US3910352A - In-tubing safety valve well tool - Google Patents

Abstract

A safety valve well tool movable to a subsurface location through a bore of a production tubing for securing therewith in response to a predetermined fluid pressure for thereafter controlling undesired upwardly flow through the bore of the production tubing with a rotatable ball valve operating in response to a control fluid pressure communicated to the well tool through an annular passageway.

Description

United States Patent [191 [1 :1 3,910,352

Mott 1 Oct. 7, 1975 [5 lN-TUBING SAFETY VALVE WELL TOOL 3,391,740 7/1968 Edwards, Jr. 166/120 3,603,388 9/1971 C t 166/120 [75] Inventor: James Mott Houston 3,747,682 7/1973 166/224 A [73] Assignee: Hydril Company 22] il -9 1974 Primary Examiner.lames A. Leppink Attorney, Agent, or Firm-Pravel & Wilson [21] Appl. No.: 504,301

Related U.S. Application Data Continuation of Ser. No. 291,561, Sept. 25, 1974, abandoned.

U.S. Cl. 166/315; 166/120; 166/224 A Int. Cl.E21B 43/00; E21B 43/12 Field of Search 166/120, 126, 133, 188,

References Cited UNITED STATESPATENTS 11/1966 Tausch 166/120 zat C [57] ABSTRACT 9 Claims, 13 Drawing Figures U.S. Patent Oct. 7,1975Shem 1 0m 3,910,352

US. Patent Oct. 7,1975 Sheet 3 of6 3,910,352

M m LL I a 2 a W A My A J v v\ \IW 6 Q v 15 l W J. 7 .1 k WW/ ME \G d r 4/ *4 A A 7 4 J h C h fi C h A W w WWW w W 7 i u m, a, w u I US. Patent Oct. 7,1975 Sheet 5 of6 3,910,352

US. Patent Oct. 7,1975 Sheet 6 of6 3,910,352

l AB IN-TUBING SAFETY VALVE WELL TOOL CROSS-REFERENCE TO RELATED APPLICATIONS This is a continuation of application Ser. No. 291,561 filed Sept. 25, 1974 now abandoned.

BACKGROUND OF THE INVENTION This invention relates to the field of subsurface safety valves for use in wells.

While surface controlled safety valve well tools movable through a bore of a production tubing to a subsurface operating location are known, these well tools have previously required that the numerous costly and extremely hazardous installation and retrieval operations be performed downhole under well pressure. Other surface controlled safety valve well tools having an annular fluid pressure control passageway means, such as disclosed in US. Pat. Nos. 3,065,793, 3,065,794, 3,094,170, 3,332,497 and 3,497,004, required pulling the production tubing to retrieve the valve or holding a control fluid pressure with the casing either of which requirement increased the cost of the produced well fluids.

SUMMARY OF THE INVENTION A new and improved well tool movable through a bore of a production tubing including a housing mounting a rotatable ball bore closure means for controlling flow through the bore of the production tubing and which is releasably secured therein by a predetermined fluid pressure. The housing is connected with a second production tubing and communicating desired flow to the earth surface which is concentricallypositioned in the bore of the production tubing to form an annular flow passage therebetween for supplying control fluid pressure to the housing for operating the ball.

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

A further object of the present invention is to provide a new and improved in-tubing safety valve.

Yet another object of the present invention is to provide a new and improved surface controlled subsurface safety valve.

BRIEF DESCRIPTION OF THE DRAWINGS FIG. 1 is a side view, partially in section, illustrating te well tool of the present invention secured at a subsurface location in a bore of a production tubing;

FIGS. 2A, 2B, 2C and 2D are side views, partially in section, illustrating the well tool prepared for running in the well;

FIGS. 3A and 3B are side views, partially in section, illustrating the well tool secured with the production tubing;

FIGS. 4A and 4B are side views, partially in section, illustrating the valve operated open; and

FIGS. 5A, SB, 5C and 5D are views similar to FIGS. 4A, 4B, 4C and 4D, respectively, illustrating the well tool during retrieval from the well.

DESCRIPTION OF THE PREFERRED EMBODIMENT The well tool of the present invention, generally designated T, is operably positioned in a bore of a production tubing P at a subsurface or downhole location of a well W for controlling undesired upwardly flow of well fluids through the bore 0 of the production tubing P in response to a controlled fluid pressure communicated to the well tool T. An annular seal between the production tubing P and a well casing C effected by a well packer (not illustrated) directs upwardly flow from the well W through the bore 0 of the production tubing P to the well tool T. Desired upwardly flow from the well tool T is communicated through the bore of a second or inner production tubing or conduit Q positioned in the bore 0 of the production tubing P to a christmas tree X located at the earth surface or ground G. The christmas tree X provides a manifold for flowing the hydrocarbons and well fluids from the well W through the conduit A while communicating a source of controlled fluid pressure (not illustrated) through a conduit F with the well tool T for effecting operation thereof to control flow of fluid through the bore 0 of the production tubing P. The production tubing P is normally positioned in the well casing C, but the casing C is not required as the well too] T is equally adapted for use in wells W without the casing C.

The well tool T includes a housing H mounting thereon a securing means L and a seal means R which is movable through the bore 0 of the production tubing P to the desired subsurface location where the securing means L operates to mount the housing H with the production tubing P while the seal means R effects an annular seal between the housing H and the production tubing P. The well tool T further includes a bore closure means B movably mounted with the housing H and an actuator means D for effecting movement of the bore closure means B to an open position for enabling flow of fluids through the bore 0 of the production tubing P and to and from a closed position for substantially blocking flow of fluid through the bore 0 of the production tubing P.

As illustrated in FIG. 2A, the housing H includes an upper orfixed sleeve 10 and an intermediate or movable portion sleeve 1 l secured together by threaded engagement at 10a with an O-ring 12 blocking leakage of fluid between thesleeves 10 and 11. Thefixed sleeve 10 includes a threaded box connection (not illustrated) to secure the well tool T with the second production tubing Q for communicating flow of fluid through a longitudinally extending bore or flow passage M of the housing H through the second production tubing Q to the christmas tree X. The flow passage M is defined through thesleeve 10 by an inner surface 10b forming an upwardly facingannular shoulder 10c for receiving thereon a landing shoulder (not illustrated) of a plug means E (FIG. 3A), for supporting and properly positioning the plug means E in the flow passage M as is well known in the art.

Thesleeve 1 1 extends downwardly from an upper annular shoulder 1 la,adjacent threads 10a, to a lowerannular shoulder 1 1b (FIG. 2C) with aninner surface 11c defining a portion of the longitudinally extending housing flow passage M while an outer surface 11d serves as a movement guide for the securing means L concentrically mounted thereon.

The housing H further includes alower sleeve 13, operably connected with thefixed sleeve 10 and which extends upwardly from a downwardly facing lowerannular shoulder 13a (FIG. 28) to an upwardly facing annular shoulder 13b (FIG. 2C) above the seal means R with aninner surface 13c defining a bore or opening 13d through thesleeve 13 for concentrically mounting thesleeve 13 in telescoping relationship with thesleeve 1 1 and for forming a portion of the flow passage M for communicating the flow of fluid through the housing H.

The bore closure means B is movably disposed in thebore 13d and includes arotatable ball member 20 and a pair of inwardly extendingpivot pins 21 secured to thesleeve 13 at eccentric positions bythreads 21a for mounting theball 20 with thesleeve 13. Theball 20 is provided with a flow opening 20a therethrough and a pair of parallel, flatcircular surfaces 20b having a radially extending recess orgroove 200 formed in each of theflats 20b for receiving thepivot pin 21 therein. Longitudinal movement of theball 20 relative to thepivot pins 21 will impart relative rotation to theball 20 to and from an open or lower position (FIG. 4B) aligning the opening 20a with the housing flow passage M for enabling flow of fluid through the well tool T and to and from a closed or upper position (FIG. 2D) for substantially blocking flow of fluid through the passage M and the bore of the production tubing T. Reference is made to my co-pending application entitled PRES- SURE OPERATED SAFETY VALVE WITH LOCK MEANS, Ser. No. 72,034, filed Sept. 14, 1970, abandoned after filing of continuation application Ser. No. 256,194 on May 23, 1974, for a more detailed description and illustrations of the relationship of thepivot pins 21 and the ball in rotating to and from the open and closed positions when there is relative movement therebetween.

The actuator means D includes a pair of movable sleeve operators ancl 31 positioned in thebore 13d above and below theball 20, respectively, for effecting the required longitudinal movement of theball 20 to rotate theball 20 open and closed. Thesleeves 30 and 31 are longitudinally movable to and from a first or lower position (FIG. 4A and 4B) for effecting opening rotation of theball 20 and to and from a second or upper position (FIGS. 2C and 2D) for rotating theball 20 closed Thelower sleeve 31 includes anouter surface 31a having an outwardly projecting annular collar 31b formed thereon to provide a downwardly facing annular shoulder surface 310 and an upwardly facingannular shoulder surface 31d which engage spaced annular shoulders l3e and 13f, respectively, to provide movement limit stops for thesleeve 31. Thesleeve 31 is normally urged to move to the upper position by a spring means 32 concentrically mounted about thesleeve 31 between theshoulder 31c and an annular shoulder 13g formed on thesleeve 13 and which is imparted to theball 20 by an upper arcuateannular surface 31e engaging an outerspherical sealing surface 20d of theball 20.

Theupper sleeve 30 includes a downwardly facing arcuateannular shoulder 300 which engages thespherical surface 20d for moving theball 20 downwardly to effect opening rotation of theball 20 and to effect an annular seal between theball 20 and thesleeve 30 to block upwardly flow of fluid in the passage M when theball 20 is rotated closed. Thesleeve 30 further includes anouter surface 30b mounting the sealing element 33 (FIG. 2C) thereon to effect a sliding seal with thelower housing sleeve 13 to block leakage of fluid therebetween and an outwardly projectingannular collar 30c forming an upwardly facingannular shoulder surface 30d and a downwardly facingannular shoulder surface 30e. Thesleeve 30 is normally urged to move to the upper position by a biasing means orspring 34 concentrically mounted about thesleeve 30 between an upwardly facing shoulder 1311 of thesleeve 13 and theshoulder 30e which moves theshoulder 30d into engagement with theshoulder 11b to provide an upper movement limit stop for thesleeve 30. Mounted on thecollar 300 is an O-ring 36 for effecting a sliding annular seal with thesurface 13c of thesleeve 13 to block leakage of fluid therebetween with theseal 33 blocking communication of fluid pressure in thebore 13d below theball 20 to theshoulder surface 30e. Theintermediate sleeve 11 mounts an O-ring 14 in a recess formed on the surface adjacent theshoulder 11b to effect a sliding seal with thesurface 30b of thesleeve 30 above thecollar 300 to provide a pressure responsive effective surface area on thesleeve 30, designated 30d, between the seals effected by the O-rings 14 and 36 for urging thesleeve 30 to move downwardly to rotate theball 20 open.

As illustrated in FIG. 2A, the means for releasably securing the housing with the production tubing is operable in response to a predetermined fluid pressure and includes a movable lower orfirst wedge 40, an upper orsecond wedge 41, and a plurality of threeslips 42 engaging thewedges 41 and 42 for effecting operational movement of theslips 42. Theslips 42 are movable to and from a retracted or free position (FIGS. 2A and 5A) enabling the housing to move through the bore 0 of the production tubing P and to and from an expanded or locked position (FIG. 3A) for engaging and frictionally gripping the production tubing P to block relative movement between theslips 42 and the production tubing P. Theslips 42 are positioned in a correspondending plurality of three windows orapertures 41a which are equally circumferentially spaced about the sleeve-likeupper wedge 41 with an upper tapered inner edge of theslips 42a engaging a tapered upper surface 41b of thewindows 41a for moving theslips 42 radially as they move longitudinally along the surface 41b. Theupper wedge 41 is concentrically mounted with thesleeve 10 by an upwardly facingannular shoulder 10d engaging a downwardly facingannular shoulder surface 410 which enables relative circumferential rotational movement between theupper wedge 41 and thetubular member 10 when thetubular member 10 is rotated to partially disengage thethreads 10a while blocking relative longitudinal movement therebetween during such rotation. Thewedge 41 is concentrically mounted with thesleeve 11 with an inwardly projecting bolt or threaded pin 41d secured with theupper wedge 41 extending into a longitudinally extending slot or groove lle formed in the outer surface 11d of thesleeve 11 and which blocks relative circumferential rotation between thetubular member 11 and thewedge 41 while enabling limited longitudinal movement therebetween when thesleeve 10 is rotated to partially disengage the threaded engagement at 10a.

Thelower wedge 40 includes a tapered upwardly facingannular shoulder surface 40a engaging a lower tapered inner surface 42b of theslips 42 for wedging or forcing theslips 42 radially outwardly as thelower wedge 40 moves longitudinally from a first or lower position (FIG. 2A) to a second or upper position (FIG. 3A) toward theupper wedge 41. As illustrated in FIG. 2B, thelower wedge 40 is preferably in the form of a sleeve which extends downwardly from the upperannular shoulder 40a to a downwardly facing annular shoulder 40b with a longitudinal movement guidinginner surface 40c thereof forming a downwardly facing pressure responsiveannular shoulder surface 40d for urging upward movement of thewedge 40 and which is located adjacent an opening or port 11f formed through thesleeve 11. Thewedge 40 is concentrically mounted with thesleeve 11 and carries an O-ring 43 thereon to effect a sliding annular seal with thesleeve 11 to block leakage of fluid therebetween.

Mounted below theshoulder 40a in the concentric annular space between thewedge 40 and thesleeve 1 1, is apiston ring 44 and adetent latch assembly 45 for maintaining thewedge 40 in the upper position to hold theslips 42 in the locked position. Thepiston 44 is slidably sealed to thesleeve 11 and thewedge 40 by 0-rings 44a and 44b, respectively, to provide an upwardly facing pressure responsive annular surface 440 adjacent the port 11f for urging thepiston 44 to move downwardly in response to the predetermined fluid pressure communicated through the port 11f and urging thereon.

Thedetent assembly 45 includes aring member 46 having a plurality of four circumferentially equally spaced windows or apertures 46a formed therein for mounting therein a corresponding plurality ofmovable detents 47 having a saw-tooth surface 47a biased towards engagement with thewedge 40 by a spring means 48 mounted with thering 46. The saw-tooth surface 47a of thedetent 47 is shaped to enable upward movement of thewedge 40 relative to thedetent 47 while downward movement of thewedge 40 along thesurface 47a moves thedetents 47 to engage and move longitudinally along a taperedlower surface 46b of the windows 46a to wedge thedetent 47 to move radially outwardly to block any downward movement of thewedge 40 relative to thedetent 47. Thedetent ring 46 is initially blocked from downward movement by a snap-ring 49 mounted below thering 46 and which is easily moved downwardly along with thering 46 when the predetermined fluid pressure is applied to thepiston 44 for moving thering 46 downwardly by engagement of adjacentannular shoulders 46c and 44d.

Thelower wedge 40 is illustrated, in an incorrect sectional view in FIG. 2A, connected with theupper wedge 41 by a threaded pin orbolt 40e secured with thelower wedge 40 and which extends outwardly within a longitudinal window slot 4le formed through thewedge 41 to enable limited relative longitudinal movement therebetween while blocking relative circumferential rotational movement. Concentrically mounted with thetubular member 11 below thewedge 40, is a floating sleeve 50 (FIG. 2B) having a threaded connector pin orbolt 50a secured thereto which extends outwardly into a longitudinal extendingwindow slot 40f formed through thewedge 40 for connecting thewedge 40 and the floatingsleeve 50 to enable limited relative longitudinal movement therebetween while blocking circumferential rotational movement therebetween similar to the connection between thewedges 40 and 41 by thepin 40a and which is also illustrated in perspective.

The floatingsleeve 50 extends downwardly from an upwardly facingannular shoulder 50b adjacent the snap-ring 49 (FIG. 28) to a downwardlyfacingannular shoulder 50c (FIG. 2C) adjacent the seal means R and having alongitudinal slot 50d formed therethrough adjacent theshoulder 500 for receiving therein an outwardly projecting threaded bolt or pin member 131' secu'red to thesleeve 13 for connecting thelower sleeve 13 with the floatingsleeve 50 for enabling limited relative longitudinal movement while blocking relative circumferential rotational movement therebetween.

concentrically mounted with thesleeve 13 below theannular shoulder 50c of the floatingsleeve 50 is the sealing means R including a replaceable resilientlydeformable sealing element 60 which is forced or wedged to expand radially outwardly into annular sealing engagement with the production tubing P (FIG. 3B) by longitudinal upward or contracted movement of thesleeve 13 toward theannular shoulder 500 of thesleeve 50 while longitudinal downward movement of thesleeve 13 from the sleeve 50 (FIGS. 2C and 5C) stretches the sealingelement 60 to contract sufficiently radially inwardly to enable the housing H to move through the bore 0 of the production tubing P.

In the use and operation of the present invention, the well tool T is assembled in the condition illustrated in the FIGS. 2A, 2B, 2C, and 2D, and transported to the site of the well W. The well tool T is then connected with the inner production tubing Q using the threaded box connections (not illustrated) as is well known in the art and lowered down the bore 0 of the production tubing P to the desired subsurface location for setting the well tool T by the addition of tubing joints to the inner production tubing Q.

When the well too] T is at a desired subsurface location the plug means E is lowered down the bore of the inner production tubing Q where it is received in the flow passage M of the housing I-I (FIG. 3A) and positioned and secured therein by engagement with thelanding shoulder 10c as is old and well known in the art. The plug means E includes a downwardly extendingextension 71 from the landing shoulder (not illustrated) to anenlarged head 71a mounting a plurality of replacable annular packing or sea] rings 71b thereon to block communication of the flow passage M above and below the seals so effected by the seal rings 71!). Theextension 71 of the plug means E is suitably dimensioned to locate the seal rings 71b below the flow port 11f when the plug means E is properly positioned in the housing H to enable a pump or other pressure generating means (not illustrated) connected to the conduit A of the christmas tree X to increase the pressure in the passage M above therings 71b. This fluid pressure is communicated in this predetermined manner through theport 1 If to urge on the pressureresponsive shoulder 40d for urging thelower wedge 40 to move upwardly while urging on the shoulder 440 of thepiston 44 for urging thepiston ring 44 and thedetent assembly 45 to move downwardly.

As illustrated in FIG. 3A, the upward movement of thewedge 40 forces the plurality ofslips 42 outwardly to engage the production tubing P with a serratedouter surface 42c for increasing the frictional engagement therebetween to enable the securing of the housing H with the production tubing P at any desired subsurface location. While thewedge 40 is moving upward relative to the saw-toothdetent 47, thepiston 44 is urging thering 46 to move downwardly and bringing the split-ring 49 into full engagement with theannular shoulder 50b of the floatingsleeve 50; Such movement is illustrated in greater. detail by comparing the relative position of thepin 50a in theslot 40f in FIGS. 23 and 3B. Thereafter, the saw-tooth edge 47a of thedetent 47 will block downward movement of thelower wedge 40 from the upper position and maintain theslips 42 in the radially expanded locked position. When the pressure in the flow passage M above theseals 71b is reduced, the plug means E may then be retrieved back to the surface G and removed from the well W by any suitable tool as is well known in the art.

When the pressure in the passage M above theball 20 is reduced below the pressure in the bore of the production tubing P below theclosed ball 20, such as by venting from the conduit A, a pressure differential will be established across theball 20 for urging upwardly movement thereof. This urging will move both theball 20 and thesleeve 13 upwardly relative to the floatingsleeve 50 which is blocked from moving upwardly relative to thewedge 40 by engagement of theshoulder 50b with thering 49.

The relative upward movement of thesleeve 13 to the floatingsleeve 50 will deform the sealingelement 60 sufficiently to effect an annular seal about thetubular member 13 with the production tubing P to block leakage of fluid therebetween. This relative motion is also illustrated by comparing the position of the threadedpin 13i in theslot 50d in FIGS. 2C and 3B. The unbalanced upwardly urging of the well prsssure on thesleeve 13 will thereafter maintain thesleeve 13 in this position relative to the floatingsleeve 50.

The establishment of an annular seal by the sealingelement 60 thus defines an annular passageway for communicating control fluid pressure communicated into the bore of the production tubing at the christmas tree X through the conduit F to a location adjacent the well tool T and above theannular seal 60.

As illustrated in FIG. 4A, this annular control fluid pressure is communicated through theslot 50d of the floating sleeve immediately above the sealingelement 60 to a longitudinally extendingrecess 11g formed in theouter surface 1 1a of thesleeve 11 adjacent the sealingelement 60 for communicating the fluid pressure above theannular shoulder 13d of thesleeve 13 to an annular chamber formed between thesleeves 11 and 13 above the pressure responsiveannular shoulder surface 30d of theoperator 30. The control fluid pressure communicated to the well W through the conduit P will thus be communicated to theshoulder 30d for urging theoperator 30 to overcome the upwardly urging of thesprings 32 and 34 to move theoperator sleeves 30 and 31 and theball 20 to the lower positions for effecting opening rotation of theball 20 and enabling flow of fluids through the flow passage M.

When it is desired to block flow of fluid from the well W the control fluid pressure in the conduit F is reduced, enabling thesprings 32 and 34 to move theoperator sleeves 31 and 30, respectively, to the upper position for rotating theball 20 closed and maintaining theball 20 in that position until the control fluid pressure is again introduced to the conduit F for effecting opening rotation of theball 20.

When it is desired to retrieve the well tool T from the well W back to the surface G, it is only necessary to impart right-hand rotation of the inner production tubing Q at the christmas tree X to effect partial disengagement of the threadedconnection 10a between thetubular member 10 and thetubular member 11. As illustrated in FIG. a, this effects a relative upward movement of theupper wedge 41 and the tubular member from thelower wedge 40 to space thewedges 40 and 41 sufficiently for enabling theslips 42 to move inwardly to the free position as illustrated. With theslips 42 in the free position, the inner production Q is elevated to bring the threadedmember 50a of the floatingsleeve 50 into engagement with the lower edge of theslot 40f to move the floatingsleeve 50 upwardly relative to thelower sleeve 13 and enabling the sealing element to contract inwardly for breaking or releasing the annular seal. The floatingsleeve 50 will move upwardly relative to thesleeve 13 until thepin 13i engages the bottom of theslot 50d for moving thesleeve 13 and theball 20 upwardly along with the floatingsleeve 50 until the well tool T is removed from the bore 0 of the production tubing P at the surface G. The rotation of the inner production tubing Q moves the tubular member 1 l downwardly relative to thetubular member 10 and thesleeve 13 to move theshoulder 11b into engagement with theoperator shoulder 30d and move theoperator 30 to the lower position for rotating theball 20 to the open position and holding it in that position during the retrieval operation.

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.

I claim:

1. A well tool for controlling flow of well fluids through the bore of a first production tubing at a desired subsurface location in a well, including:

a first production tubing extending downwardly from the earth surface in a well;

a tubular housing movable through the bore of the first production tubing to and from the desired subsurface location and having a flow passage extending therethrough for enabling communication of well fluids and the like in the bore of the first well tubing past said tubular housing;

bore closure means mounted with said housing and movable to and from an open position for enabling flow of fluid through said flow passage and a closed position for substantially blocking flow of fluid,

through said flow passage;

a second production tubing sealingly connected with said tubular housing and having a bore disposed in flow communication with said flow passage and extending upwardly from said tubular housing within the bore of the first production tubing for forming a flow passage for well fluids from said tubular housing to the earth surface separate from the bore of the first production tubing, said second production tubing spaced from said first production tubing;

means for releasably securing said tubular housing .with the first well tubing at a desired subsurface location, said means for releasably securing actuated by increasing fluid pressure in the bore of the second production tubing and said flow passage;

means for releasably sealing said tubular housing with the first production tubing to direct the flow of well fluids from the bore of the first production tubing below said tubular housing into said flow passage, said means for sealing actuated by said means for releasably securing to effect sealing when said tubular housing is secured with the first production tubing; and

actuator means mounted with said housing foreffecting movement of said boreclosure means to and from theopen and closed positions in response to a control fluid pressure cornmunicatedto said actuator means from the bore of the firstproduction tubing through a port in said housing located above said means for sealing and separately from the well fluids in the bore of the second production tubing wherein said well tool is operably installedin a well. I 2. A well tool for controlling flow of well fluids through the bore of a well tubing, including:

a well casing extending downwardly from the earth surface in a well and secured in the well; a first production tubing extending downwardly from the earth surface within a bore of the well casing;

a well packer disposed adjacent the lower end of of the first production tubing for effecting a seal between the well casi ng and thefi rst production tubmg;

a tubular housing movable through a bore of the first production tubing to and from a subsurface location and having a flow passage extending therethrough for enabling communication of well fluids and the like in the bore of the first production tubing past said housing;

a second production tubing having a lower end sealingly secured with said tubular housing with said second production tubing movable through the bore of the first production tubing with said tubular housing, said second production tubing having a bore disposed in flow communication with said flow passage and extending upwardly from said tubular housing for forming a conduit for well fluids from said tubular housing separate from the bore of the first production tubing;

bore closure means mounted with said housing and movable to and from an open position for enabling flow of fluid through said flow passage and a closed position for substantially blocking flow of fluid through said flow passage;

means mounted with said housing for effecting movement of said bore closure means to and from the open and closed position; and

means mounted with said housing for releasably securing said housing with said first production tubing at a subsurface location in response to a controlled application of fluid pressure in said flow passage wherein said well tool is operably positioned in a well.

3. A well too] apparatus for controlling flow of well fluids through a first production tubing at a desired subsurface location in a well, including:

a tubular housing movable through a bore of the first production tubing to and from the desired subsurface location in a well and having a flow passage extending through said tubular housing for enabling communication of well fluids and the like in the bore of the first production tubing below said housing with a location above said tubular housing, said tubular housing having means for connecting and sealing said tubular housing with a second production tubing disposed within the bore of the first production tubing above said tubular housing for communicating said flow passage with the bore of the second production tubing and for supporting said tubular housing with the second production tubing when said tubular housing moves to and from the desired subsurface location by movement of the second production tubing within the bore 01 the first production tubing;

seal means mounted with said housing and actuatable for blocking passage of fluids between said tubular housing and the first production tubing to direct the flow of well fluids through said flow passage oi said housing;

bore closure means mounted with said housing and movable to and from an open position for enabling flow of fluid through said flow passage a closed position for substantially blocking flow of fluid through said flow passage;

actuator means mounted with said housing for effecting controlled movement of said bore closure means to and from the open and closed position in response to a control fluid pressure communicated to said tubular housing through the bore of the first production tubing; and

means with said housing for releasably securing said housing with the first production tubing at the desired subsurface location, said means for releasably securing actuated by the application of fluid pressure in a predetermined manner in said flow passage wherein said well tool is operably positioned in a well.

4. The well tool apparatus as set forth in claim 3, including:

said bore closure means including a ball-type valve member having a flow port formed therethrough and disposed in said flow passage for rotational movement to and from the open position with said flow port aligned with said flow passage to enable flow of fluid through said flow port and said flow passage and the closed position where said balltype member blocks flow through said flow passage wherein rotation of said ball controls flow of fluid in the bore of the production tubing.

5. The well tool apparatus as set forth in claim 3, wherein:

said seal means when actuated expands radially outwardly for effecting an annular seal between said tubular housing and the first production tubing.

6. The well tool apparatus as set forth in claim 3, wherein said means for releasably securing includes:

a slip means mounted with said tubular housing and movable to and from a free position enabling said housing to move through the bore of the first production tubing and a locked position engaging the first production tubing for blocking movement of said housing relative to the first production tubing; and

wedge means mounted with said tubular housing and movable in response to the urging of a predetermined pressure from a first position to a second position for effecting movement of said slip means from the free position to the locked position wherein said housing is secured with the first production tubing.

7. A method of installing a controlled safety valve well tool at a desired subsurface location in a well having a first well tubing extending downwardly from the ground surface for flowing well fluids to the surface through the bore of the first well tubing, including the steps of:

connecting a safety valve well tool with a second well tubing; moving the safety valve to a desired subsurface location in the well through the bore of the first well tubing by moving the second well tubing into the bore of the first well tubing; securing the safety valve with the first well tubing at the desired location by increasing fluid pressure in the second well tubing in a controlled manner; and forming a fluid passage to the safety valve from the surface between the first well tubing and the second well tubing to communicate control fluid pressure to the safety valve from the surface wherein the safety valve well tool is installed. 8. A method of installing and operating a controlled safety valve well too] at a desired subsurface location in a well having a first well tubing extending downwardly from the ground surface for flowing well fluids to the surface through the bore of the first well tubing, including the steps of:

connecting a safety valve well tool with a second well tubing;

moving the safety valve to a desired subsurface location in the well through the bore of the first well tubing by moving the second well tubing into the bore of the first well tubing;

securing the safety valve with the first well tubing at the desired location by increasing fluid pressure in the second well tubing;

forming a fluid passage to the secured safety valve from the surface between the first well tubing and the second well tubing to communicate control fluid pressure to the safety valve from the surface; and

controlling the pressure of the fluid in the fluid passage for operating the safety valve wherein the safety valve operates to control flow at the subsurface location.

9. The method as set forth in claim 8, wherein the step of controlling includes:

increasing the pressure of the fluid in the fluid passage for operating the safety valve to the open condition.

Claims (9)

1. A well tool for controlling flow of well fluids through the bore of a first production tubing at a desired subsurface location in a well, including: a first production tubing extending downwardly from the earth surface in a well; a tubular housing movable through the bore of the first production tubing to and from the desired subsurface location and having a flow passage extending therethrough for enabling communication of well fluids and the like in the bore of the first well tubing past said tubular housing; bore closure means mounted with said housing and movable to and from an open position for enabling flow of fluid through said flow passage and a closed position for substantially blocking flow of fluid through said flow passage; a second production tubing sealingly connected with said tubular housing and having a bore disposed in flow communication with said flow passage and extending upwaRdly from said tubular housing within the bore of the first production tubing for forming a flow passage for well fluids from said tubular housing to the earth surface separate from the bore of the first production tubing, said second production tubing spaced from said first production tubing; means for releasably securing said tubular housing with the first well tubing at a desired subsurface location, said means for releasably securing actuated by increasing fluid pressure in the bore of the second production tubing and said flow passage; means for releasably sealing said tubular housing with the first production tubing to direct the flow of well fluids from the bore of the first production tubing below said tubular housing into said flow passage, said means for sealing actuated by said means for releasably securing to effect sealing when said tubular housing is secured with the first production tubing; and actuator means mounted with said housing for effecting movement of said bore closure means to and from the open and closed positions in response to a control fluid pressure communicated to said actuator means from the bore of the first production tubing through a port in said housing located above said means for sealing and separately from the well fluids in the bore of the second production tubing wherein said well tool is operably installed in a well.

2. A well tool for controlling flow of well fluids through the bore of a well tubing, including: a well casing extending downwardly from the earth surface in a well and secured in the well; a first production tubing extending downwardly from the earth surface within a bore of the well casing; a well packer disposed adjacent the lower end of of the first production tubing for effecting a seal between the well casing and the first production tubing; a tubular housing movable through a bore of the first production tubing to and from a subsurface location and having a flow passage extending therethrough for enabling communication of well fluids and the like in the bore of the first production tubing past said housing; a second production tubing having a lower end sealingly secured with said tubular housing with said second production tubing movable through the bore of the first production tubing with said tubular housing, said second production tubing having a bore disposed in flow communication with said flow passage and extending upwardly from said tubular housing for forming a conduit for well fluids from said tubular housing separate from the bore of the first production tubing; bore closure means mounted with said housing and movable to and from an open position for enabling flow of fluid through said flow passage and a closed position for substantially blocking flow of fluid through said flow passage; means mounted with said housing for effecting movement of said bore closure means to and from the open and closed position; and means mounted with said housing for releasably securing said housing with said first production tubing at a subsurface location in response to a controlled application of fluid pressure in said flow passage wherein said well tool is operably positioned in a well.

3. A well tool apparatus for controlling flow of well fluids through a first production tubing at a desired subsurface location in a well, including: a tubular housing movable through a bore of the first production tubing to and from the desired subsurface location in a well and having a flow passage extending through said tubular housing for enabling communication of well fluids and the like in the bore of the first production tubing below said housing with a location above said tubular housing, said tubular housing having means for connecting and sealing said tubular housing with a second production tubing disposed within the bore of the first production tubing above said tubular housing for communicating said flow passage with the bore of the second production tubing anD for supporting said tubular housing with the second production tubing when said tubular housing moves to and from the desired subsurface location by movement of the second production tubing within the bore of the first production tubing; seal means mounted with said housing and actuatable for blocking passage of fluids between said tubular housing and the first production tubing to direct the flow of well fluids through said flow passage of said housing; bore closure means mounted with said housing and movable to and from an open position for enabling flow of fluid through said flow passage a closed position for substantially blocking flow of fluid through said flow passage; actuator means mounted with said housing for effecting controlled movement of said bore closure means to and from the open and closed position in response to a control fluid pressure communicated to said tubular housing through the bore of the first production tubing; and means with said housing for releasably securing said housing with the first production tubing at the desired subsurface location, said means for releasably securing actuated by the application of fluid pressure in a predetermined manner in said flow passage wherein said well tool is operably positioned in a well.

4. The well tool apparatus as set forth in claim 3, including: said bore closure means including a ball-type valve member having a flow port formed therethrough and disposed in said flow passage for rotational movement to and from the open position with said flow port aligned with said flow passage to enable flow of fluid through said flow port and said flow passage and the closed position where said ball-type member blocks flow through said flow passage wherein rotation of said ball controls flow of fluid in the bore of the production tubing.

5. The well tool apparatus as set forth in claim 3, wherein: said seal means when actuated expands radially outwardly for effecting an annular seal between said tubular housing and the first production tubing.

6. The well tool apparatus as set forth in claim 3, wherein said means for releasably securing includes: a slip means mounted with said tubular housing and movable to and from a free position enabling said housing to move through the bore of the first production tubing and a locked position engaging the first production tubing for blocking movement of said housing relative to the first production tubing; and wedge means mounted with said tubular housing and movable in response to the urging of a predetermined pressure from a first position to a second position for effecting movement of said slip means from the free position to the locked position wherein said housing is secured with the first production tubing.

7. A method of installing a controlled safety valve well tool at a desired subsurface location in a well having a first well tubing extending downwardly from the ground surface for flowing well fluids to the surface through the bore of the first well tubing, including the steps of: connecting a safety valve well tool with a second well tubing; moving the safety valve to a desired subsurface location in the well through the bore of the first well tubing by moving the second well tubing into the bore of the first well tubing; securing the safety valve with the first well tubing at the desired location by increasing fluid pressure in the second well tubing in a controlled manner; and forming a fluid passage to the safety valve from the surface between the first well tubing and the second well tubing to communicate control fluid pressure to the safety valve from the surface wherein the safety valve well tool is installed.

8. A method of installing and operating a controlled safety valve well tool at a desired subsurface location in a well having a first well tubing extending downwardly from the ground surface for flowing well fluids to the surface through the bore of the first well tubing, includiNg the steps of: connecting a safety valve well tool with a second well tubing; moving the safety valve to a desired subsurface location in the well through the bore of the first well tubing by moving the second well tubing into the bore of the first well tubing; securing the safety valve with the first well tubing at the desired location by increasing fluid pressure in the second well tubing; forming a fluid passage to the secured safety valve from the surface between the first well tubing and the second well tubing to communicate control fluid pressure to the safety valve from the surface; and controlling the pressure of the fluid in the fluid passage for operating the safety valve wherein the safety valve operates to control flow at the subsurface location.

9. The method as set forth in claim 8, wherein the step of controlling includes: increasing the pressure of the fluid in the fluid passage for operating the safety valve to the open condition.

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