. Consequently, the mounting means and body 1 are telescopically connected in a manner permitting relative axial movement and rotative movement thereof.

As the tool is subject to operation at any depth in the well, it is necessary to releasably hold the mounting means against movement whereby the packers thereon may be mechanically actuated responsive to axial movement of the body 1 relative to the mounting means. Accordingly, anchoring means is operatively connected with the mounting means for engaging the casing 11 to anchor the mounting means thereto.

The packer mounting means and the body 1 are also operatively connected with locking means for releasably holding the anchoring means and the packers in inoperative position on the body 1 whereby the tool may be Ifreely moved in the well. This locking means releases the body 1 for axial movement relative to the mounting means responsive to rotative movement of the tubing string 2 and the body 1 relative to the mounting means. Accordingly, conventional drag springs 14 are associated with the anchoring means to frictionally contact the casing 11 and restrain movement of the mounting means in a manner permitting movement of the tubing string 2 and body 1 to release the locking means, setting the anchoring means and mechanically expanding the packers.

As the downward movement of the body 1 causes the anchoring means to operate before the packers are expanded, it is apparent that on the upward movement of the body member 1, the packers will be retracted before the anchoring means is released. Thus, at no time in the use of the tool is it necessary to move the packers bodily in the well while they are expanded, thereby preventing damage of the packers as would be caused if so moved while in contact with the well wall.

The mounting means for the packers 8 and 9, as shown in FIGS. 1-6, is constructed and arranged so that these packers are sequentially expanded and retracted. As here provided the upper packer 8 will expand first, after which the lower packer 9 will expand. Although the lower packer 9 is moved bodily axially of the well while expanding and retracting the upper packer '8, it is not expanded during such movement and consequently is not damaged by contact with the wall of the well. In retracting the packer the reverse of the expanding operation takes place as the lower packer is retracted before the upper packer.

To provide for these operations the packer mounting means is constructed of two tubular main sections 15 and 16 which telescope the body 1 and in turn are telescopically connected for relative axial movement. The section 15 is uppermost and section 16 lowermost on the tool body.

The upper sleeve packer 8 surrounds the lower portion of the upper section 15 so that the lower end of this packer is fixed to a thimble 17 threadedly connected to the lower end of the section 15. A sealing ring 17 is carried by the thimble 17 to form a seal between the thimble and the section 16. A retainer ring 18 is Vulcanized and interlocked as at 19 with the lower end of the packer 8 and threadedly connected with the thimble to fix the packer to the thimble.

The upper end of the upper sleeve packer 8 is bonded to and interlocked as at 20 with a ring 21 corresponding to the ring 18 and threadedly connected with the lower end of a cylindrical cage member 22 fixedly connected with the upper end of the lower tubular section 16 of the packer mounting means. A sealing ring 21 is confined between the ring 21 and an internal flange 22 on the cage 22 to form a seal between the ring, cage and section 15. The upper end of the lower section 16 telescopes the body 1 and extends within the upper section 15 to a point above the packer 8. Opposed longitudinal slots 23 (see FIGS. la and 5) are formed in the upper section 15 to slidably accommodate webs 24 which join the lower section 16 with the cage 22. Thus, the cage 22 telescopes the slotted portion of the upper section 15 of the packer mounting means and is movable axially relative thereto. As the ends of the upper packer are fixed to the cage 22 and lower end of the upper tubular section 15 respectively, it will be apparent that this packer Will be expanded and retracted on appropriate relative movement between the cage 22 and the upper section 15 of the packer mounting means, it being noted that this cage, in effect, is a part of the lower section 16 of the packer mounting means.

The lower packer 9 surrounds the lower portion of the section 16. The lower end of this lower packer is vulcanized to and interlocked with a ring 26 (see FIG. 1b) threadedly connected to a thimble 27 in turn threadedly connected with the lower end of the lower tubular section 16. The upper end of this lower packer is fixed to the body 1 through the medium of a cylindrical cage member 28 fixed to the body 1 and telescoping the lower section 16. A ring 29 is vulcanized and interlocked with the upper end of the lower packer 9 (see FIG. lb) and threadedly connected with the lower end of the cage 28. This cage is fixed to the body 1 by means of the tubular member 13 which forms the ports 12. The member 13 is welded to the body 1 so that it extends laterally from opposite sides of the body and into openings 31 in the cage 28. These ends of the member 13 are welded to the cage and thereby x the cage to the body 1. Slots 28 in the section 16 slidably accommodate the member 13 whereby the cage 28 while fixed to the body 1 is slidable on the exterior of the section 16. An annular nut 33 is screwed into the upper end of the cage and holds a sealing ring 34 in place between the lower tubular section 16 and the cage. A similar sealing ring 35 is held in place by the ring 29 between the lower end of the cage and the lower section 16. These sealing rings prevent fluid from entering between cage 28 and the lower section 16.

As the ends of the lower packer 9 are fixed to the cage 28 which is a part of the body 1, and to the lower end of the lower section 16 respectively, it is apparent that this packer will be expanded and retracted responsive to appropriate relative movement between the body 1 and the lower section 16.

In order that the upper packer 8 will be expanded before the lower packer 9, the lower section 16 of the packer mounting means must be moved downwardly while the upper section is anchored to the casing. Such downward movement of the lower section 16 is effected by lowering the tubing string 2 and body 1. Thus, the lower section 16 must be connected to the body 1 in order to be lowered to expand the upper packer as well as raised to retract this packer. This connection of the body 1 and section 16 must be releasable after expansion of the upper packer, as it is then necessary to move the body 1 downwardly relative to the section 16 to expand the lower packer. Accordingly, detent means which releases under a given force is employed to releasably connect the body 1 with the tubular section 16. As here shown this detent means comprises a shear pin 36 fixed to the thimble 27 and engaged in a notch 37 formed in a collar 38 at the lower open end of the body 1. The collar 38 mounts a perforated sub 39 on the lower end of the body 1. The pin 37 will shear when the body 1 and the lower section 16 as a unit are moved downwardly relative to the upper section 15 suliciently to expand the upper packer 3 into sealing engagement with the bore Wall. Although the packer 9 is moved bodily downwardly with the aforesaid joint movement of the body 1 and the lower section 16, it is not expanded at this time and therefore not damaged.

Downward movement of the body 1 relative to the lower section 16 as aiected when the pin 37 shears 01T, causes the packer 9 to be expanded into sealing engagement with the bore wall, thereby forming with the expanded packer 8 the pressure chamber C into which iiuid under pressure may be introduced through the ports 12 to treat the formaton as in acidizing or fracturing the formation or otherwise subjecting it to fluid under pressure for such treatment as may be desired.

The anchoring means for anchoring the packer mounting means to the casing 11 includes a down-drive type spear or expander 40 carried by the upper section 15 of the mounting means for moving slips 41 into and out of anchoring engagement with the casing. The slips 41 are slidably dovetailed on the expander and connected by means of links 42 with a collar 42a rotatably connected with a locking sleeve 43 surrounding the upper section 15. The collar 42a is rotatably interlocked with an annular member 42b welded to the upper end of the sleeve 42 for holding the upper ends of the drag springs 14 in place on the sleeve 43. A similar member 42c on the lower end of the sleeve 43 retains the lower ends of the drag springs. The locking sleeve 43 is provided with a J-slot 44, which with a pin 45 on the upper section 15 forms a conventional J-lock for releasably holding the slips 41 against axial movement relative to the expander. The spear or expander 40 surrounds the upper section 15 and is fixed thereto by a collar 46 threadedly connected as at 47 with the upper section 15 and as at 48 with the upper end of the expander.

Threadedly connected with the upper end of the collar 46 is a locking sleeve 50 which surrounds the upper end of the body 1 and telescopes the coupling member 3. The sleeve 50 is provided with a J-slot 51 which with a pin 52 on the coupling member 3 forms a conventional J-lock for releasably holding the body 1 and the sleeve 50 against relative axial movement. This lock cooperates as will be hereinafter described, with the J-lock on the sleeve 43 to releasably hold the slips and the expander against movement out of inoperative position with the slips retracted as shown in FIG. l.

A constantly open by-pass passage 54 is provided as shown in FIGS. la and lb, by the annular space between the body 1 and the lower tubular section 16. This bypass passage extends from the lower end of the tool to ports 55 formed adjacent the upper end of the lower section 16. The ports 55 open into the cage 22 whereby through openings 56 in the cylindrical wall of the cage, well iluid may flow into the by-pass 54 from the casing annulus or vice versa when positioning, repositioning or removing the tool. The by-pass passage 54 is closed above the ports 55 by means of a sealing ring 57 sealing between the upper end of the section 16 and the body 1, as shown in FIG. la. Fluid entering the portion of the bore of the body 1 below the tubular member 13 which closes the bore will pass through a port 58 in the body 1 into the by-pass passage 54 as indicated by the arrows in FIG. lb. Should the lower packer fail, the pressure fluid in the chamber C will be released through the bypass passage 54 thereby preventing this pressure from raising the tool and damaging the tubing string.

As shown in FIG. la the upper tubular section 15 is made in two parts connected by means of the coupling members 59 and 60. The coupling member 60 provides a shoulder 60 opposed to a stop ring 61 threadedly mounted on the body 1. The stop ring 61 supports the weight of the two sections 15 and 16 and parts connected therewith, when the tool is locked for positioning in the well as shown collectively in FIGS. l, la and lb. The body 1 may also be made of two parts which as shown in FIG. la are joined by a coupling member 63.

With reference to FIG. la it will be seen that opposed ports 64 and 65 are provided in the body 1 and upper tubular section 15 respectively, above the cage 22. Port 65 in the section 15 is open at all times. Port 64 however, is closed as shown in FIG. 3, by being straddled by the sealing ring 57 and a similar sealing ring 66 on the lower tubular section 16. This action takes place when the body 1 is lowered to dispose the port between the rings 57 and 66. The port 64 when open provides for scavenging the well fluid from the tubing string and tool into the casing to prepare the tool for operation as will be hereinafter described.

Operation When the tool with the ports thereof locked against relative axial movement as shown in FIGS. 1, la and 1b, has been positioned on the tubing string 2 at the selected zone of the well to be treated, the tubing string is lifted slightly and turned in a clockwise direction. This causes the coupling member 3 which is rotatively coupled to the body 1 to be correspondingly turned relative to the body 1 whereby the pin 52 on the member 3 is moved to the limit of its horizontal movement in the J-slot 51 in the locking sleeve 50. Continued clockwise turning of the string 2 and coupling member 3 causes the pin 52 to drive the locking sleeve 50 so as to turn in a clockwise direction. As the sleeve 50 is a continuation of the upper tubular section 15 of the sectional mounting means for the packers, the slip expander 40, slips 41, links 42 and rotative collar 42a also turn in a clockwise direction with the section 15. At this time the drag springs 14, by fractional contact with the casing 11 will restrain rotative movement of the sleeve 43 so that as the section 15 continues to turn in a clockwise direction, the locking pin 45 on the section 15 will be positioned in the J-slot 44 in the sleeve 43 for axial movement in such slot.

When the parts of the tool are unlocked as above described, the tubing string is lowered, thereby allowing the sectional mounting means (tubular sections 15 and 16) for the packers 8 and 9 to lower by the weight thereof,

whereby the slip expander 40 carried by the upper section 15 will be lowered relative to the slips 41. As the slips are held against axial movement by the drag spring 14, it is apparent that the lowering of the expander 40 will cause the slips to be moved into anchoring engagement with the casing 11 to anchor the upper section 15 thereto. During this slip setting operation the packers 8 and 9 move axially in the Well but are not expanded and thus are moved freely.

After the upper section 15 is thus held against axial movement, the body 1 is lowered relative thereto and through the shear pin 36 causes the lower section 16 to be lowered correspondingly. As the cage 22 is fixed to the upper end of the lower section 16, movement thereof relative to the upper section 15 as permitted by the slots 23 in the latter, will cause the upper packer to be compressed between the cage 22 and the thimble 17 on the lower end of the then stationary upper section 15, thereby expanding this packer into sealing contact with the wall of the well.

During this downward movement of the lower section 16 to expand the upper packer 8, the lower packer 9 is moved bodily downwardly in the well but is not expanded at this time. However, when the force developed by this downward movement of the body 1 and section 16 in compressing and expanding the upper packer 8, exceeds the holding force of the shear pin 36, this pin will break off and permit the body 1 to be moved downwardly relative to the lower section 16. `On this relative downward movement of the body 1, the lower packer 9 confined between the cage 28 and the thimble 27 on the lower end of the lower section 16 will be compressed and expanded into sealing contact with the wall of the well. This will form the pressure chamber C between the packers 8 and 9 in the annular space between the tool andthe wall of the well.

After the slips 41 are set and the upper packer 8 has been expanded to seal against the well wall, but before the lower packer 9 has been expanded, the body 1 will not have been lowered sufficiently to close the by-pass port 64. Thus, the port 64 is open as shown in FIG. 2 and the tool may be prepared for operation by pumping uid down the tubing string to scavenge the well fluid through the ports 64 and 65 into the casing. When it is determined by the usual method that this pressure uid reaches the tool, the tubing string and body 1 are lowered in the manner hereinbefore noted to expand the lower packer 9.

When the lower packer 9 is expanded to seal against the well wall, the by-pass port 64 is disposed between the sealing rings 57 and 66 and thereby closed. The pressure fluid forced from the top of the well through the tubing string 2 will now pass through the port 12 into the pressure chamber C for such treatment of the formation as may be desired according to the nature of the uid directed into the chamber C.

It should be noted that the constantly open by-pass 54 in the tool makes it possible to move the tool freely through uid in the well during positioning, repositioning and removing the tool.

Fluid under extremely high pressure may be employed in the operation of this tool as the weight of the tubing string is not relied upon to counteract hydraulic up-thrust forces of the pressure fluid.

The weight of the tubing string is directly applied to the upper end of the lower packer 9 only, and any tendency of axial movement of lower packer 9 under the working pressure can be compensated by lowering the tubing string,

To release the tool for removal from the well or to reset it in a zone above or below the zone previously worked, the tubing string 2 and the body 1 as a unit are lifted. Upon this lifting of the body 1 the packers are sequentially retracted, in the reverse order to the setting thereof.

Ou the imtial upward movement of the body 1 from the position shown in FIG. 3, the Weight of the tubing string 2 is relieved from the top of the lower packer 9 and as the lift of the body continues this packer is fully retracted by being placed under tension while the upper packer remains compressed and tightly sealed against the well wall. The upper packer 8 remains compressed and sealed against the well wall due to the fact that the body 1 and cage 28 carried thereby are movable upwardly relative to the lower section 16 by reason of the tubular member 13 on the cage being free to move upwardly in the slots '28' in the lower section 16. When the tubular member 13 reaches the tops of the slots 28', the lower packer 9 is fully retracted. Continued upward movement of the body 1 at this time causes the lower section 16 to be lifted for retracting the upper packer. As the cage 22 carried on the upper end of the lower section 16 is fixed to the upper end of the upper packer 8 while the lower end of the packer is fixed to the lower end of the then anchored upper section 15, it is apparent that the aforementioned continued upward movement of the body 1 and consequent upward movement of the lower section 16 will place the upper packer under tension and fully retract it.

During the retraction of the upper packer 8 the cage 22 on the lower section 16 moves freely upwardly in the slots 23 in the anchored upper section 15, without causing any movement of this upper section, thereby assuring that the slips 41 will remain in anchoring contact With the casing during the retraction of the upper packer.

When the top of the cage 22 reaches the top of the slot 23 in the upper section 15, this upper section will be raised as the lifting of the body 1 continues, whereby the expander 40 will be lifted relative to the slips 41 to thereby release the slips. When the slips have been released the pins 45 and 52 will be disposed at the tops of the J- slots 44 and 51 whereby counter clockwise turning of the body 1 as effected through the tubing string 2 will cause the pin 52 to move horizontally into locking position in the locking sleeve 50 so as to turn this sleeve and the upper section 15 correspondingly. As the upper section 15 carries the pin 45 it will be moved horizontally to locking position in the J-slot 44 in the sleeve 43, which latter is held against turning by the drag springs 14. With the tool locked in this manner it may be positioned at any desired point in the well for further operation or removed from the well.

A modified form of this invention as shown in FIGS. 7-11, differs from the form shown in FIGS. l-6, primarily in that two axailly spaced compression type resilient sleeve packers 70 and 71 thereof are simultaneously expanded and retracted mechanically through manipulation of the tubing string 72 to which a sectional tubular tool body 73 is coupled. It differs further in that the force for compressing the packers 70 and 71 to expand them into sealing engagement with the well wall, as well as the force for placing the packers under tension to retract them, are simultaneously applied alike to the opposed ends of the packers by geared drive means 74 operable responsive to axial movement of the too-l body 73 relative to the mounting means for the packers.

In this modified tool, the means for mounting the packers on the tool body is similar to the upper section 15 of the mounting means in the tool shown in FIGS. l-6, but differs therefrom in that the upper end of the upper packer 70 and the lower end of the lower packer 71 are fixed thereto. These ends of the packers are immovable axially when the mounting means is anchored to the casing 76. Accordingy, the mounting means includes a sectional tubular member or unit 77 telescoping the body unit 73 and supporting thereon a slip expander 78 together with slips 79 and drag springs 80. The downdrive expender 78, slips 79, drag springs 80, together with two J- lock arrangements 81 and 82 associated therewith are identical With the expander, slips, drag springs and J- locks in the first described form of this invention.

The upper end of the upper packer 70, as shown in FIG. 7a, is bonded to and interlocked with a ring 84 threaded into a coupling member 85 in turn threaded onto the upper end of the lower section 77a of the tubular mounting member 77, thereby txing the upper end of this packer to the mounting member 77. In this connection it should be noted that the sectional member 77 includes an intermediate section 77b and an upper section 77C. The lower section 77a is joined to the intermediate section -by means of a coupling member 8S threadedly connected with the upper end of the coupling member S and the lower end of the upper section 77C. A sealing ring 88 is confined between the couplings 85 and 88 for sealing against the exterior of the body section 73a. The upper section 77c is coupled to the intermediate section 77b for rotation relative thereto by means of the coupling member 89. This member 89 is adapted to cooperate with a stop ring 90 on the body member 73 whereby the packer mounting means and the parts connected therewith will Abe supported on the body member in moving the tool in the well.

The lower end of the upper packer 70 is bonded to and interlocked with a coupling member 91 (see lower end of FIG. 7a and upper end of FIG. 7b) slidable on the lower section 77a. The coupling member 91 is threadedly connected with another coupling member 92, threaded onto the upper end of an actuating sleeve 93. A sealing ring 94 is retained in the coupling member 92 by a nut 95 for sealing against the section 77.

As the lower end of the upper packer 70 is slidable on the section 77a but xed to the slidable actuator sleeve 93 upward movement of this sleeve relative to the sections 77a will compress the packer -and expand it into sealing engagement with the well wall, inasmuch as the upper end of this packer is fixed to the section 77a. Downward movement of the sleeve 93 relative to the section 77a will put the packer under tension and retract it from sealing contact with the well wall.

The lower packer 71 as shown in FIG. 7b is xed at its lower end to the section 77a by means of a ring 96 which is bonded to and interlocked with the packer as well as threadedly connected with a coupling member 97 screwed onto the section 77a.

The upper end of the lower packer 71 is sildably mounted on the section 77a by means of a coupling member 98 interlocked with and bonded to the packer as well as threadedly connected with an actuator sleeve 99 for the lower packer. 'Ihe actuator sleeve 99 is telescoped by the actuator sleeve 93 -for the upper packing. These sleeves are movable simultaneously to expand and retract the packers responsive to the geared drive means 74 which is actuated by manipulation of the tubing string 72 and body 73 as a unit.

The drive means 74 includes pairs of pinions 100 and 101 mounted in opposed openings 102 in the upper end of the actuator sleeve 99 for the lower packer 71. The teeth on opposite sides of the pinions 100 mesh with the teeth of opposed racks 103 and 104 formed on the actuator sleeve 93 and a section 73a of the tool body 73 respectively. The teeth on opposite sides of the pinions 101 mesh with the teeth of opposed racks 105 and 106 formed on the sleeve 93 and the body section 73a. The section 77a is provided with opposed longitudinal slots 107 (see FIG. 1l) through which the pinions are extended to mesh with the racks 104 and 106 on the body section 73a. These slots also permit the pinions to move axially relative to this body section.

Relative angular movement between the actuator sleeve 99 and the section 77a about the axis of the latter is prevented by a dovetailed splined connection 109 (see FIGS. 9 and ll) between the sleeve 99 and the section 77a. This maintains the pinions in mesh with the racks. Relative angular movement between the body section 73a, the section 77a, sleeve 99 yand sleeve 93 about the axis of the latter, is also prevented by a pin 110 lixed to 10 the body section 73a so as to be slidable axially in aligned slots 111, 112 and 113 formed respectively in the section 77a, the sleeve 99 and the sleeve 93.

The body section 73a carrying the racks 104 and 106 is connected by a coupling 114 (see FIG. 7a) to the upper section 73b of the tool body. The upper section 73b, as shown in FIG. 7, is rotatably connected with the tubing string 72 by means of coupling members 11S and 115'. The coupling member 115 provides a ange 116 coopera'ble with a flange 117 on the section 73b to effect the rotatable joint. A sealing ring 118 is carried in the coupling member 115' for sealing against the upper section 73b to provide a fluid tight joint.

It will now be apparent that the lowering and raising of the tubing string 72 and the sectional body 73 of the tool when the mounting member 77 for the packers is anchored to the casing, will cause the racks 104 and 106 on the body section 73a to drive the pinions 100 and 101 whereby through the racks 103 and 105 on the actuator sleeves 93 and 99, these sleeves will be simultaneously axially moved to positively expand and retract the packers 70 and 71. This expansion and contraction will take place without necessitating any bodily movement of the packers axially of the well and makes it possible to operate the tool at any zone in the well as well as to reset the tool above or below the position in which the packers were previously set, without removing the tool from the well.

As a means whereby the working fluid pumped under high pressure down the tubing string 72 may be introduced into the pressure chamber D (FIG. 8) formed between the packers 70 and 71 when the latter are set, a tubular member 120 is mounted in the lower section 73a of the tool body as shown in FIGS. 7a and 9. Thus, the tubular member 120 forms a passage 120 for the passage of pressure uid between the upper section 73b of the tool body and the well space outside the tool between the packers 70 and 71.

As shown in FIG. 7a, a closure ring 121 surrounds the upper end of the tubular member 120 and is welded thereto and to the upper end of the body section 73a. This ring secures the upper end of the member 1120 so that its bore is in direct communication with the bore of the upper body section 73b. The lower open end of the tubular member 120 (see FIG. 9) is laterally directed and Welded as at 123 to the body section 73a in registration with a port 124. This port is closed by the lower section 77a of the mounting means for the packers when the tool is locked for movement in the well. However, when the body 73 is released and lowered relative to the sectional tubular member 77, the port 124 is moved into registry with the slots 113, 1-12 and 111, thereby establishing communication between the tubular member 120 and the annular space outside the tool between the two packers. The pin 110 is xed to the lower end of the tubular member 120 below the open end thereof and extends through the port 124 and the slots 113, 112 and 111. When the port 124 is closed as shown in FIG. 9, this pin 110 abuts the upper ends of these slots. Thus, these slots and the port 124 comprise the port means for introducing pressure uid into the pressure chamber D formed between the packers 70 and '7-1.

A constantly open byapassage 126 (see FIGS. 9 and 7a) is provided whereby the tool may be moved freely in the well. This passage is formed by the lower portion of the bore of the tool body section 73a (FIG. 9), the space 126' between the body section 73a and the lower portion of the tubular member 120, also the space 126 (FIGS. 9 and 7a) between the upper portion of the tubular member 120 and the section 73a. Ports 127 and 128 (FIG. 7a) in the body section 73a and the section 77b of the sectional tubular member 77 respectively complete the passage 126. The port 127 is below the closure ring 121 which seals the upper end of the space 126 between the member 120 and body section 73a.

With reference to FIGS. 7a, 7b, 9 and ll, it will be seen that the bore 130 through that portion of the tubular body section 73a along which portion the racks 104 and 106 are disposed, is of non-circular cross section (see FIG. 1l), whereas the tubular member 120 in the bore 130 is of circular cross section. With this arrangement portions of opposite surfaces of the bore 130 contact opposite sides of the tubular member 120 shown in FIGS. 7b and l1, but the other surfaces of the bore 130 and tubular member 120 are spaced (see FIG. 9) and define the space 126' which forms the intermediate portion of the by-pass passage 126.

Valved by-pass means as shown in FIGS. 7a and 8 is provided above the upper packer 70 for securing the well fluid from the tubing string 72 in preparation for operation of the tool. This by-pass means includes ports 131 formed by short tubes 132 welded to the tubular member 120 and the body section 73a so as to communicate the interior of the member 120 with the exterior of the section 73a. Ports 134 in the coupling member 88 provide with the ports 13l1 for the flow of fluid between the interior of the tubular member 120 and the well space exteriorly of the tool. The ports 1311 are open when the tool parts are locked for movement of the tool through the well, but will be closed as shown in FIG. 8, when the body 73 is lowered relative to the sectional tubular member 77. In this lowering of the body 73, the ports 131 are disposed below the sealing ring 88 which prevents escape of the pressure fluid through ports 131 and thereby effecting the closure of such ports.

In the operation of the tool shown in FIGS. 7-11, after it has been positioned in a selected zone of the well in the usual manner, the tubing string is raised slightly and turned in a clockwise direction to dispose the J-lock pin 81a on the coupling member 115 at the limit of its horizontal movement of the J-slot 8117 in the locking sleeve 81e. As this sleeve is joined to the slip expander 78 and the section 77c of the tubular member 77 by means of a coupling 136 and becomes with the expander a part of the section 77e, continued rotation of the tubing string will cause the pin 81a to turn the sleeve and the section 77e in the same direction. As the section 77c is thus turned, the J-lock pin 82 on the section 77a` will be turned in the J-slot 82b in the locking sleeve 82e, to release the J-lock 82. As the sleeve 82C carries the drag springs 80 and is connected with the slips 79 by means of a rotative coupling 82a' and links 82e, it is apparent that the drag springs will restrain rotation of the sleeve 82 to permit the J-lock 82 to be unlocked in the manner above noted. During the release of the lower J-lock 82 the sleeve 81C, expander 78 with the slips 79 dovetailed thereon and links 82e are turned with the upper section 77a as a unit relative to the sleeve 82C, due to the rotative coupling 82d between the links 82e and the sleeve 82C.

After release of the J- locks 81 and 82, the body 73 is lowered to permit the slips 79 to set. These slips are restrained against axial movement at this time by the action of the drag springs 80. The setting f the slips is effected by the lowering of the tubular member 77 and the expander 78 carried thereby. The weight of the member 77 and parts carried thereby causes the member 77 to follow the body 73 upon lowering of the latter. This lowering of the member 77 is stopped when the slips are set, thereby permitting lowering of the body 73 relative to the member 77. As no appreciable relative axial movement between the body 73 and the member 77 takes place upon the initial lowering of the body, the pinions 100 and 101 are not actuated at this time to expand the packers. Operation of these pinions to expand the packers does not commence until the body 73 is lowered after the member 77 is anchored to the casing by the slips 79.

During the positioning of the tool in the well the constantly open by-pass passage 126 permits of free movement of the tool through the well fluid.

After this setting of the slips, the well fluid to be used in treating the selected zone of the well formation, is pumped down the tubing string to scaven'ge the well fluid through the tool and out the by- pass ports 131 and 134 which are then open. When it is determined by the usual method that this working uid has reached the tool, the tubing string 72 and body 73 are lowered, thereby closing the by-pass ports 131 as these ports move below the sealing ring 88 which latter is stationary due to the sectional tubular member 77 being stationary.

Downward movement of the body 73 after the member 77 is anchored, causes the racks 104 and 106 on the lower body section 73a to rotate the pinions 100 and 101 so that the racks 103 and 105 on the actuator sleeves 93 and 99 respectively, will effect a simultaneous movement of these sleeves. The sleeve 93 moves upwardly while the sleeve 99 moves downwardly, thereby applying compression forces to the opposed ends of the packers 70 and 71 to expand them into sealing contact with the well wall. When thus expanded, the packers form the chamber D (FIG. 8) and upon continued pumping of the working fluid down the tubing string this fluid will be introduced into the chamber D through the ports 124 and the slots 113, 112 and 111. The port 124 is closed until the packers 70 and 71 are expanded, the downward movement of the body section 73a to expand the packers, causing this port to move downwardly to register with the slots 113, 112 and 111, whereby the working uid will enter the pressure chamber D.

It will now be apparent that this tool may be operated at any depth in the well as tubing string weight sufficient to move the packers 70 and 71 into contact with the well wall is all that is required. The high pressure working fluid in the chamber D will be effective against the opposed ends of the packers to further compress and expand the packers into full sealing engagement with the well wall. As this high pressure is applied to the opposed ends of the packers the tubing string 72 and body 73 are lowered proportionally to compensate for any movement of the packers that would tend to cause back-lash of the pinions and 101.

Either packer may expand relative to the other according to the contour of the formation engaged thereby, thereby assuring the provision of an effective pressure chamber between the packers and an efficient treatment of the selected zone of the well.

The constantly open by-pass passage 126 permits any lower packing failure or Huid short-circuiting through the formation back into the well bore above the packers, to be immediately determined and this condition corrected before the well becomes damaged.

Retraction of the packers 70 and 71 from expanded position is effective by lifting the tubing string 72 and the tool body 73. This causes the pinions 100 and 101 to retract the sleeves 93 and 99 so that a direct pull is applied alike to the opposed ends of the packers to place them under such tension as to restore them to normal position clear of engagement with the wall of the well. This retraction of the packers takes place before the slips 79 are released inasmuch as the sectional tubular member 77 carrying the slip expander 78 is not moved during the retraction of the packer. However, when the J-lock pin 81a reaches the top of the J-slot 81b continued upward movement of the tubing string 72 and the body 73 will also lift the sectional tubular member 77 relative to the slips 79 whereby the expander 78 will be raised and release the slips. When the slips are released, the J-slot pin 82a on the upper section 73C of the member 77 will have been moved to the top of the J-slot 82b in the sleeve 82C. Upon now turning the tubing string 72 in a counterclockwise direction the pins 81a and 82a will be moved into locked position in the J-slots 81b and 82b respectively. This locks the tool in condition for free movement in the well so that it may be reset above or below the position in which it was previously operated.

Another modified form of this invention as shown in FIGS. l2-l6 comprises a tool wherein axially spaced and resilient sleeve packers 140 and 141 are mechanically actuated simultaneously responsive to manipulation of the tubing string 142 and a sectional tubular body 143 of the tool.

Surrounding the tool body 143 is a sectional tubular member 144 for supporting the packers. This membel is adapted to be anchored to the well casing 145 whereby the tool body may be moved relative thereto for operating the tool.

The tool body 143 has an upper section 143 rotatably connected by means of coupling members 146 and 147 with the tubing string 142. The upper end of the section 143' is provided with a flange 148 rotatably confined between shoulders 149 and 150 on the coupling members 146 and 147. A packer ring 151 is held by a nut 152 in the coupling member 147 for sealing engagement with the section 143 to provide a fiuid tight rotative joint.

A J-lock is provided to releasably lock the sectional tubular member 144 and body 143 against relative axial movement. This lock includes a pin 153 on the coupling member 146 arranged to be moved into and out of locking position in a J-slot 154 in a locking sleeve 155 forming the uppermost section of the member 144.

Anchoring means for anchoring the tubular member 144 to the well casing includes a down drive slip expander 156 joined to a coupling member 157 which c-ouples sleeve 155 to the intermediate section 144a of the member 144. Slips 158 are dovetailed on the expander so as to be movable into anchoring engagement with the well casing responsive to downward movement of the expander relative thereto. These slips a-re connected by means of links 159 with a collar 160 rotatably joined to `a retainer ring 161 fixed on the upper end of a locking sleeve 162 slidable on the section 14411. The ring 161 retains the upper ends of drag spring 163 whereas the lower ends of these springs are retained on the sleeve 162 by a similar ring 164.

A second J-lock is provided by means of a pin 165 on the section 144a operable in a J-slot 166 in the sleeve 162. The drag springs 163 will restrain rotative movement of the sleeve 162 to permit the sleeve 166, section 144e, expander 156 and slips 15S to turn relative to the sleeve 162, due to rotative coupling at 160-161. Consequently when the tubing string is rotated in a clockwise direction, the pin 153 will reach the limit of its horizontal movement in slot 154 then turn the sleeve 155, thereby turning the section 144a and the pin 165 thereon, to unlock the second J-lock whereby the sectional body 143 may be lowered relative to the sectional member 144. This lowering of the body 143 will permit the sectional tubular member 144 to lower by its weight, thereby lowering the expander 156 whereby the slips 158 will be moved into anchoring engagement with the well casing. The packers 140 and 141 are not expanded during the movement of the body 143 and the member 144 to set the slips.

The lower section 143" o-f the body 143 is joined (see FIG. 12a) by means of a coupling member 167 with the upper body section 143.

The intermediate section 144a of the sectional tubular member 144 is rotatably coupled to the lower section 144b of the member (see FIG. 12a) by means of a pair of coupling members 168 and 169, and a ring 170. The coupling member 168 surrounds the section 14411 and is threaded onto the coupling 169 which latter is threaded onto the lower section 144b. The ring 170 is threaded onto the section 144a and confined between the coupling members 168 and 169 so that it may turn relative thereto with the section 14411, thereby providing for turning of the intermediate section 144:1 and the sleeve 155 as a unit relative to the lower section 144b.

The lower end of the upper packer 140 is fixed to a thimble 173 slidable on the lower section 144b. A similar sealing ring 182 is confined between the opposed por- 14 tions of the coupling member and the inner surface of the lower end of the sleeve 177. The sleeve 177 is provided with a pair of axially spaced internal shoulders 183 -and 184 adapted to engage shoulders 185 and 186 on the coupling member 180 whereby on downward movement of the sleeve 177, the coupling member 180 and thimble 173 will be moved downwardly relative to the section 144b to compress and expand the packer 140.

In opposed surfaces of the coupling member 180 and the sleeve 177 are opposed complementary grooves 187 and 18S extending axially thereof and ball members 189 are mounted. Openings in the sleeve 177 provide for insertion of the ball members 189 intothe grooves 187 and 18S. These openings are sealed by plug 191 after inserti-on of the ball members. With this arrangement a delayed retraction of the packer 140 will take place in a manner to be hereinafter described.

The lower end of the lower packer`141 is fixed to the lower end of the section 144]: by means of the thimble 192 and a coupling member 193 which latter is threadedly connected with the thimble and the section 144b respectively.

The upper end of the lower packer is fixed to a thimble 194 slidable on the lower section 144b and having a lost motion connection with an actuator sleeve 195 for the lower packer. The sleeve 195 is fixed to the lower end of the body section 143 so as to telescope the lower section 144b f-or axial movement relative thereto to expand and contract the lower packer 141. As here shown a tubular member 196 is provided on the lower end of the body section 143 so as to extend transversely thereof with opposite end portions slidable in longitudinal slots 197 in the section 144b. The end portions extend through openings in the sleeve 196 and are welded to the sleeve so that the open ends thereof provide ports 193 between the packers 140 and 141.

The lost motion connection between the thimble 194 and the sleeve 195 includes a -coupling member 199 threadedly joined to the thimble 194 and extending into the lower end of the sleeve 195. A sealing ring 200 is interposed between the thimble and the coupling meinber 199 so as to seal against the section 14417. Between the coupling member 199 and the sleeve 195 is a sealing ring 200 thereby making the lost motion joint uid tight. In opposed surfaces of the coupling member 199 and the sleeve 195 are opposed and complementary longitudinal grooves 201 and 202 in which ball members 203 are movable in the same manner as in the lost motion connection between the upper sleeve 177 and the thimble 176 for the upper packer.

The coupling member 199 is provided with axially spaced shoulders 204 and 205 engageable by shoulders 206 and 207 on the sleeve 195 whereby on lowering the sleeve 195 relative to the section 14412 the coupling 199 and thimble 194 will be moved downwardly to compress and expand the packer 141. The lost motion connection for this packer makes it possible for the pressure of the working fluid in the pressure chamber E (FIG. 13) between the packer to compress the upper end of the lower packer and move this upper end downwardly relative to the sleeve 195 in a manner to be hereinafter fully described.

A constantly open by-pass passage 209 is provided as shown in FIGS. 13, 12b and 12a from the open lower end of the lower body section 143 through the bore of this section to the slots 179 in the section 144b and a series of openings 210 in the actuation of the sleeve 177 for the upper packer 140.

Working fluid by- pass ports 212 and 213 for scavenging well fluid from the tubing string and tool are provided as shown by FIGS. 12a and 13, in the sections 143 and 144!) above the upper packer 140. The ports 212 in the body section 143 remains open until the tubing string and this body section are lowered to set the slips. This lowering of the body section 143" disposes the ports 212 between axially spaced sealing rings 214 and 215 mounted in internal grooves in the section 144b, thereby closing the ports whereby the tool is ready for operation. When the ports 212 are opened the well fluid may be scavenged from the tubing string and tool through ports 212 and 213 by pumping the working fluid down the tubing string. When 4the working fluid reaches the tool, as determined by the usual method, the tubing string is lowered further to expand the packers.

Operation In operation, the tool shown in FIGS. 12-16, with the parts locked as shown in FIGS. 12, 12a and 12b is run into the well to the zone to be treated. After this positioning of the tool the tubing string 142 is lifted and then turned clockwise to move the J-lock pin 153 to the limit of its horizontal movement in the J-slot 154. Continued turning of the string 142, will cause the pins 153 to drive the sleeve in a clockwise direction, thereby moving the J-lock pin 165 on the section 14411 to an unlocked position in the J-slot 166 in the sleeve 162. As the sleeve 162 is held against rotative and axial movement at this time by the drag springs 163, it is seen that the pin 165 will move `as stated to unlocked position and that the tool body 143 may be lowered relative to the sleeve 162. As this lowering of the body 143 takes place the sectional tubular member 144 supporting the packers 140 and 141 by the weight thereof, lowers and causes the expander 156 to move 4the slips 158 into anchoring engagement with the casing. If this lowering of the tool body 143 closes the ports 112, the tool may be lifted to open the ports 112, without releasing the slips, thereby providing for scavenging the well fluid from the tubing string through the ports 112 `and 113 as hereinbefore noted. After this scavenging of the well fluid, the body 143 is lowered further thereby through the actuator sleeves 177 and 195 compressing the packers 140 and 141 and causing them to be expanded into sealing engagement with the wall of the well.

When the packers are expanded in this manner the Working fluid is pumped under pressure down the tubing string and out through Ithe ports 198 into the pressure chamber formed between the packers to subject the well formation to the desired treatment according to the nature of the uid matter so pumped.

The hydraulic pressure between the packers 140 and 141 is effective against the opposed ends of the packer to compress the packers into tighter engagement with the well wall. The slidably mounted lower end of the packer 140 makes possible this addi-tional compression of packer 140. The lost-motion connection (balls 203 and associated elements) at the upper end of the lower packer 141 permit this end to be moved axially relative to the section 144a when hydraulic pressure is applied thereto.

When it is desired to withdraw the tool from the well or to reposition it, the tubing string is lifted. At this time, the ball members 203, due to the hydraulically effected actuation of packer 141 as above noted, are engaged with the upper ends of the grooves 201 and the lower ends of the grooves 202. Thus, as the grooves 202 are in the sleeve 195 which is lifted with the body section 143" upon lifting the tubing string, it is apparent the ball members 203 will serve as a drive connection between the parts 195 and 199 which latter is raised and exerts a pull on the packer 141 to retract it from expanded position. During this retraction of the packer 141, the packer 140 may remain expanded, it being necessary for the body section 143 to be raised until balls 189 are lifted into con- Itact with the upper end of the groove 187 before a pull is exerted on the upper packer 140 for retracting it. Thus, the packers 141 and 140 are sequentially retracted. This will insure that both packers are retracted clear of engagement with the well wall whereby the tool may be freely moved in the well and without damaging the packers.

It should be noted that each of the several tools embodying the present invention is capable of performing useful work in the open formation of a cased well below the casing. Each tool has one member adapted to be anchored to the casing while another member thereof is connected with the tubing string for axial movement therewith relative to the anchored member responsive to manipulation of this string at the top of the well. The tool members have relatively movable portions adapted to be disposed below the casing while one of the tool members is anchored to the casing. In the tools so far described, the relatively movable portions disposed below the casing are employed to mount and operate sleeve packers. These packers are expanded into sealing contact with the open formation upon axial movement in one direction of the tubing string and consequent relative axial movement between the two tool members. Axial movement of this string in the opposite direction will cause the packers to be retracted.

The initial movement of the tubing string in the direction for expanding the packers permits the anchoring means to anchor one of the tool members to the casing after which, continued movement of the string in that direction causes the packers to be expanded. This arrangement is such that the packers may be expanded and retracted while the tool is anchored to the casing. Thus, when the packers have been retracted responsive to movement of the tubing string, continued movement of the string in the same direction as required to retract the packers will release the anchoring means whereby the tool may be repositioned for operation in another zone of the well. This resetting of the tool may be repeated as desired without removing the tool from the well.

Another feature of importance common to the tools embodying the present invention is the double J-lock arrangement which makes it possible to operate the tools in the advantageous manner hereinbefore noted.

Another modified form of this invention as shown in FIGS. 17-20 constitutes a tool, which, without the use of packers, may be advantageously used to inject fluid under pressure into the open formation below the casing to which latter the tool is anchored in the same manner as in the previously described tools. This modified tool is particularly adapted for acidizing limestone and other formations where acidizing may be desired. It provides a fexible tube which is adapted to be projected from the tool laterally into the formation, while discharging fluid under pressure, responsive to relative movement between members of the tool as effected by manipulation of the tubing string in the same manner as in operating the packers in the previously described tools hereof. This exible discharge tube is progressively moved laterally into the formation as the acid dissolves or eats a path therefor. With this arrangement the tool may be operated to provide a series of lateral drain holes opening into the well bore for draining oil into the latter. The rate of lateral progression of the flexible discharge tube into the formation is determined by rate of penetration action of the acid and the rate of movement of the string and the member of the tool connecting the flexible tube with the string, while the other member of the tool is anchored to the casing. As the acid is pumped down the string the action of the pump (back pressure) will enable the operator at the top of the well to properly govern the lowering of the tubing string best to form the lateral drain holes in the formation.

Referring more specifically to the tool shown in FIGS. 17 to 20, it is seen that it includes a pair of telescopically connected inner and outer tubular members 215 and 216. The inner member 215 comprises an upper section 215:1 and a lower section 21511 joined by means of a coupling 215e. The upper section 21511 is adapted to be connected at its upper end to a tubing string 218 by means of a coupling member 219 corresponding to the coupling 3 in the first described form of this invention, whereby the tubing string may be rotated relative to the upper sectiOn 215e. The Outer tool member 216 includes an upper 17 section 216g joined to a lower section 216b by means of a rotative coupling 216C.

Mounted on the outer member 216 in the same manner as in the rst described form of this invention, are the J- lock sleeves 220 and 221, the slip expander 222, the slips 223, the links 224 connecting the slips with the sleeve 221 through a rotative coupling 225, and the drag springs 226 carried by the sleeve 221. The coupling member 219, is provided with a J-lock pin 227 operable in the J-slot 228 in the sleeve 220, whereas the member 216 is provided with a J-lock pin 229 operable in the J-slot 230 in the sleeve 221. These two J-locks are operated responsive to rotation of the string 218, in the same manner as in the tool shown in FIGS. l-6.

The slips 223 are operated to anchor the member 216 to the casing by the weight of the member 216 and parts thereon, upon the initial downward movement of the string 213 after release of the two J-locks, in the same manner as in the previously described form of this invention. This anchoring of the member 216 is effected so that portions of the members 215 and 216 will be disposed in the open formation below the casing, whereby upon relative movement between these portions the tool may be operated,

As a means for introducing fluid under pressure, `for example acid, so that it will penetrate limestone and other formations where it is desired to open oil bearing zones by means of drain holes, an elongated exible discharge tube 232 is provided in the lower portion of the outer tool member 216. This discharge tube may be made of synthetic rubber or other suitable flexible material and is connected at its upper end by means of a suitable coupling 233 with the lower end of the lower section 215i: of the inner and axially movable tool member 215. A guide tube 234 mounted in the member 216 is constructed and arranged to guide the flexible tube 232 so that it will extend laterally from member 216 into the formation when the tubing string and member 215 are lowered relative to the section 216. Accordingly, this guide tube is welded or otherwise secured at its upper end to a bushing 235 Welded within the bore of the member 216. The lower section 215b is slidable in this bushing and the upper end of the guide tube responsive to lowering and raising of the tubing string, there being a suitable packing gland 235 in the bushing.

To provide for free movement of the flexible tube 232 without binding, the guide tube 234 is curved as at 234a on a large radius adjacent the discharge end thereof. This discharge end is extended substantially horizontally into an opening 237 in the side of the outer member 216 whereby the flexible tube may be projected laterally into the open formation. An annular boss 238 is formed on the exterior of the member 216 around the opening 237 so as to receive in the bore thereof the discharge end of the guide tube 234, this end being secured to the boss as by being welded thereto. A nozzle 239 formed of metal or other suitable hard material is fixed on the discharge end of the flexible tube 232 and is retracted into the bore of the boss when not in use, the boss thereby protecting the nozzle in the Iaxial movement of the tool in the well bore.

In order that the guide tube 234 may be curved on a large radius, the outer or anchored member 216 of the tool is slotted as at 240 so that a portion 234b of the tool may be projected therethrough; this portion being welded as at 241 and 242 to the member 216. An additional support may be provided intermediate the ends of the guide tube in the form of an annular ring 242 welded to the tube and disposed in the member 216 so as to maintain the upper part of the tube centered in the member 216.

The lower end of the outer member 216 is provided with drain openings 243 for fluid which enters the member 216 below the bushing 235. Similar drain openings 18 244 are provided above the bushings 235 for fluid which enters the member 216 above the bushing 235.

It should be noted that the protruding portion 234b of the guide tube 234 and the boss 238 have a substantially equal lateral extent from the exterior of the member 216 whereby the tool will be centered in the well bore.

When this tool is lowered into the well bore, the flexible tube 232 is in the retracted position shown in FIG. 18, being so held by the two J-locks which include the sleeves 220 and 221 and associated pins 227 and 229 respectively. These J-locks hold the inner and outer members 215 and 216 against relative axial movement as well as maintain the slips 223 retracted in the same manner as in the previously described forms of the invention.

When it is determined by the usual method that the tool is in the desired position in the well bore with the lower ends of the members 215 and 216 disposed in the open formation below the casing, the operator rotates and then lowers the tubing string to release the J-locks `and cause the slips to set and anchor the outer member 216 to the casing in the same manner as in the previously described forms of this invention. This setting of the slips is effected so that the member 216 will be anchored before the lower ends of the members 215 and 216 contact the bottom of the bore hole.

The working iiuid, such for example as a suitable acid, is now pumped down the tubing string to scavenge the well iluid from the string through the tube 232 and nozzle 239 into 4the casing. When this scavenging operation is completed, the tubing string is lowered slowly whereby the inner member 215 will be lowered and cause the exible tube 232 to be forced downwardly so that the nozzle 239 will be moved into intimate contact with th open formation. The pumping of acid to the tool is continued and it is apparent that continued lowering of the string will cause the nozzle 239 to progressively penetrate the formation as the acid discharged from the nozzle eats into the formation as indicated in FIG. 17.

With the acid ow regulated for a constant rate of discharge from the nozzle 239, the proper rate of advance of the nozzle and iiexible tube into the formation may be determined by the back pressure as noted by pumping pressure variations at the top of the well. Care should be exercised to avoid a too rapid projection of the flexible tube to prevent distortion of the tiexible tube and the consequent formation of an improperly sloping drain hole or cavity in the formation.

It will now be apparent that by lowering the tubing string slowly, the flexible tube 232 and nozzle 239 may be advanced as the hole is formed by the acid discharging into the formation from the nozzle, whereby an effective drain hole leading from the desired depth in the formation to the well bore, may be quickly and easily produced.

After one such hole is formed the flexible tube 232 and nozzle 239 may be retracted within the guide tube as shown in FIG. 18 by lifting the tubing string and the member 215 connected therewith. This raising of the string and member 215 suiciently to retract the flexible tube 232 does not release the slips which therefore hold the outer member 216 anchored to the casing during the retraction of the flexible tube.

Continued lifting of the tubing string will cause the coupling member 215e to engage the shoulder 246 on the outer member 216, thereby lifting the member 216 and the slip expander 222 on the member 216, so that the slips will be released in the same manner as in the previously described forms of this invention. After releasing the slips, the tubing string is rotated to lock the pins 227 and 229 in the slots therefor in the sleeves 220 and 221 whereby the members 215 and 216 are locked against relative movement. The tool may now be repositioned in the well and again operated to make another drain hole in the open formation, it being possible to make as many holes as desired with the tool, with one run of the tool into the well bore.

I claim:

1. A well tool including: a tubular body member and a mounting member telescopically connected for relative axial movement; said body member being adapted to be connected with a tubing string; a pair of resilient sleeve packers axially spaced on said mounting member for sealing against the well wall to provide therebetween a pressure chamber; means providing with said body member a passage for conducting uid between said tubing string and said chamber; means including said mounting member providing with said body member a passage for conducting fluid between said first named passage and the exterior of said members above the uppermost packer; closure means on one of said members for opening and closing said last named passage responsive to relative axial movement between said members; means including said mounting member providing with said body member a constantly open passage for conducting tiuid between port means opening exteriorly of said members above and below said pair of packers; means for releasably anchoring said mounting member in said well; and means supported on and operatively connected with said members and engaging the ends of said packers, respectively, operable to compress said packers to expand them into sealing contact with the well wall responsive to relative axial movement between said members.

2. A well tool including: a tubular body member and a mounting member telescopically connected for relative axial movement; said body member being rotatively connected with a tubing string; a pair of resilient sleeve packers axially spaced on said mounting member for sealing against the well wall to provide therebetween a pressure chamber; means providing with said body member a passage for conducting uid between said chamber and said tubing string; means including said mounting member providing with said body member a passage for conducting iluid between said Iirst named passage and the exterior of said members above the uppermost packer; closure means on one of said members for opening and closing said last named passage responsive to relative axial movement between said members; means including said mounting member providing with said body member a constantly open passage for conducting fluid between port means opening exteriorly of said members above and below said pair of packers; a slip expander on said mounting member; locking means operatively connected with said string and said mounting member movable to an initial position for holding said members against relative axial movement; said locking means releasing said members for relative axial movement responsive to initial limited rotative movement of said string relative to said mounting member; a sleeve mounted on said mounting member for rotative movement relative thereto; slips engaged with said expander; links connected with said slips; means rotatably connecting said links with said sleeve; locking means holding said mounting member against axial movement relative to said sleeve, said last named locking means releasing said mounting member for axial movement relative to said sleeve and slips responsive to rotation of said mounting member relative to said sleeve following said initial rotative movement of said string; drag springs on said sleeve engageable with the wall of the well to restrain rotative and axial movement of said sleeve; and means supported on and operatively connected with said body member and mounting member, respectively, cooperable to expand said packers into sealing engagement with the wall of the Well upon relative axial movement of said body member and said mounting member.

3. A well tool including: a tubular body adapted to be positioned in a well on a tubing string; tubular means mounted on said body; said body and tubular means 20 being relatively axially movable; a pair of axially spaced resilient sleeve packers on said tubular means; said body having a port between said packers; means for releasably anchoring said tubular means in the well; packer compressing means supported by said tubular means; said packer compressing means being located between and engaging the adjacent ends of said packers and being movable in opposite directions; and means on the body operatively connected to said packer compressing means to move the latter in opposite directions responsive to longitudinal movement of said body for applying a compression force to the opposed ends of said packers to expand the packers into sealing engagement with the well wall.

4. A well tool including: a tubular body adapted to be positioned in a well on a tubing string; tubular means mounted on said body; said body and tubular means being relatively axially movable; a pair of axially spaced resilient sleeve packers on said tubular means; said body and tubular means having port means therein opening exteriorly of said tubular means between said packers; means for releasably anchoring said tubular means in the well; means on said tubular means engaging the outer ends of said packers to hold the packers against bodily axial movement relative to said tubular means; actuating members engaged with the opposed ends of said packers movable axially relative to said tubular means; and means operatively connected with said body and said actuating members for moving said actuating members axially of said tubular means in opposite directions to expand and retract said packers responsive to axial movement of said body relative to said tubular means.

5. A well tool including: a pair of sectional tubular units telescopically connected for relative axial movement; a pair of resilient sleeve packers axially spaced on one o f Said units; means for releasably anchoring said one unit against axial movement in the well; said units having port means opening exteriorly thereof between said packers; means xing the outer ends of said packers to said one unit; actuating members connected for relative axial movement in opposite directions, with ends thereof engaging the opposed ends of said packers; and drive means for said actuating members mounted on one of said units and one of said actuating members respectively, for shifting said actuating members responsive to relative axial movement between said units.

6. A well tool including: a pair of tubular units telescopically connected for relative axial movement; a pair of resilient sleeve packers axially spaced on one of said units; means for releasably anchoring said one unit against axial movement in the well; said units having port means opening exteriorly thereof between said packers; means fixing the outer ends of said packers to said one unit; actuating members connected for relative axial movement with their ends engaging the opposed ends of said packers; and drive means for said actuating members comprising pinions on one of said actuating members meshing with rack teeth on said other actuating member and the other of said units respectively.

7. A Well tool including: a pair of tubular units connected for relative axial movement; a pair of resilient sleeve packers axially spaced on one of said units; means for releasably anchoring said one unit against axial movement in the well; said units providing port means opening exteriorly thereof between said packers; means tixing the outer ends of said packers to said one unit; actuating sleeves fixed to opposed ends of said packers and telescopically related for axial movement in opposite directions; and means for simultaneously effecting axial movement of said sleeves in opposite directions responsive to relative axial movement between said units.

8. A well tool including a pair of tubular units connected for relative axial movement; a pair of resilient sleeve packers axially spaced on one of said units; means for releasably anchoring said one unit against axial movement in the well; said units providing port means opening exteriorly thereof between said packers; means lixing the outer ends of said packers to said one unit; actuating sleeves fixed to opposed ends of said packers and telescopically related for axial movement relative to said units; and means for simultaneously effecting axial movement of said sleeves responsive to relative axial movement between said units; said last named means comprising rack teeth on the other of said units and one of said sleeves respectively; and pinions on the other of said sleeves meshing with said teeth.

9. A well tool including, a pair of tubular units connected for relative yaxial movement; a pair of resilient sleeve packers axially spaced on one of said units; means for releasably anchoring said one unit against axial movement in the well; said units providing port means opening exteriorly thereof between said packers; means xing the outer ends of said packers to said one unit; actuating sleeves xed to opposed ends of said packers and telescopically related for relative axial movement relative to said units; and means for simultaneously effecting axial movement of said sleeves in opposite directions responsive to relative axial movement between said units; said units providing a constantly open passage extending from a port below the lowermost packer to port means opening exteriorly of the units above the uppermost packer.

10. A well tool including a pair of tubular units connected for relative axial movement; a pair of resilient sleeve packers axially spaced on one of said units; means for releasably anchoring said one unit against axial movement in the Well; said units providing port means opening exteriorly thereof between said packers; means fixing the outer ends of said packers to said one unit; actuating sleeves fixed to opposed ends of said packers and telescopically related for axial movement relative to said units; and means for simultaneously effecting axial movement of said sleeves in opposite directions responsive to relative axial movement between said units; said port means including registering openings in said units and said sleeves respectively.

1l. A well tool including: a tubular body member and a mounting member telescopically connected for relative axial movement; said body member being rotatively connected with a tubing string; a pair of resilient sleeve packers axially spaced on said mounting member for sealing against the well wall to provide therebetween a pressure chamber; means providing with said body member a passage for conducting fluid between said chamber and said tubing string; means including said mounting member providing with said body member a passage for conducting fluid between said first named passage and the exterior of said members above the uppermost packer; closure means on one of said members for opening and closing said last named passage responsive to relative axial movement between said members; means including said mounting member providing wtih said body momber a constantly open passage for conducting fluid between port means opening exteriorly of said members above and below said pair of packers; said members being relatively rotatable; a slip expander on said mounting member; locking means comprising coengaging means operatively connected with said string and mounting member for holding said members, respectively, movable to one position against relative axial movement; said coengaging means being movable to another position releasing said members for relative axial movement responsive to limited rotative movement of said string relative to said mounting member; said coengaging means being operable to transmit rotative thrust from said string to said mounting member; a sleeve mounted on said mounting member for axial and rotative movement relative thereto; slips engaged with said expander; links connected with said slips; means rotatably connecting said links with said sleeve; locking means operable in one position for holding said mounting member against axial movement relative to said sleeve; said last named locking means releasing said mounting member responsive to limited rotation of said mounting member relative to said sleeve; drag springs on said sleeve engageable with the wall of the well to restrain rotative and axial movement of said sleeve; actuating members surrounding said mounting member between the adjacent ends of said packers; said actuating members being movable in opposite directions and connected with said adjacent ends of said packers; means connected with one of said actuating members and engaged with said body member and with the other of said actuating members, and actuated by said body member to move said actuating members in opposite directions to expand said packers against the wall of the well responsive to axial movement of said body mem-ber relative -to said mounting member.

l2. A well tool including: a tubular body adapted to be positioned in a well on a tubing string; tubular means mounted on said body; said body and tubular means being relatively axially movable; a pair of axially spaced resilient sleeve packers on said tubular means; said body having a port between said packers; means for releasably anchoring said tubular means in the Well; a pair of members supported on said tubular means operatively connected with the ends of said packers and operable responsive to longitudinal movement relative to said tubular means for simultaneously compressing said packers t0 expand them into sealing engagement with the wall of the well; and means operatively connected to said body and to said pair of members for moving said pair of members longitudinally as aforesaid.

13. A well tool including: a pair of tubular inner and outer members telescopically connected for relative axial movements; means for connecting the inner of said members with a tubing string for rotative movement of Said string relative to said inner member; coengaging locking means on said connecting means and the outer of said members, respectively, cooperable when in one position for releasably holding said string and said outer member against relative axial movement; said locking means being movable to another position releasing said string and inner member for axial movement relative to said outer member responsive to initial limited rotative movement of said string and connecting means relative to said outer member; said coengaging means being operable to transmit rotative thrust from said string to said outer member; a sleeve axially movable on said outer member; a second locking means comprising coengaging means on said outer member and said sleeve, respectively, cooperable when in one position for holding said outer member against axial movement relative to said sleeve and in another position releasing said outer member for axial movement relative to said sleeve; means connected with said sleeve for frictionally contacting the wall of the well; said second locking means being movable to said another position for releasing said outer member for axial movement relative to said sleeve responsive to rotative movement of said string and outer member relative to said inner member and said sleeve following said initial rotative movement of said string; anchoring means connected with said outer member and said sleeve operable to anchor said outer member to the well wall following release of said second locking means and a continued downward movement of said string and inner member relative to said sleeve; an element supported by said outer member for actuation against the well wall; and means interposed between said element and said inner member operable for actuating said element against said Wall responsive to additional downward movement of said inner member under the weight of said tubing string following release of said second locking means.

14. A well tool including: a pair of inner and outer tubular members telescopically connected for relative axial movement; means for connecting said inner member with a tubing string as a continuation of said string and to permit rotative movement of said string relative to said inner member; coengageable locking means connected with said connecting means and said outer member, respectively, cooperable when in one position for releasably holding said string and said outer member against relative axial movement; said locking means being movable to another position releasing said string and inner member for axial movement relative to said outer member responsive to an initial limited rotative movement of said string and connecting means relative t said outer member; said coengaging means being operable to transmit rotative thrust from said string to said outer tubular member; a sleeve axially movable on said outer member; a second locking means comprising coengaging means on said outer member and said sleeve, respectively, cooperable when in one position for holding said outer member against axial movement relative to said sleeve and in another position releasing said outer member for axial movement relative to said sleeve; means connected with said sleeve for frictionally contacting the wall of the well; said second locking means being movable to said another position for releasing said outer member for axial movement relative to said sleeve responsive to rotative movement of said string and outer member relative to said inner member and said sleeve following said initial rotative movement of said string; anchoring means connected with said outer member and said sleeve operable to anchor said outer member to the well wall following release of said second locking means and axial movement of said string and inner member relative to said sleeve; an element supported by said outer member for actuation relative to said outer member into and out of contact with the wall of the well; and means connected with said inner member operable to so actuate said element responsive to downward and upward movement of said inner member relative to said outer member.

l5. A well tool including: a pair of inner and outer tubular members telescopically connected for relative axial movements; means for connecting said inner member with a tubing string for axial movement therewith in a well; coengaging locking means connected with said connecting means and said outer member, respectively, cooperable when in one position for releasably holding said string and said outer member against relative axial movement; said coengaging means being movable to another position releasing said string and outer member for axial movement of said string relative to said outer member responsive to initial limited rotative movement of said string relative to said outer member; a sleeve axially movable on said outer member; said coengaging means being operable to transmit rotative thmst from said string to said outer member; a second locking means comprising coengaging means operatively connected with said outer member and said sleeve, respectively, cooperable when in one position for holding said outer member against axial movement relative to said sleeve and movable to another position releasing said outer member for axial movement relative to said sleeve; means connected with said sleeve for frictionally contacting the wall of the well; said second locking means releasing said outer member for axial movement relative to said sleeve responsive to rotative movement of said string and outer member relative to said sleeve following said initial rotative movement of said string; anchoring means operatively connected with said outer member and said sleeve operable an anchor said outer member to the well wall following release of said second locking means and initial axial movement of said string and outer member relative to said sleeve; an element supported by and actuatable laterally from said outer member for engaging the wall of the well; and means mechanically connecting said element with said inner member to actuate said element against the well wall responsive to further axial movement of said inner member.

16. A well tool including: a pair of inner and outer tubular members telescopically connected for relative axial movements; means for connecting said inner member with a tubing string as a continuation thereof and to permit rotative movement of said string relative to said inner member; coengaging locking means connected with said connecting means and said outer member, respectively, cooperable when in one position for releasably holding said string and said outer member against relative axial movement; said coengaging means being movable to another position releasing said string and outer member for axial movement of said string relative to said outer member responsive to initial limited rotative movement of said string relative to said outer member; said coengaging means being operable to transmit rotative thrust from said string to said outer member; a sleeve axially movable on said outer member; a second locking means comprising coengaging means operatively connected with said outer member and said sleeve, respectively, cooperable when in one position for holding said outer member and said sleeve against relative axial movement and movable to another position releasing said outer member for axial movement relative to said sleeve; means connected with said sleeve for frictionally contacting the wall of the well; said second locking means releasing said outer member for axial movement responsive to further rotative movement of said string and outer member relative to said inner member and said sleeve; anchoring means operatively connected with said outer member and said sleeve operable to anchor said outer member to the well wall following release of said second locking means and initial axial movement of said string and inner member relative to said sleeve; said outer member having an upper section and a lower section; means forming a swivel connection between said upper and lower sections; an element supported by said lower section for actuation against the well wall; and means connected with said outer member and said element for actuating said element against the wall of the well responsive to further axial movement of said inner member.

References Cited in the file of this patent UNITED STATES PATENTS 2,150,406 Taylor Mar. 14, 1939 2,156,939 Fulkerson May 2, 1939 2,172,948 Weiler Sept. 12, 1939 2,223,099 Fisher Nov. 26, 1940 2,255,451 Otis Sept. 9, 1941 2,633,200 Humason Mar. 31, 1953

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