Subsurface Safety Valve Well Tool Operable By Differential Annular Pressure

Abstract

A well tool apparatus adapted for connection in a production tubing including a separable flow housing having a bore extending therethrough with a rotatable ball bore closure means positioned in said bore which is operable in response to differential fluid pressure in an annular area about the tubing and a means for releasably securing the separable portions of the housing for effecting housing separation by either a directional fluid pressure or mechanical movement to enable retrieval of the rotatable ball.

Description

CROSS-REFERENCE TO RELATED APPLICATIONS

This application is related to my co-pending applications Ser. No. 359,757, filed of even date with the present application, entitled "METHOD AND APPARATUS FOR A SUBSURFACE SAFETY VALVE OPERATING WITH DIFFERENTIAL ANNULAR PRESSURE" and Ser. No. 359,758, filed of even data with the present application, entitled, "IMPROVED SUBSURFACE SAFETY VALVE WELL TOOL OPERABLE BY DIFFERENTIAL ANNULAR PRESSURE", both of which are assigned to the assignee of the present application.

BACKGROUND OF THE INVENTION

This invention relates to the field of a subsurface safety valve well tool operable by differential annular pressure.

The differential annular pressure operated subsurface safety valves disclosed in my co-pending applications, identified hereinabove, serve a most useful purpose of preventing undesired blow-out flow from a well through a production tubing. Both of these disclosures employed releasable securing means requiring either tubing rotation or a reduction of well pressure to effect housing release. The tubing rotation release is undesirable because inadvertent and unexpected tubing joint separation may occur which requires a fishing operation to retrieve the disconnected tubing. The well pressure reduction release required additional operations of setting a plug or killing the well prior to separating the housing. The additional time and effort to effect housing release utilizing those means was costly and yet a positive release and separation of the housing with those inventions was not assured.

SUMMARY OF THE INVENTION

A new and improved differential annular pressure operated rotatable ball subsurface safety valve well tool having separable housing portions releasably secured together to form a portion of a production tubing during safety valve operation which are selectively released by either a directional fluid pressure or mechanical manipulation to enable retrieval of the rotatable ball when desired without requiring retrieval of the production tubing connected below the well tool.

An object of the present invention is to provide a new and improved subsurface safety valve well tool.

Another object of the present invention is to provide a new and improved subsurface safety valve well tool having a housing separating selectively by either a fluid pressure or a mechanical manipulation of the housing.

BRIEF DESCRIPTION OF THE DRAWINGS

FIGS. 1A and 1B are side views, partially in section, from top to bottom of the well tool of the present invention, illustrating the well tool releasably securing the housing portion S;

FIGS. 2A and 2B are views, similar to FIGS. 1A and 1B, illustrating the housing portions of the well tool prior to effecting separation; and

FIG. 3 is a side view, illustrating construction of the well tool pivot member.

DESCRIPTION OF THE PREFERRED EMBODIMENT

The well tool of the present invention, generally designated T in the Figs., is connected at a subsurface location in a production tubing (not illustrated) to control undesired upwardly flow from the well through a bore of the production tubing to the ground or earth surface (not illustrated). The well tool T includes a flow housing H comprising two releasably secured separate portions to enable selective desired separation of the housing H and having a longitudinal flow passage or bore X in communication with the bore of the production tubing for flowing well fluids through the secured housing H. Disposed in the bore X is a movable bore closure means B to control flow of fluid therethrough which is retrievable with a portion of the housing H and is normally operable in response to a differential fluid pressure in an annular area adjacent the flow housing H for controlling the undesired flow in the bore X and which may be releasably locked in an open position when desired.

The flow housing H is connected with the production tubing at its upper and lower ends by suitable means, such as threaded box and pin connections (not illustrated) as is well known in the art, to form a portion of the production tubing for flowing well fluids and the like through the bore X of the flow housing H.

As illustrated in FIG. 1B, the flow housing H includes a lower or first portion L and an upper or second portion U which are releasably secured together to form the flow housing H. Preferably, the lower portion L is in the form of a sleeve 10 which extends upwardly from the lower threaded pin connection (not illustrated) to an upwardly facing annular shoulder 10a for supporting the upper housing portion U. The sleeve 10 includes an outer surface 10b having a downwardly facing annular shoulder surface 10c which is partially machined away to form fluted openings 10d for communicating fluid pressure by the shoulder 10c. The production tubing is positioned within a well casing C having a reducer or adapter N providing an upwardly facing annular shoulder S engaging the shoulder 10c for mounting the flow housing H at a desired subsurface location with the well casing C to support the flow housing H and connected production tubing thereto in the well casing C. While the well tool T of the present invention is described as being positioned in the well casing C, it will be immediately appreciated by those skilled in the art that the production tubing and the well tool T may be positioned in the bore of any well conduit, such as within the bore of another production tubing, with no change in the operation of the well tool T of the present invention as herein disclosed.

The tubular member 10 includes an inner surface 10e defining the bore X through the tubular member 10 and having a left-hand thread 10f formed thereon adjacent the shoulder 10a and a right-hand thread 10g located below and in spaced relationship to the thread 10e to provide a sealing surface 10h therebetween.

The upper portion U of the housing preferably includes a tubular member 11 extending downwardly from the upper threaded box connection (not illustrated) to telescope within the lower sleeve 10 to position a lower annular shoulder 11a adjacent the threads 10g. The tubular member 11 includes an outer surface 11b forming a downwardly facing annular shoulder 11c engaging the shoulder 10a to support and block further downward movement of the tubular member 11 and for positioning a pair of replacable seal rings 11d to effect an annular fluid seal with the surface 10h to block leakage of fluid therebetween.

The bore closure means B is disposed in the bore X of the housing H formed by an inner surface 11e of the tubular member 11 and is movable to and from an open position for enabling flow of fluid through the bore X and the production tubing and to and from a closed position for blocking the flow of fluid through the bore X. The bore closure means B preferably includes a ball member 20 having a flow port 20a formed therethrough which is rotatable to an from a closed or transverse position (FIG. 1B) for blocking flow of fluid through the bore X and to and from an opened or aligned position (FIG. 2B) for enabling flow of fluid through the aligned flow port 20a. The ball 20 includes a spherical outer sealing surface 20b having two separate portions removed to form a pair of parallel flat portions 20c with each of the circular shaped flats 20c having a radially extending elongated recess 20d formed therein for operably connecting the ball 20 with the flow housing H. Reference is made to my two co-pending applications, identified hereinabove for a more detailed illustration and description of the ball 20.

The bore closure means B further includes a longitudinally movable upper seat ring 21 which is concentrically positioned in the bore X immediately above the ball 20 and in engagement therewith with a sealing element 21a and a lower seat ring 22 which is also concentrically positioned in the bore X immediately below the ball 20 and also in engagement therewith. The lower seat ring 22 mounts thereon a ring shaped sealing element 22a having an arcuate upwardly facing annular surface 22b for effecting an annular fluid seal with the spherical surface 20b of the ball 20 for blocking passage of fluid therebetween and an O-ring 22 and the tubular member 11 to block passage of fluid therebetween. The bore closure means B also includes a biasing means or seal spring 24 which is located between a downwardly facing annular shoulder 22c of the seat ring and an upwardly facing annular shoulder 11f for biasing the seat ring 22 to move upwardly for maintaining sealing contact with the spherical surface 20b of the ball 20.

The flow housing H includes an operator member 40 and a pivot member 30 for effecting desired rotational movement of the ball 20 to and from the open and closed positions. The pivot sleeve member 30 is concentrically mounted in the bore X between the ball 20 and the tubular member 11 and is longitudinally movable between a first or upper position (FIG. 1B) for rotating the ball 20 closed and a second or lower position (FIG. 2B) for rotating the ball 20 to the open position. The pivot member 30 includes a pair of inwardly projecting eccentric fingers 30a, which are secured to the pivot member 30 by suitable fastening means, such as threaded engagement at 30b, and which extend into the corresponding recesses 20d for rotating the ball 20 when there is relative longitudinal movement between the ball 20 and the pivot member 30. The pivot member 30 further includes a lower annular shoulder 30c for engaging an upwardly facing annular shoulder 11g to provide a lower movement limit stop to the pivot member 30 when the ball 20 is rotated open and an upwardly facing tapered annular shoulder 30d for engaging a tapered downwardly facing annular shoulder 11h to provide an upper movement limit stop for the pivot member 30 when the ball 20 is rotated closed. The pivot member 30 includes an inner surface 30e which guides the longitudinal movement of the seat ring 21.

The tubular operator member 40 is concentrically positioned in the bore X above the pivot member 30 and is also longitudinally movable between an upper position (FIGS. 2A and 2B) and a lower position (FIGS. 2A and 2B) for moving the pivot member 30 to rotate the ball 20 to and from the open and closed positions. The operator member 40 extends upwardly from a downwardly facing annular shoulder 40a (FIG. 1B) telescoped within the pivot member 30 and adjacent the upper seat ring 21 to an upwardly facing annular shoulder 40b (FIG. 2B). The operator member 40 includes a downwardly facing annular shoulder 40c formed on an outer surface 40d which engages an upwardly facing flat annular shoulder 30f of the pivot member 30 for moving the pivot member 30 to the lower position along with the operator 40 to rotate the ball 20 open.

As illustrated in FIG. 1A, secured on the outer surface 40d of the operator 40 is an outwardly projecting annular collar 40e forming an upwardly facing annular shoulder surface 40f and a downwardly facing annular shoulder surface 40g with a flow passage 40h extending through the collar 40e between the annular shoulders 40f and 40g. Concentrically mounted with the outer surface 40d of the operator 40 above the collar 40e and movable relative thereto is a directional flow valve or closure ring 41 which serves as a check valve for enabling some upwardly flow through the low passage 40h while blocking downwardly flow through the flow passage 40h by moving into engagement with the surface 40f. The closure ring 41 includes a pair of seal rings 41a and 41b which effect annular fluid seals with the surfaces 40f and 40d, respectively, to block leakage of fluid therebetween. The closure ring 41 is biased away from the surface 40f by a spring 42 to enable passage of fluid through the flow passage 40h under certain desired production tubing leak testing conditions as set forth in greater detail in my related application identified hereinabove.

The operator 40 is slideably sealed by a pair of seal rings 14 and 15 with the tubular member 11 at spaced locations above and below the collar 40e, respectively, and by a seal ring 43 mounted with the collar 40e to block leakage of fluid therebetween. The three annular seals so effected form a pair of annular expansible chambers 44 and 45 located above and below the annular collar 40e, respectively. The upwardly facing annular shoulder surface 40f between the seal rings 15 and 43 and the closure ring 41 between the seals 41a and 41b form a portion of the chamber 44 for enabling the fluid pressure in the chamber 44 to urge thereon for urging movement of the operator member 40 downward to the lower position for rotating the ball 20 open. The annular surface 40g between the seal rings 14 and 43 forms a portion of the chamber 45 for enabling the fluid pressure in the chamber 45 to urge thereon for urging movement of the operator member 40 to the upper position for enabling the ball 20 to rotate closed.

The outer surface 11b mounts a packing or seal ring 12 thereon adjacent the operator 40 for effecting an annular fluid seal between the well casing C and the tubular member 11 to block leakage of fluid in the annular area therebetween. The seal 12 divides the annular area between the production tubing and the well casing C into an upper chamber or reservoir R above the seal 21 and a lower chamber or reservoir P below the seal 12 and above a well packer (not illustrated). The lower reservoir P communicates with the chamber 45 through a passageway 11i formed through the tubular member 11 while the chamber 44 communicates with the reservoir R through a flow aperture or port 11j formed through the tubular member 11. Thus, the annular pressure differential between the upper reservoir R and the lower reservoir P will be sensed across the collar 40e of the operator 40 for rotating the ball 20 to and from the open and closed position. A greater pressure in the upper reservoir R urging downwardly on the annular shoulder 40f will move the operator 40 to the lower position to rotate the ball 20 open while a greater pressure in the lower reservoir P will urge upwardly on the annular shoulder 40g for moving the operator 40 upwardly to rotate the ball 20 closed. The flow passage 40h is of such small flow capacity in comparison with the volume of the reservoirs R and P, that the differential pressure urging upwardly from the reservoir P when the ring 41 moves from sealing engagement with the surface 40f will move the operator 40 to the upper position prior to equalizing with the pressure in the upper reservoir R. As illustrated in FIG. 3, the urging of the plurality of springs 31, located in a pair of recesses 30g formed in the surface 30c of the pivot member 30 and engaging the shoulder 11g is normally sufficient to move the pivot member 30 and the operator 40 to the upper position when the pressures in the reservoirs R and P are substantially equal.

As illustrated in FIG. 1A, the flow housing H further includes means for releasably locking the ball 20 in the open position in response to a directional fluid pressure to thereafter block movement of the ball 20 to the closed position comprising a lug ring 50, a detent 51 and a piston ring 52, all of which are movably mounted in the bore X above the operator 40. The lug ring 50 includes a plurality of circumferentially spaced downwardly extending fingers or lugs 50a engaging the upper annular shoulder 40b of the operator 40 while enabling fluid communication through the ring 50 between the lugs 50a. The lug ring 50 is longitudinally movable between an upper position (FIG. 1A) and a lower position (FIG. 2A) moving the engaged operator 40 downwardly for rotating the ball 20 to the open position. The detent 51 is a gapped, radially expansible ring positioned above and in engagement with an upwardly facing annular shoulder 50b formed on the lug ring 50 above the lugs 50a and which is also longitudinally movable with the lug ring 50 between an upper expanded position (FIG. 1A) and lower position (FIG. 2A), where the detent will radially contract to move into an annular locking recess 11k of a chamber defining surface 11m of the tubular member 11. The piston ring 52 is positioned above the detent ring 51 and is longitudinally movable along the surface 11m with the lug ring 50 from an upper position (FIG. 1A) to a lower position (FIG. 2A) for locking the detent 51 in the recess 11k where it blocks upward movement of the lug ring 50. The piston ring 52 includes a constant diameter inner surface 52a adjacent the surface 11m and a constant diameter outer surface 52b engaging a constant diameter inner surface 50c of the lug ring 50 for guiding relative longitudinal movement therebetween. The surfaces 52a and 52b mount O-rings 52c and 52d, respectively, for effecting sliding seals with the tubular member 11 and the lug ring 50 to block leakage of fluid about the piston ring 52. Sealed in this manner, the piston ring 52 provides an upwardly facing annular shoulder 52e and a downwardly facing annular shoulder 52f for a direcitonal fluid pressure to urge thereon to effect longitudinal movement of the piston ring 52. The inner surface 52a includes an annular locking recess 52g adjacent the lower annular shoulder 52f for blocking radial expansion of the detent 51 out of the recess 11k when the piston ring 52 is in the lower position to lock the ball 20 open. The lug ring 50 mounts an O-ring 50d on an outer surface 50e thereof for slidably sealing the lug ring 50 with the tubular member 11. By sealing the lug ring at this location, the lug ring 50 is provided with a pressure responsive annular effective surface area between seals effected by the O-rings 52d and 50d in order that the differential pressure urging on the piston ring 52 will also urge on this pressure responsive effective surface area for effecting the desired movement of the lug ring 50 along with the piston 52. The lug ring 50 includes an upwardly facing annular shoulder 50f, which will be referred to as the upwardly facing pressure responsive effective surface area of the lug ring 50 for urging downwardly movement thereof for purposes of this disclosure, and which also engages a downwardly facing annular shoulder 11n of the tubular member 11 to provide an upper movement limit stop for the lug ring 50. The lug ring 50 further includes a downwardly facing annular shoulder 50g, which will also be referred to as the downwardly facing pressure responsive effective surface area for purposes of this disclosure, for urging upwardly movement of the lug ring 50 in response to directional fluid pressure urging thereon. Mounted in the bore X below the lug ring 50 is a biasing means or spring 53 for urging the lug ring 50 to remain in the upper position until the predetermined directional pressure urges downwardly thereon.

The fluid pressure seals effected by the O-rings 50d, 52c and 52d block fluid communication by the lug ring 50 and the piston ring 52 for forming an upper or first chamber 55 above the lug ring 50 and a second or lower chamber 56 below the annular shoulder 52f of the piston ring 52 and adjacent the lugs 50a. The upper annular expansible chamber 55 communicates with the bore X through a port 11p formed in the tubular member 11 adjacent the annular shoulder 11n while the lower annular expansible chamber 56 communicates with the bore X through the area between the lugs 50a and which are spaced from the port 11p to enable the establishment of a fluid seal in the bore 11 therebetween. Normally, fluid pressure in the bore X is communicated into both the chamber 55 and the chamber 56 to provide equal and offsetting urging on the lug ring 50 and the piston ring 52, wherein the spring 53 maintains the lug ring 50, the piston ring 52 and the detent 51 in the upper position.

The flow housing H additionally includes a means for releasably securing the sleeve 10 with the tubular member 11 in response to a predetermined directional fluid pressure to enable normal pressure responsive operation of the ball 20 for controlling flow of fluid in the bore X comprising a plurality of four movable latch dogs 60 mounted with the tubular member 11 in a corresponding plurality of windows or apertures 11q which are formed equally circumferentially spaced about the tubular member 11. The plurality of latch dogs 60 move radially to and from a retracted or free position enabling separation of the tubular member 11 from the sleeve 10 (FIG. 2A) and to and from an extended or locking position for securing the tubular member 11 with the sleeve 10 (FIG. 1A) in response to the directional fluid pressure. The casing C includes a section or joint J forming a tapered downwardly facing annular locking shoulder A engaging the latch dogs 60 in the locking position for securing the tubular member 11 by blocking upward movement of the tubular member 11 in the casing C from the sleeve 10. When the plurality of latch dogs 60 are moved radially inwardly to the free position, the tubular member 11 may be removed from the sleeve 10 and withdrawn from the well with the production tubing below the sleeve 10 supported by the sleeve 10 and remaining in the well casing C.

The means for releasably securing the flow housing H includes a lock member 61 disposed in the tubular member 11 adjacent the latch dogs 60 and which is longitudinally movable to and from a first or lower position (FIG. 1A) for locking the latch dogs 60 in the locking position and to and from an upper or second position (FIG. 2A) for enabling the latch dogs 60 to move radially inwardly to the free position. The lock member 61 is preferably in the form of a sleeve having a constant diameter outer surface 61a adjacent the latch dogs 60 with a pair of spaced, tapered edged annular recesses 61b formed therein for receiving corresponding inwardly projecting annular collars 60a formed on the latch dogs 60 to enable the latch dogs 60 to move to the free position when the lock member 61 moves to the upper position to align the recesses 61b with the collars 60a. Downward movement of the lock member 61 to the lower position will cam or wedge the latch dogs 60 with the tapered edges of the recesses 61b to move radially outwardly to the locking position in engagement with the shoulder A and in which position the latch dogs 70 are locked by the surface 61a moving adjacent the latch dog collars 60a. Thereafter, when the lock members 61 move back to the upper position, engagement of the latch dogs 60 with the tapered annular shoulder L will wedge the latch dogs 60 radially inwardly to the free position when the tubular member 11 is elevated.

The locking member 61 mounts a pair of O-rings 61c and 61d thereon adjacent the latch dogs 60 for effecting an annular fluid seal with the tubular member 11 above and below the latch dogs 60, respectively, for blocking leakage of fluid between the tubular member 11 and the locking member 61.

The means for releasably securing the flow housing H further includes a detent 62 and a latch piston 63 located adjacent the locking member 61. The detent 62 is a radially expansible gapped split ring which is longitudinally movable to and from an upper position (FIG. 2A), along a constant diameter surface 11s of the tubular member 11 and to and from a lower position (FIG. 1A), where it moves into a tapered edge annular recess 11t formed in the surface 11s. The latch piston 63 is a ring-shaped member positioned above the detent 62 which is also movable longitudinally to and from an upper or free position (FIG. 2A) and to and from a lower or latching position (FIG. 1A), where it blocks radial expansion of the detent 62 from the recess 11t with a downwardly extending concentric ring extension 63a. The latch piston 63 mounts a pair of O-rings 63b and 63c for effecting sliding seals with the locking member 61 and the surface 11s and tubular member 11 to block leakage of fluid therebetween. The locking member 61 includes an upwardly facing annular shoulder 61e adjacent the detent 66 which engages the detent 61 locked in the recess 11t to block upward movement of locking member 61 when the detent 62 is held in the recess 11t by the latch piston extension 63a. The locking member 61 is fluted at 61f to enable communication of fluid pressure between the shoulder 61e and a downwardly facing annular shoulder 61g which engages a lower movement limit stop ring 64 secured to the tubular member 11. A vertically extending flow passage or port 11u formed in the tubular member 11 communicates the fluid pressure in the chamber 55 to the area adjacent the stop 64.

By sealing the locking member 61 and the latch piston 63 with the O-rings 61c, 61d, 63b and 63c, a first or upper annular expansible chamber 65 is formed above and a second or lower annular expansible chamber 66 is formed below the locking member 61 and the latch piston 63. Fluid pressure in the lower chamber 66 will urge upwardly on the locking member 61 on a downwardly facing annular pressure responsive surface area between the O-rings 61d and 63b, designated 61h for urging the locking member 61 to move upwardly. The pressure in the chamber 66 will also be communicated along the flukes 61f for urging on a downwardly facing annular pressure responsive effective surface area between the O-rings 63b and 63c, designated 63d, for moving the latch piston 63 to move upwardly. The flow port 11u communicating the chambers 55 and 66 insures that the fluid pressure in these chambers is equal and the same as the fluid pressure communicated through the port 11p.

Fluid pressure in the upper chamber 65 will urge on an upwardly annular facing pressure responsive effective surface area of the latch piston 63 between the O-rings 63c and 63d designated 63e, for moving the latch piston 63 to the lower position. The fluid pressure in the chamber 65 will also urge downwardly on an upwardly facing annular effective surface area 61e of the lock member 61 between the O-rings 61c and 63b to urge the lock member 61 to move downwardly. The tubular member 11 includes a flow port 11v formed therethrough for communicating the bore X with the chamber 65 which is spaced from the flow port 11p to enable the establishment of a seal therebetween in the bore X.

The well tool T includes a plurality of plug means M for controlling the directional urging of the fluid pressure to effect operation of the well tool T. The control fluid pressure is provided by connecting a pump or other fluid pressure generating source to the bore of the production tubing above the well tool T which is communicated by the plug means M positioned in the bore X of the housing H in a controlled manner to provide a predetermined directional fluid pressure for accomplishing desired operation of the well tool T. Preferably the plug means M includes a movable lug N which radially expands into a pair of annular landing recesses 11w formed in the bore X of the tubular member 11 to secure and position the plug means M therewith. The plug means M may be moved through the bore of the production tubing by either a wireline or a pump-down operation to position the plug means M in the bore X.

The plug means M, which are old and well known in the art, are provided with seals and internal passages to communicate the fluid pressure above the plug means M through the ports 11p and 11v or the openings adjacent the lugs 50a in a manner predetermined by the selection of the plug means M to accomplish desired operation of the well tool T.

As illustrated in FIG. 1A, the plug means M includes a locking plug 70 mounting a replacable packing 70a thereon to seal the bore X of the housing H between the port 11v and the port 11p. The locking plug 70 includes a flow passage 70b formed therethrough which communicates the pressure above the plug 70 to a location adjacent the port 11v for communication therethrough into the chamber 65 for urging the lock member 61 and the latch piston 63 to move downwardly for locking the latch dogs 60 in engagement with the annular shoulder L for securing the tubular member 11 with the sleeve 10. The fluid seal effected by the packing 70a blocks communication of this increased pressure past the plug 70 where it would be communicated into the chamber 66 and thus enables the escape of fluid from the chamber 66 into the bore X below the plug 70 as the locking member 61 and the latch piston 63 move downwardly.

As illustrated in FIG. 2A, the plug means M includes a cross-over or unlocking plug 71 mounting a plurality of replacable packings or O-rings 71a, 71b and 71c, for effecting three annular spaced seals along the plug 71 to block communication of fluid pressure thereacross. The unlocking plug 71 includes a first flow channel 71d formed therein for communicating the fluid pressure above the plug 71 to the area of the bore X adjacent the port 11p and a vent passage 71e for communicating the area in the bore X adjacent the flow port 11v with the bore X below the plug 71. Fluid pressure in the bore of the production tubing above the plug 71 will thus be communicated into the chamber 55 and 66 where it will urge the latch piston 63 to move upwardly to release the detent 62 from the recess 11t and thereafter move the latch piston 63, the detent 52 and the lock member 61 to the upper position for enabling the latch dog 60 to move to the free position. The fluid pressure in the chamber 65 will move the lug ring 50, the detent 51 and the locking piston 52 downwardly as a unit for moving the operator 40 and the pivot member 30 downwardly to rotate the ball 20 open and for locking the ball 20 in the open position by the movement of the detent 51 into the recess 11k where it will be locked by additional downward movement of the locking piston 52. This arrangement of the plug 71 is preferred in that it allows the pulling of the production tubing and the tubular member 11 dry instead of wet.

By the use of a plug means M (not illustrated), effecting an annular seal below the flow port 11p, the ball 20 may be rotated and locked open by communicating the controlled pressure into the chambers 55 and 66 while preventing its communication through the openings between the lugs 50a and which also communicates the fluid pressure above the plug means M into the chamber 65 in order that the fluid pressure urging on the lock member 61 and the latch piston 63 are equal and offsetting and the tubular member 11 remains secured to the sleeve 10.

In addition to the hydraulic means for releasably securing the sleeve 10 with the tubular member 11, the means for releasably securing the flow housing H includes a mechanical manipulation release which may selectively be used to effect separation of the housing H which includes a left-hand threaded engagement at 11x of the tubular member 11 above the chamber 65. A righthand rotation manipulation of the production tubing above the flow housing H will shear the threaded pin 80 and move the inner threaded sleeve 11y upwardly relative to the remainder of the tubular member 11 a sufficient distance to move the lock member 61 with the stop ring 64 secured to the portion 11y to the upper position to effect release of the latch dogs 60.

In the use and operation of the present invention, the sleeve 10 is connected in the production tubing using the pin connection and the left-handed thread connection 10f is engaged with a well conduit (not illustrated) for lowering the sleeve 10 with the production tubing into the well until the shoulder 10c engages the shoulder S of the casing adapter N which blocks further downward movement of the sleeve 10 and the production tubing in the casing C. Right-hand rotation is then imparted to the well conduit above the sleeve 10 for disengaging the threaded connection at 10f to retrieve the well conduit from the casing C.

The tubular member 11 is then connected in the production tubing using the box connection and is lowered into the casing C while adding joints of tubing until the shoulder 11c engages the shoulder 10a of the sleeve 10 with the tubular member 11 telescoped within the sleeve 10 for effecting a fluid seal with packing 11d. When the tubular member 11 is supported on the tubular member 10, the seal 12 effects the annular fluid seal between the tubular member 11 and the well casing C to form the upper and lower reservoirs R and P, respectively. The locking plug 71 is then run through the bore of the production tubing to be received in the bore X where it is secured by movement of the lugs N into the recesses 11w. Fluid pressure, normally hydraulic, is then increased in the bore X above the plug 71 which is communicated through the port 11v to move the locking member 61 downwardly to force the dogs 60 to the locking position for securing the tubular member 11 with the sleeve 10. The plug 71 is then retrieved from the bore X back to the surface. The well is then completed by any suitable well known method and hydrocarbons and other well fluids are thus enabled to flow upwardly through the bore of the production tubing and the bore X of the flow housing H.

When it is desired to produce hydrocarbons and the like from the well, the pressure in the upper reservoir R is increased by a pressure generating source or means which is communicated through the port 11j into the chamber 44 for urging the operator 40 to move downwardly along with the engaged pivot member 30 to rotate the ball 20 to the open position.

When it is desired to close in the well at the subsurface location or a catastrophic well failure resulting in a well blow-out occurs, pressure in the upper reservoir R is decreased or otherwise vented to reduce the pressure in the chamber 44 to a pressure less than the pressure in the chamber 45 for moving the operator 40 to the upper position. The pressure in the lower reservoir P when the ball 20 is rotated open will expand the casing C below the seal 12 to provide a latent fluid pressure in the reservoir P for closing the ball 20 when the pressure in the upper reservoir R is reduced. The flow passage 40h is of such a small size when compared to the volume of reservoirs P and R, that the pressure equalization therebetween will not occur until after the operator 40 is moved to the upper position and is maintained in that position by the spring 31. When rotated closed, the ball 20 co-acts with the sealing element 22a and the O-ring 23 to substantially block upwardly flow of fluid through the bore X of the housing H and the production tubing.

A subsequent increase in pressure in the reservoir R above the pressure in the lower reservoir P will again rotate the ball 20 to the open position for enabling production of hydrocarbons and other well fluids.

When it is desired to run various well tools and the like through the bore X of the production tubing Y to a location below the well tool T and in necessary operations for completing the well, the ball 20 may be releasably locked in the open position by the use of a suitable plug means M (not illustrated) which is received and secured in the bore X of the housing H to communicate fluid pressure above the plug means M through the port 11p while blocking communication of that pressure to the area of the bore X adjacent the lugs 50a. Fluid pressure above the plug means M is then increased and communicated through the port 11p and into the expansible chamber 55 to urge downwardly on the upwardly facing annular shoulder 52e and 50f of the piston ring 52 and the lug ring 50, respectively, for moving the lug ring 50, the detent 51 and the piston ring 52 downwardly from the upper position, as a single engaged unit relative to the tubular member 11. When the detent 51 is adjacent the annular recess 10k, the detent 51 will move into the recess 10k and enable the piston ring 52 to move downwardly relative to both the detent 51 and the lug ring 50 for locking the detent 51 in the recess 10k and blocking subsequent upward movement by engagement of the lug ring 50. The downward movement of the lug ring 50 moves the operator member 40 downwardly along the pivot member 30 for rotating the ball 20 open and in which position it is locked by engagement of the lug ring 50 with the detent 51. Thereafter, differential fluid pressure in the reservoirs R and P is ineffective to rotate the ball 20 from the open position. The plug means M may thereafter be released and retrieved from the bore X to enable the running and retrieval of other well tools through the bore of the production tubing all of which is well known in the art.

When it is desired to return the ball 20 to pressure responsive operation, an unlocking plug means M (not illustrated) is run in through the bore of the production tubing in the bore X of the housing H. The unlocking plug means M communicates the increased fluid pressure to the area of the bore X adjacent the lugs 50a and on into the chamber 56 while blocking communication through the ports 11p. The pressure differential so established across the lug ring 50 and the piston ring 52 will initially move the piston ring 52 upwardly relative to the detent 51 and the lug ring 50 for releasing the detent 51 from the annular recess 10k. Thereafter, the differential pressure urging on the lug ring 50 and the piston ring 52 will move the lug ring 50, the detent 51 and the piston ring 52 upwardly, as a unit relative to the tubular member 11, to the upper position. This movement enables the spring 31 to urge the pivot member 30 to move upwardly for rotating the ball 20 to the closed position. The unlocking plug means M is retrieved to the surface with the ball 20 restored to the normal pressure responsive operation. Preferably in locking and unlocking the ball 20, the plug means M is suitably sealed and provided with flow passages to maintain the same fluid pressure in the chambers 65 and 66.

Should the valve malfunction for any reason, such as, but not limited to, a scored sealing surface, a broken spring or the like, the tubular member 11 mounting the ball 20 may be selectively released and retrieved without the need to pull the sleeve 10 and the lower production tubing thus enabling the use of more inexpensive workover equipment for replacement. Preferably, the ball 20 is locked open during the retrieval operation, but that operation is not required.

The preferred manner to release the tubular member 11 from the sleeve 10 is to run in the unlocking plug 71 and then increase the pressure in the bore X above the plug 71 for controlled communication into the chamber 66 while blocking communication into the chamber 65 to establish a pressure differential across the lock member 61 and the latch piston 63. Initially the latch piston 63 will move upwardly in response to the pressure to free the detent 62 and enable movement of the lock member 61 to the upper position for releasing the latch dogs 60. The initial upward movement of the tubular member 11 wedges the latch dogs 60 radially inwardly with the shoulder A. The ball 20 is then retrieved for enabling desired work to be accomplished. Thereafter, the tubular member 11 may be lowered into telescoping engagement with the sleeve 10 and be releasably secured therewith by controlled fluid pressure as set forth hereinabove.

Should the fluid pressure fail to effect release of the securing means, a right-hand rotational manipulation of the production tubing imparted to the tubular member 11 may be employed to effect release. Such rotation shears the pin 80 and enables the sleeve section 11y to move upwardly relative to the remainder of the tubular member 11 to move the lock member 61 to align the recesses 61b with the collar 60a. The stop ring 64 engages the lock member 61 at the shoulder 61g to move the lock member 61 to release the latch dogs 60.

The foregoing disclosure and description of the invention are illustrative and explanatory thereof, and various changes in the size, shape and materials as well as in the details of the illustrated construction may be made without departing from the spirit of the invention.

Claims

What is claimed is:

1. A well tool adapted for connection in a production tubing including:

a. a flow housing having a bore formed therethrough and comprising a first housing portion and a second housing portion, said housing adapted for connection in the production tubing to form a portion thereof with said bore in communication with a flow passage of the production tubing for enabling flow of fluid through said bore;

b. bore closure means mounted with said flow housing for movement in said bore to and from an open position for enabling flow fluid through said bore and to and from a closed position for blocking flow of fluid through said bore; and

c. means with said flow housing for releasably securing said first housing portion of said flow housing with said second housing portion of said flow housing, said means for releasably securing comprising means moving in response to a predetermined directional fluid pressure thereon to release said second housing portion from said first housing portion to enable removal of said bore closure means from the well.

2. The invention as set forth in claim 1, wherein:

said means releasably securing said first housing portion of said flow housing with said second housing portion of said flow housing includes means responsive to a predetermined directional fluid pressure thereon to separate said first and second housing portions.

3. The invention as set forth in claim 1, wherein:

said means for releasably securing said first housing portion of said flow housing with said second housing portion of said flow housing inclues means responsive to a mechanical manipulation imparted to said housing to separate said first and second housing portions.

4. The invention as set forth in claim 1, wherein:

said means for releasably securing said first housing portion of said flow housing with said second housing portion of said flow housing includes means selectively operable to separate said first and second housing portions in response to either the urging of a predetermined directional fluid pressure or a mechanical manipulation of said housing.

5. The invention as set forth in claim 1, wherein said means for releasably securing said first housing portion of said flow housing with said second housing portion of said flow housing includes:

a. a latch dog mounted with said flow housing and movable to and from a locking position for securing said first housing portion with said second housing portion and to and from a free position for releasing said first housing portion from said second housing portion; and

b. a lock member mounted with said flow housing and movable to and from a first position for moving said latch dogs to the locking position in response to the urging of a predetermined directional fluid pressure and to and from a second position for enabling said latch dogs to move to the free position.

6. The invention as set forth in claim 5, wherein:

said latch dog moves radially outwardly relative to the longitudinal axis of said flow housing in moving from the free position to the locking position wherein said first portion and said second housing portion of said flow housing are secured.

7. The invention as set forth in claim 5, wherein the apparatus is adapted for use in a well casing having a surface forming a downwardly facing shoulder and wherein:

said latch dog has a surface which moves into engagement with the shoulder when moving to the locking position wherein said flow housing is releasably secured.

8. The invention as set forth in claim 5, including:

a plurality of latch dogs mounted with said flow housing and simultaneously movable to and from the locking position and to and from the free position.

9. The invention as set forth in claim 5, including:

a. means with said first housing portion of said flow housing for mounting said flow housing with a well casing at a subsurface location for supporting said flow housing in the well; and

b. said bore closure means mounted with said second housing portion of said flow housing to enable removal of said bore closure means from the well when said second housing portion of said flow housing is released from said first housing portion of said flow housing.

10. The invention as set forth in claim 1, wherein:

said bore closure means includes a ball member having a flow port formed therethrough which is rotated to and from the open position enabling flow of fluid through said flow port and to and from the closed position where said ball member blocks flow of fluid through said bore of said flow housing.

11. The invention as set forth in claim 1, including:

means with said flow housing for effecting movement of said bore closure means to and from the open and closed position in response to a fluid pressure differential in an annular area between the production tubing and the well casing.

12. The invention as set forth in claim 1, including:

means with said flow housing for locking said bore closure means in the open position in response to a directional fluid pressure.