US3467185A

US3467185A - Pressure and mechanically operated valve

Info

Publication number: US3467185A
Application number: US640249A
Authority: US
Inventors: Sanford R Dowden
Original assignee: Otis Engineering Corp
Current assignee: Otis Engineering Corp
Priority date: 1967-05-22
Filing date: 1967-05-22
Publication date: 1969-09-16
Anticipated expiration: 1986-09-16

Description

Sept. 16, 1969 5, DQWDEN PRESSURE AND MECHANICALLY OPERATED VALVE 3 Sheets-Sheet 1 Filed May 22. 1967 w mn H V 2mm W w R 3m! .m m F5 Sept. 16, 1969 s. R. DOWDEN PRESSURE AND MECHANICALLY OPERATED VALVE 3 Sheets-Sheet 2 Filed May 22, 1967 R w 0 A m. m W n m e w 2 m A .m o F D R. //W X 0 M r O f n A 2 s W Q 3 Q m C! 8 m b. F H -ELI-EZI E: L52: .2. MU M Sept. 16, 1969 s. R. DOWDEN PRESSURE AND MECHANICALLY OPERATED VALVE 3 Sheets-Sheet 3 Filed May 22, 1967 6 m M 2 1Q I H g n Wm F W w m N x O 1 m o y 4, 7 f4 m. 0 v Q a w 5 w .u. '11 S M 1 1 6 I 3"lllliin'l r Y K/ z B m. J M

... lnll ll United States Patent Ofiice 3,467,185 Patented Sept. 16, 1969 3,467,185 PRESSURE AND MECHANICALLY OPERATED VALVE Sanford R. Dowden, Morgan City, La., assignor to Otis Engineering Corporation, Dallas, Tex., a corporation of Delaware Filed May 22, 1967, Ser. No. 640,249 Int. Cl. E21b 33/12; F16k 31/12 U.S. Cl. 166-147 23 Claims ABSTRACT OF THE DISCLOSURE An apparatus for circulating fluid through a well bore preparatory to the setting of a well packer within the well bore including a sliding sleeve valve for controlling flow through a lateral port in a flow conductor between a pair of packers. The sleeve valve is opened by fluid pressure within the flow conductor after plugging the conductor below the valve and is closed by mechanical force applied by a second flow conductor adapted to move relative to the first conductor.

This invention relates to well tools and more particularly relates to circulation devices for use in well bores.

It is an object of the invention to provide a well tool for circulating fluid between the interior and exterior of a flow conductor.

It is another object of the invention to provide a sliding sleeve valve for controlling fluid communication between the interior and exterior of a flow conductor disposed in a well bore.

It is another object of the invention to provide a sliding sleeve valve for a flow conductor which is opened by a fluid pressure differential between the interior and exterior of the flow conductor and is closed by a mechanical force.

It is another object of the invention to provide a sleeve valve for use on a flow conductor between packers in a well bore for circulating between the well bore and the flow conductor, the sleeve valve being operable by a fluid pressure differential between the interior and exterior of the flow conductor for opening the valve and being movable to a closed position by a mechanical force transmitted to the valve from a second flow conductor in the well bore movable relative to the first flow conductor.

It is still another object of the invention to provide a circulating device for a flow conductor which includes a sleeve valve slidably supported on the flow conductor for movement between positions covering and uncovering the lateral port in the conductor and having inner and outer seal means for sealing between the portions of the sleeve valve and the flow conductor and defining an annular area of the sleeve valve exposed on one side to pressure within the flow conductor and on the other side to pressure exterior of the flow conductor, the sleeve valve being movable to an open position by a pressure within the flow conductor greater than the pressure exterior of the flow conductor, and including an operator member slidable on the flow conductor for engaging the sleeve valve to move the valve from an open position back to a closed position over the port.

It is still another object of the invention to provide a sleeve valve for a flow conductor to control communication between the interior and exterior of the flow conductor through a lateral port in the conductor, the sleeve valve including first and second sleeve valve members telescopicably related and slidable on the flow conductor, the first sleeve valve member initially closing the port and being movable on the flow conductor by a fluid pressure differential between the interior and exterior of the flow conductor to open the port and the second sleeve valve member being movable toward the port and the first sleeve valve member to close the port by application of a mechanical force thereto.

It is another object of the invention to provide in combination with a sliding sleeve valve on a long flow conductor a lower packer on the flow conductor below the sliding sleeve valve' and an upper packer around the long flow conductor and a short flow conductor above the sliding sleeve valve, the upper packer permitting the short flow conductor to move downwardly relative to the long flow conductor for returning the sliding sleeve valve to its closed position.

Additional objects and advantages of the invention will be readily apparent from the reading of the following description of a device constructed in accordance with the invention, and reference to the accompanying drawings thereof, wherein:

FIGURE 1 is a schematic longitudinal view in section and elevation of a well system including one form of circulating device embodying the invention shown at its first closed position before the upper packer is set;

FIGURE 2 is a view similar to FIGURE 1 showing the lower packer expanded within the well bore and the circulating device in its open position;

FIGURE 3 is a view similar to FIGURE 2 showing the circulating device moved to a closed position and the upper packer expanded;

FIGURE 2A is a longitudinal diagrammatic view in section and elevation of one form of upper packer used with the circulating device showing the upper packer as it is run into the well bore and before the closing of the circulating device;

FIGURE 3A is a view similar to FIGURE 2A showing the upper packer expanded;

FIGURE 4 is an enlarged fragmentary longitudinal view in section and elevation of the circulating device illustrated in FIGURES l-3, showing the device at its first closed position while running into the well bore;

FIGURE 5 is a further enlarged fragmentary view in section and elevation of only a lower portion of the sleeve valve of the circulating device of FIGURE 4;

FIGURE 6 is a view in section along the line 6-6 of FIGURE 4;

FIGURE 7 is a fragmentary longitudinal view in section and elevation of an alternate form of circulating device embodying the invention, showing its sleeve valve closed; and,

FIGURE 8 is a longitudinal schematic view in section and elevation similar to FIGURES 1-3 of an alternate form of the circulating device of FIGURE 7.

Referring to the drawings, particularly FIGURE 1, a circulating device 20 embodying the invention is supported on a section 21' of a long tubing string 21 and a section 22' of a short tubing string 22. The circulating device is located between a lower well packer 23 and an upper well packer 24 which seal between the tubing strings and the inner wall surface of a Well casing 25. The circulating device opens and closes the ports 21a in the long tubing string for circulation between the tubing string and the casing annulus. A well head 30 is supported at the surface providing a closure over the upper end of the casing and has suitable apertures through which the tubing strings extend into the well. A conduit 31 having a valve 32 is connected to the short tubing string above the well head and similarly, a conduit 33 having a valve 34 is connected to the long tubing string 21. Another conduit 35 having a valve 40 is connected into the well head to the casing annulus 41 defined within the well casing 25 around the

tubing strings

21 and 22.

The circulating device 20 is lowered into a well with the ports 21a closed either at the time of or subsequent to the setting of the lower packer 23. After expanding the lower packer, the long tubing string is plugged at its lower end below the circulating device, as discussed in detail hereinafter, a pressure differential is applied between the interior of the long tubing string and the casing annulus opening the circulating device, and the desired circulation procedure is carried out within the well bore above the expanded lower packer. The upper packer is then expanded and the circulating device is closed by movement of the lower section 22' of the short tubing string relative to the long tubing string 21.

The circulating device 20, shown in detail in FIGURES 4, 5, and 6, includes telescopically coupled lower and

upper sleeve valves

50 and 51 which are slidable both on the flow conductor 21 and relative to each other. The sleeve valves serve as a closure over ports 21a of the long tubing string, as described in detail below. The sleeve valve 50 has a lower thick walled portion 50a which is initially disposed over the ports 21a and supports an internal ring seal 53 to seal between the sleeve valve and the outer surface of the tubing string section 21 below the ports. The bore of the sleeve valve 50 is enlarged providing an intermediate portion 50b of reduced wall thickness and is further enlarged along an upper end portion 50c of still further reduced wall thickness. The upper sleeve valve 51 has a lower end portion 51a of reduced wall thickness so that the portion 51a may be telescoped into the lower sleeve valve above its lower end portion I 50a, as best seen in FIGURE 5. The upper sleeve valve has an external ring seal 54 which seals between the intermediate portion 50b of the lower sleeve valve and the portion 511: of the upper sleeve valve.

Due to the sliding fit between the lower sleeve valve and both the tubing string section 21 and the reduced lower end portion 51a of the upper sleeve valve pressure within the tubing string is communicated from the ports 21a downwardly within the lower sleeve valve portion 50a along the tubing string outer surface to the line of sealing engagement between the ring seal 53 and the tubing string surface. Similarly, the pressure is communicated from the ports upwardly within the intermediate portion 50b of the lower sleeve valve along the upper sleeve valve portion 51a to the line of sealing engagement between the ring seal 54 and the internal surface of the lower sleeve valve. Thus, the pressure within the tubing string acts on upwardly facing surface portions of the lower sleeve valve over an effective annular area thereof between the lines of sealing engagement of the

ring seals

53 and 54 with the tubing string and lower sleeve valve, respectively, biasing the lower sleeve valve downwardly toward an open position with respect to the ports 21a. Similarly, of course, the pressure exterior of the tubing string exerts an upward force on the lower sleeve since the area of the downwardly facing surfaces of the lower sleeve valve exposed to the external pressure is greater than the area of its upwardly facing surfaces exposed to the external pressure and biases the lower sleeve valve upwardly. The lower sleeve valve is releasably secured to the upper sleeve valve by a pair of shear pins 55. At the initial closed position of the circulating device illustrated in FIGURES 4 and 5 fluid pressure transmission upwardly between the tubing string and the sleeve valves from the ports 21a is limited by a pair of internal lower ring seals 60 supported within the lower end portion of the upper sleeve valve.

A pair of upper internal ring seals 61 are disposed within the sleeve valve 51 spaced from its ring seals 60 so that when the upper sleeve valve is moved downwardly to close the ports 210, the ring seals 60 are then positioned below the ports and the ring seals 61 above the ports.

The upper sleeve valve 51 has a reduced upper portion 51b threaded into a dual collar type operator member 62 slidably disposed on the long tubing section 21' and secured to the short tubing section 22'. The collar 62 is locked on the short tubing string section 22' by upper and lower lock rings 63 on a threaded portion 22a of the tubing string section. Longitudinal movement of the short tubing string section 22' relative to the long tubing string moves the operator member on the long tu'bing string shifting the sleeve valve 51 along the tubing string.

The sections of the long and short tubing strings on which the circulating device is supported are each relatively short special tubing sections included in strings of standard tubing making up both the long and short tubing strings. The long tubing string section 21' is provided with the ports 21a and is coupled into the long tubing string below the upper packer by the coupling collars 21" which are in turn connected with conventional tubing sections 21" which make up the remainder of the long tubing string both below and above the upper packer. Similarly, the short tubing string section 22 is a special section adapted to be secured through the operator member 62 and connected with conventional tubing sections 22" which make up the remainder of the short tubing string above and below the upper packer. The short tubing section 22 has an enlarged upper box section 22b which is threaded on the lower end ofthe tubing section 22" above the circulating device. The tubing section 22 is also provided at its lower end with a coupling 220 into which is threaded a male coupling 22d from which additional tubing sections may be supported, if desired.

The lower end of the short tubing string 22 is provided with a ring shaped ball seat 70 secured by shear pins 71 within the tubing string which is engageable by a plugging ball 72, FIGURE 3, to close the lower end of the short tubing string for setting the upper packer and closing the circulating device 20. Similarly, the long tubing strin is provided with a ring shaped ball seat 74 below the circulating device secured within the tubing string by shear pins 75 which is engageable by a ball for closing the long tubing string.

The lower packer 23 is any suitable, single, standard well packer which seals between the long tubing string 21 and the well casing 25 below the circulating device. Several packers suitable for the purpose are the Otis Perma-Trieve Production Packers illustrated at pages 3790-3791 of the 1966-67 edition, Composite Catalogue of Oil Field Services and Equipment, published by World Oil, Houston, Tex. Similarly, the upper packer 24 may be any suitable packer for sealing around at least two tubing strings with one of the tubing strings being movable relative to the other to effect the desired operation of the circulating device 20. For example, a suitable packer, illustrated diagrammatically in FIGURES 2A and 3A, is shown at pages 3810-3811, Composite Catalogue of Oil Field Services and Equipment, supra, and also is shown in United States Patent No. 3,288,218, issued to C. R. Young, Nov. 29, 1966.

Referring to FIGURES 2A and 3A, the upper packer 24 includes a head having a pair of

passages

91 and 92 which constitute upper end portions of

passages

92 and 93, respectively, through the packer. A long mandrel 94 is rigidly secured to the head in communication with the passage 91 and a short mandrel 95 is movably secured to the head in communication with the second passage 92. The bores or longitudinal passages of the

mandrels

94 and 95 constitute lower portions of the

passages

92 and 93, respectively. The lower end of the portion of the long tubing string 21 above the packer is receivable in the passage 91 and the lower end of the portion of the short tubing string above the packer is receivable in the passage 92 of the packer head. The

packer also includes a hold-down body secured to the short mandrel 95 and having a pair of

parallel passages

101 and 102, the long mandrel 94 extending through the passage 101 while a dependent tubular section 90a of the head 90 is telescoped into the upper end of the passage 102. A plurality of resilient packing elements 103 disposed about the mandrels are compressed and expanded laterally to seal between the mandrels and the well casing by a downward movement of the hold-down body 100 on the long mandrel. The packing elements are disposed between the downwardly facing shoulder or surface 104 of the hold-down body and an upwardly facing shoulder 105 of an expander 110 disposed around both the long and short mandrels. The packing elements are expanded when downward movement of the expander on the long mandrel which extends through the expander is arrested after the expander has moved a plurality of locking slips 111 outwardly to expanded positions at which the locking slips engage the well casing. The locking slips 111 are mounted on a slip carrier 112 releasably held against downward movement on the

mandrels

94 and 95 disposed through parallel passages of the slip carrier which is held against downward movement by a latch or holding assembly 113. The latch assembly includes a cylinder 114 releasably secured to the long mandrel by a shear pin 115. The

mandrels

94 and 95 extend through parallel passages of the cylinder to its downwardly opening bore 120. A piston 121 is disposed in the cylinder on the mandrels and with the cylinder defines a chamber 122 into which fluid pressure from the short mandrel is communicated by lateral ports 123 therein. The piston is held against downward movement relative to the dependent section 22" by engagement with a stop shoulder 124 of an enlarged upper end portion of a dependent section 22" of the short tubing string 22 secured to the short mandrel 95 and extending downwardly from the packer. The cylinder has a latch assembly 124a engageable with the short mandrel which permits downward movement of the short mandrel relative to the cylinder but prevents its upward movement thereto. The holddown body 100 is releasably held in the upper position on the long mandrel illustrated in FIGURE 2A by a shear pin 125 and is provided with hold-down buttons 130 which are movable outwardly to engage the well casing and prevent upward movement of the hold-down body in the casing by fluid pressure from below the resilient packing elements communicated to the hold-down buttons by fluid passages which extend through the hold-down body, the packing elements, and the expander, when the pressure below the expanded packing elements exceeds the pressure there-above by a predetermined value. Further, the downward movement of the short mandrel 95 during the setting of the packer lowers the short tubing string sections below the packer supported from the short mandrel shifting the sleeve valve 51 to its closed position, FIGURES 3 and 4. Further structural details of the upper packer 24 are illustrated and described in US. Patent No. 3,288,218, supra.

In use, the single string lower packer 23 is set in the casing 25 between the lower perforations 26 and upper perforations 27 in any suitable conventional manner. The circulating device 20 along with the lower sections of the long and short tubing strings associated with it below the upper packer are connected with the

mandrels

94 and 95 of the upper packer in the relationship illustrated in FIGURES 2A and 4 with the lower sleeve 50 locked by shear pins 55 to the upper sleeve valve. The lower sleeve 50 is over the ports 21a closing the circulating device. The upper packer is supported on the sections of the long tubing string 21 above the packer, the lower end portion of the lowermost of such sections being releasably secured into the first passageway 91 of the head 90. The upper packer with the circulating device supported therefrom is lowered through the well casing until the lower end portion of the long string 21 below the circulating device is inserted into and landed in the lower packer 23. The upper portion of the short tubing string 22 is then lowered into the well bore until its lower end portion is seated in and releasably secured in the flow passage 92. The well head is installed on the casing and the

flow conductors

31, 33, and 35 are connected to the flow conductors and the well head.

The lower ends of the long and short tubing strings are open while they are being lowered through the well casing to their final positions within the well bore so that drilling fluid in the well bore rises in the tubing strings as they move downwardly. After the well head is set and the necessary surface connections are made as discussed above, the valve 40 in the conduit 35 to the casing annulus is closed while the

valves

32 and 34 in the conduits leading to the tubing strings are opened so that the desired circulation may be effected through the tubing strings for circulating drilling fluid from the tubing strings and easing annulus praparatory to producing the wells. A plugging ball 82 having a density exceeding that of the well liquids is introduced into the long tubing string 21. The ball sinks downward in the drilling fluid filled tubing string coming to rest at the lower end of the tubing string on the ball seat thereby plugging the tubing string and preventing fluid communication between its interior and the casing annulus below the lower packer 23. The ball seat 80 is shear pinned within the lower end of the long tubing string with pins of greater shear strength than the shear pin 55 of the circulating device and the plugging ball 82 is of a material which prevents its extrusion through the ball seat so that the long tubing string remains plugged throughout and subsequent to the opening of the circulating device. Fluid, generally water, is pumped then through the conduit 33 into the long tubing string building up the pressure within the tubing string since it is plugged at its lower end by the ball until the pressure differential between the interior of the'tubing string at its ports 21a and the casing annulus around the tubing string at the ports is sufiicient to shear the pins 55 and force the lower sleeve valve 50 downwardly to its open position illustrated in FIGURE 2. The pressure within the tubing string is transmitted through the ports 21a along the tubing string and the upper sleeve valve 51 within the lower sleeve valve to the ring seals 53, 54 and 60 biasing the lower sleeve valve downwardly relative to the tubing string and the upper sleeve valve by a force resulting from the pressure acting over an effective upwardly facing annular area defined between the line of sealing engagement of the ring seal 53 with the outer surface of the tubing string on the inside and the line of sealing engagement between the outer ring seal 54 with the inside surface of the intermediate portion 50b of the lower sleeve valve. The pressure around the tubing string acts upwardly on the lower sleeve valve over an effective annular area between the ring seals 53 and 54. The upper sleeve valve 51 is held against upward movement by the operator member 62 which is secured at a fixed position on the tubing string by the lower section 22' of the short tubing string 22. When the pressure differential across the lower sleeve valve exceeds a predetermined value, the pins 55 are sheared releasing the lower sleeve valve for downward movement on the tubing string to a position spaced below the upper sleeve valve. The lower sleeve valve is forced downwardly away from the upper sleeve valve opening the ports 21a, as illustrated in FIGURE 2. During its downward movement, shortly after severance of the shear pins 55, the inner surface of the intermediate portion 50b of the lower sleeve valve passes below the ring seal 54 and the fluid pressure within the tubing string is transmitted outwardly between the lower sleeve valve and the outer surface of the lower end portion of the upper sleeve valve. Since the space between the upper and lower sleeve valves at the time the ring seal 54 ceases to be effective is still relatively small, the pressure drop in the fluid flowing in the annular space between the sleeve valve portions 50b and 51a is sufficient to continue to apply a downward force on the lower sleeve valve to move it on to a fully open position. The distance the lower sleeve valve moves downward on the tubing string depends, of course, upon the conditions under which the valve is opened, including the pressure differential across the valve at the time the pins 55 are sheared. If the pressure differential is particularly high when the pins are sheared, the sleeve valve will generally move rapidly downwardly to fully uncover the ports 21a establishing communication between the interior of the tubing string and its exterior within the casing annulus 41. During the opening of the circulating device, the upper packer remains at the position shown in FIGURE 2A.

As soon as the circulating device is opened, as shown in FIGURE 2, the fluid within the long tubing string is pumped outwardly through the ports 21a into the casing annulus. Since the valve 40 in the conduit 35 leading to the casing annulus is closed while the valve 32 in the conduit 31 from the short tubing string is open and the lower end of the short tubing string below the upper packer is open, circulation is established into the short tubing string so that fluid within the casing annulus flows upwardly in the short tubing string and from the well through the conduit 31 as fluid is forced into the long tubing string at the surface. The circulation through the long tubing string, the casing annulus, and the short tubing string continues until the drilling fluid within the tubing strings has been circulated out of the well bore to the surface leaving the tubing strings substantially filled with the fluid being used to circulate, which, as stated previously, may comprise water. Some of such drilling fluid between the open lower end of the short tubing string and the ports may also be removed in this manner.

After the desired circulation procedure has been completed, the circulating device is closed and the upper packer is set so that the well may be produced. To close the circulating device and set the upper packer the pressure is raised in the short tubing string after the plugging ball 73 is inserted at the surface into the short tubing string and is pumped or allowed to move by gravity downwardly to a seated position, FIGURE 3, on the ball seat 70 at the lower end of the tubing string below the upper packer 24. The fluid pressure in the short tubing string is increased as by pumping into it at the surface through the conduit 31. The increased fluid pressure is communicated through the lateral ports 123 of the short mandrel into the chamber 122 of the upper packer between the cylinder and piston of its latch assembly causing the piston to exert a downward force on the short mandrel. Upward movement of the cylinder is prevented by the shear screw 115 which is of greater strength than the shear screw 125 which secures the hold-down body to the long mandrel 94. The screw 125 shears as the pressure in the chamber is increased and the hold-down body 90 is released for downward movement relative to the head and the long mandrel. The force exerted by the piston on the shoulder surface 124 of the short mandrel moves the hold-down body downwardly relative to the head and the long mandrel. The expander 110 expands the slips 111 until their teeth engage the well casing 25 and further downward movement of the expander is arrested whereupon continued downward movement of the hold-down body compresses and expands the resilient packer elements 103 into sealing engagement with the well casing closing the passage between the well casing and the long and short mandrels. When the packing elements are at their expanded sealing position, pressure in the well casing below the'packing elements is communicated to the internal surfaces of the hold-down buttons 130 and when such pressure is greater by a predetermined value than the pressure above the packing elements the hold-down buttons are moved outwardly to cause their upwardly facing teeth to engage the well casing and limit the hold-down body against upward movement. The greater the pressure below the packing elements the greater the force with which the hold-down buttons are held in engagement with the well casing.

When the piston 121 forces the short mandrel 95 downwardly relative to the long mandrel to expand the packing elements and lock the packer in the well casing, the downward movement of the short mandrel lowers the short tubing string section 22' below the packer relative to the long mandrel 94 which supports the lower end portion of the long tubing string below the packer. The operator member 62 is forced downwardly on the long tubing string moving the upper sleeve valve 51 downwardly on the tubing string. The upper sleeve valve slides over and closes the ports 21a with the lower internal ring seals 60 of the sleeve valve being located below the ports at the lower end of the downward stroke of the short tubing string portion and the operator memher. The lower end portion 51a of the upper sleeve valve 51 may telescope into the lower sleeve valve 50, FIGURE 3, though such relationship with the lower sleeve valve is not essential to closure of the tubing string ports 21a since flow through the ports is prevented by the presence of the ring seals 60 and 61 Within the upper sleeve valve above and below, respectively, the ports. Complete insertion of the lower end portion of the upper sleeve valve into the lower sleeve valve is, of course, dependent on the extent to which the lower sleeve valve was forced downwardly by the fluid pressure differential across it during the opening procedure. If the lower sleeve valve was forced downwardly a greater distance than the stroke of the operator member, obviously the upper sleeve valve will not be fully reinserted into the lower sleeve valve upon closure of the circulating device. The status of the lower sleeve valve is, however, of no consequence since reclosure of the tubing string ports fully effected by the upper sleeve valve.

With the upper sleeve valve 51 fully closed fluid communication is prevented between the casing annulus between the packers and the long tubing string. The operator member 62 is held down by the short tubing string to prevent accidental opening of the upper sleeve valve. Since the lines of sealing engagement of the upper and lower seal rings 61 and 60, respectively, with the outer surface of the long tubing string are of the same diameter and since the entire outer surface portions of the upper sleeve valve above and below its internal seal rings are all exposed to pressure within the casing annulus, the sleeve valve is not movable responsive to either the pressure within the long tubing string or within the easing annulus between the packers. Therefore, any pressure differential which may exist between the casing annulus and the inside of the long tubingstring at the circulating device has no effect upon the closed upper valve sleeve and thus there is no tendency for pressure to reopen the valve.

The plugging ball 73 at the lower end of the short tubing string and the ball 82 at the lower end of the long tubing string are removable from their respective ball seats by either of two procedures, Preferably, the surface flow control devices including. the

valves

32 and 34 are adjusted, after pumping into the

conduits

31 and 33 is terminated, to allow the well to begin to produce through the tubing strings with upward flow of fluids entering the well through the ports 27 being effected through the short tubing string from between the packers and upward flow from below the lower packer entering the well through the ports 26 and flowing upwardly in the long tubing string. The plugging balls in the tubing strings are carried upwardly to the surface by the fluids being produced through the tubing strings. The halls are removed at the surface from each of the tubing strings. Alternatively, the balls 73 and 82 may be displaced outwardly from the lower ends of the tubing strings by increasing the pressure sufficiently within the tubing strings to shear the pins holding each of the ball seat rings within its respective tubing string. For example, the pressure differential across the ball seat and ball 82 is raised to a value sufiicient to apply a downward force to the seat and ball of a value sufiicient to shear the pins 81. Similarly, the pins 71 in the short string are sheared releasing its seat 70 and ball 73. If this latter procedure is followed for removing the plugging balls, both the ball and the ball seat in each of the tubing strings is displaced from the tubing string downwardly into the well bore.

After the plugging balls are removed from the tubing strings, the well is produced through either or both tubing strings with communication through the ports 21a being prevented by the closed circulating device. The circulating device is not adapted to be reopened within the well bore and thus requires removal from the well bore with the upper packer and resetting if repetition of its opening and closing function is desired. The upper packer is removed in accordance with the procedures discussed in detail in U.S. Patent No. 3,288,218 and since such removal is unrelated to the structure and function of the circulating device 20 it is not discussed in detail herein.

It will now be seen that a new and improved well tool for circulation between the interior and exterior of a flow conductor in a well bore has been illustrated and described.

It will be further seen that the circulating device is employed for circulating fluids out of the well bore during the setting of the well packers.

It will also be seen that the circulating device includes a sliding sleeve valve for controlling fluid communication between the interior and exterior of a flow conductor disposed in a well bore.

It will be further seen that the sliding sleeve valve is opened by a fluid pressure differential at the valve between the interior and exterior of the flow conductor within the Well bore.

It will be further seen that the sleeve is closed by a mechanical force applied from a second flow conductor disposed within the well bore and movable relative to the flow conductor on which the sleeve is supported.

It will be further seen that the sleeve valve includes first and second sleeve members telescopically related and slidable along the flow conductor, the sleeve valve members initially closing a port in the flow conductor and one of the sleeve valve members being movable by a fluid pressure differential between the interior and exterior of the conductor to an open position and the second sleeve valve member being movable thereafter to a closed position to close the port by a mechanical force, the second sleeve valve member being held in such closed position by an operator member employed to apply the closing mechanical force to the sleeve valve.

It will be further seen that a well system has been described and illustrated including a first long flow conductor, a second short flow conductor, an upper packer for sealing between the flow conductors and a well bore wall, a lower packer for sealing between the long flow conductor below the lower end of the short flow conductor, the short conductor having a portion below the upper packer movable relative to the long flow conductor, and valve means disposed about the long flow conductor movable to an open position by a fluid pressure diflerential between the interior of the long flow conductor and the well bore and returnable to a closed position by an operator member coupling the valve and the movable short flow conductor portion below the upper packer.

It will be further seen that the telescopically related sleeve valve members include a lower member provided with an inner ring seal sealing between the valve member and the tubing string and an outer ring seal sealing between the valve member and the second sleeve valve member defining an annular area on the first sleeve valve member which when in closed position over the tubing string port is exposed on the inside to the pressure within the tubing string and on the outside to the pressure within the well bore around the tubing string whereby a greater pressure within the tubing string biases the sleeve valve member toward an open position relative to the tubing string port.

Another form of circulating device embodying the invention is illustrated in FIGURE 7 at its initial closed position. The circulating device 140 includes a sleeve valve 141 slidably supported on a long tubing string section 211; which is supported from the long mandrel 94 of the upper packer 24 and is threaded at its lower end into a coupling 210 connected with a coupling collar 21" which in turn is connected with another long tubing string portion, not shown, which extends downwardly into the lower packer 23. The tubing string section 21b has ports 21d for communication between the interior of the long tubing string and the well bore between the upper and lower packers and which are open and closed by the sleeve valve 141.

The sleeve valve 141 is slidably disposed on the long tubing string section 21b for longitudinal movement thereon to open and close the ports 21d. The sleeve valve is initially releasably secured at a closed position by a shear pin 142 extending through the sleeve valve into a shallow blind recess 143 in the outer surface of the tubing section 21b. The sleeve valve has a head section 144 and a lower skirt portion 145. The valve has an upper bore portion a extending through its head portion 144 of a diameter to provide a sliding relationship on the tubing section 21b and a coaxial lower enlarged bore portion 15% extending through its skirt portion 145. A pair of seal rings 151 are disposed within the head section of the sleeve valve to seal between the valve and the outer surface of the tubing section 21b. \An annular flexible seal 152 is disposed around the tubing string portion 21b below the ports 21d between a pair of retainer rings 153. The downward movement of the seal 152 and its retainer rings is limited by the upper end surface 154 of the coupling 21c and their upward movement is limited by a split retainer ring 155 disposed in an external annular recess of the tubing section 21b below its ports 21d. The seal 152 seals between the inner surface of the skirt portion 145 of the sleeve valve and the long tubing string section below its ports 21d so that when the sleeve valve is at its closed position fluid may not flow downwardly from the ports 21d due to the presence of the seal 152 and similarly may not flow upwardly between the sleeve valve and the tubing string section because of the seal rings 151.

The sleeve valve 141 is exposed to pressure transmitted from within the long tubing string through its ports 21d over surface portions having an effective net downwardly facing annular area defined between the line of sealing engagement of the annular seal 152 with the inner wall surface of the skirt portion 145 of the sleeve valve and the line of sealing engagement between the ring seals 151 with the outer wall surface of the tubing string section 21b. The pressure within the tubing string acting over this annular area of the sleeve valve biases the valve upwardly toward open position on the tubing string section. The sleeve valve is similarly exposed to pressure within the well bore between the packers around the tubing string section so that the casing annulus pressure tends to bias the sleeve valve downwardly toward its closed position.

An external annular flange 161 is formed on the tubing coupling 21c providing an upwardly facing annular stop shoulder 161a located to limit the downward movement of the sleeve valve 141 during its closure to a position at which the lowermost of the ring seals 151 is located above the ports 21d so that when the sleeve valve is closed its internal ring seals are above the ports 21d. An operator member collar 162 is disposed around the long tubing string 21b above the sleeve valve 141 and secured to the short tubing string section 220. The sleeve valve is closed by moving the operator member down by the short tubing string section to engage the upper end surface 144a of the sleeve valve.

A well system in which the alternate form 140 of the circulating device is used is identical to the system disclosed in FIGURES 1-3 and is operated in exactly the same manner as described above. When the lower packer has been set, the upper packer along with the tubing strings positioned in the well and the well head connected, a plugging ball '82 is inserted into the long tubing string and pressure is applied within it by pumping fluid into it at the well head. A pressure differential is developed across the sleeve valve 141 between the interior of the tubing string section 21b and the casing annulus between the packers. When the pressure in the long tubing string is raised to a predetermined valve above the casing annulus pressure the pin 142 is sheared releasing the sleeve valve for movement on the tubing string section. The force of the pressure differential applied to the effective downwardly facing surface portions defined between the ring seals 151 and the annular seal 152 forces the sleeve valve upwardly on the tubing section to a position at which the lower end of the skirt portion 145 of the sleeve valve sufficiently clears and is spaced above the seal 152 to allow the desired fluid flow from within the long tubing string outwardly into the casing annulus. Generally, the pressure differential required to shear the pin 142 is sufficient to force the sleeve valve upwardly to the desired open position on the tubing string section to uncover the ports 21d enough to allow the desired circulation between the tubing and the casing annulus. The exact position of the sleeve valve at the upper end of its stroke on the tubing string will obviously depend upon the pressure differential applied across the valve for moving it to its open position.

These procedures described in connection with the circulating device 20 are followed with the circulating device 140 through and including the setting of the upper packer 24 by increasing the pressure within the short tubing string as previously discussed. The downward movement of the short mandrel of the upper packer during its setting forces the operator member 162 downwardly on the long tubing string section 21d so that the operator member engages the upper end surface 144a of the sleeve valve 141 forcing it back downwardly on the tubing string section to its closed position over the ports 21d. Generally the sleeve valve is returned substantially to the position shown in FIGURE 7. As soon as the internal surface of the skirt portion 145 of the sleeve valve moves over the annular seal 152 the ports 21d are effectively again closed with the operator member 162 bearing against the upper end of the sleeve valve holding it at its closed position.

In contrast with the circulating device 20, the sleeve valve 141 does have a tendency to move to the open position at any time the pressure within the long tubing string exceeds the pressure within the casing annulus between the packers and thus it is essential that the operator member 162 remain engaged with the upper end of the sleeve valve to hold it at the closed position. Obviously, any pressure within the casing annulus exceeding the pressure within the long tubing string between the packers acts over the effective upwardly facing annular surface portions of the sleeve valve defined by the upper ring seals 151 and the annular seal 152 tending to force the sleeve valve to a more tightly closed position.

After the sleeve valve 141 is returned to and held at its closed position by the operator member 162, the well is placed in production in the same manner as described above.

It will now be seen that a further alternate form of a a circulating device embodying the invention has been described and illustrated, including a sleeve valve slidably supported on a long flow conductor of a well system for movement between positions opening and closing a lateral port in the flow conductor and having inner and outer seal means for sealing between the flow conductor and the sleeve valve above and below the port and defining an annular area exposed to the pressure within the flow conductor biasing the valve toward an open position and an effective annular area of outer surface portions exposed to the pressure within the casing annulus biasing the valve toward a closed position, the valve being releasably secured at a closed position initially by shearable means and being opened by a pressure differential between the interior flow conductor and the pressure around its exterior and closed by an operator member on the long flow conductor above the valve and coupled with and moved by a short flow conductor disposed within the well adjacent to the long flow conductor.

The circulating

devices

20 and 141, as illustrated, are generally used in well systems where the upper and lower packers are reasonably close together within the well bore, spaced apart, for example, no greater than about 200 feet. An alternate form of the circulating device A is illustrated in FIGURE 8 for use in systems where operating requirements necessitate a substantially greater distance between the upper, and lower packers and the long string circulating ports are located near the lower packer with the open end of the short tubing string section being near the upper packer. The circulating device 140A is identical in all respects to the device 140 except that it includes an extension sleeve slidably disposed around the long string tubing section 21b supported from the operator member 162 for applying a downward force from the operator member to the sleeve valve 141 to close the sleeve valve. The extension sleeve 165 spans the substantial distance between the operator member and the sleeve valve when the upper and lower packers are spaced apart a larger distance than practical for use of the previously described circulating devices. Of course, the extension sleeve 165 of the operator member is lowered as the short mandrel of the upper packer is lowered during the setting of the upper packer to effect closing of the sleeve valve 141. The circulating device 140A is operated exactly as the previously discussed circulating devices.

It will now be seen that a further alternate form of circulating device for use in a well bore between packers has been described and illustrated including an extension sleeve between the operator member of the circulating device extending downwardly to its sliding sleeve valve for closing the valve when well requirements necessitate a substantial distance between the upper and lower pockers.

The foregoing description of the invention is explanatory only, and changes in the details of the construction illustrated may be made by those skilled in the art, within the scope of the appended claims, without departing from the spirit of the invention.

What is claimed and desired to be secured by Letters Patent is:

1. A well tool comprising: a flow conductor adapted to be disposed in a well bore, said flow conductor having a port for fluid communication between the interior and exterior of said flow conductor; tubular valve means slidable longitudinally on said flow conductor for closing and opening said port; fluid pressure means for operating said valve means to open said port by fluid pressure from within said flow conductor in excess of the pressure exteriorly thereof; and means slidable longitudinally on said flow conductor for operating said valve means to close said port.

2. A well tool as defined in claim 1 wherein said means for closing said port is operable responsive to a mechanical force.

3. A well tool as defined in claim 2 wherein a second flow conductor is adapted to be disposed in said well bore and said means for closing said port is connected with and responsive to movement of said second flow conductor for movement relative to said first mentioned flow conductor to close said port.

4. A well tool as defined in claim 1 wherein said tubular valve means comprises sleeve means slidable on said flow conductor; and said means for opening and closing said port comprises an operator member slidable on said flow conductor and operable by another flow conductor movable longitudinally relative to said first mentioned flow conductor.

5. A well tool as defined in claim 4, wherein said sleeve means comprises a sleeve movable from a first closed position over said port to a second open position permitting communication between the interior and exterior of said fiow conductor through said port and back to said first closed position.

6. A well tool as defined in claim 1, wherein said means for operating said valve means to close said port includes an operator member movable on said flow conductor for engaging and moving said sleeve from said open position back to said closed position.

7. A well tool as defined in claim 6 wherein said operator member is coupled to and movable by another flow conductor movable relative to said first mentioned flow conductor.

8. A well tool comprising: a flow conductor adapted to be disposed in a well bore, said flow conductor having a port for fluid communication between the interior and exterior of said flow conductor; sleeve means slidable on said flow conductor for closing and opening said port, said sleeve means including: telescopically disposed first and second sleeve valves, said first sleeve valve being movable from said position covering said port to said position uncovering said port responsive to a pressure differential across said sleeve valve between the interior and exterior of said flow conductor, said second sleeve valve being movable to a position covering said port responsive to a mechanical force applied thereto.

9. A well tool as defined in claim 8 including an operator member movable on said flow conductor for engaging and moving said second sleeve over said port.

10-. A well tool as defined in claim 9 wherein said operator member is coupled to another flow conductor disposed in said well bore and adapted to move longitudinally relative to said first mentioned flow conductor.

11. A well tool for circulating fluid between the interior and exterior of a fiow conductor comprising: a flow conductor adapted to be disposed in a Well bore, said flow conductor having a port spaced from the end thereof for communication between the interior and exterior of said flow conductor; a valve on said flow conductor for covering and uncovering said port, said valre including a slidable sleeve on said flow conductor; first inner seal means for sealing between said sleeve and said flow conductor; second outer seal means for sealing between said sleeve and said flow conductor; said first and second seal means defining an annular area of said sleeve exposed on one side to pressure within said flow conductor and on the opposite side to pressure outside of said flow conductor, said sleeve being movable to a position uncovering said port responsive to a pressure differential between the interior and exterior of said flow conductor from within said flow conductor greater than the pressure on the exterior of said sleeve acting across said annular area of said sleeve; and mechanical means movable longitudinally of said conductor to engage said sleeve for actuating said valve to cover said port in said flow conductor.

12. A well tool as defined in claim 11 including means for releasably locking said sleeve on said conductor at a position covering said port, an operator member slidable along said flow conductor for moving said sleeve from said position uncovering said port back to said position covering said port, said operator member being coupled with another flow conductor disposed in said well bore and movable relative to said first mentioned flow conductor, and stop means on said first mentioned flow conductor to limit the return movement of said sleeve to said position covering said port.

13. A well tool as defined in claim 12 including means for temporarily closing said first mentioned flow conductor below said port for applying said pressure ditferential across said annular area for moving said slidable sleeve to said position uncovering said port.

14. The well tool of claim 13 in combination with first packing means on said first mentioned flow conductor below said port in said first mentioned flow conductor for sealing between said conductor and a well bore Wall and second packing means on said first and second mentioned fiow conductors above said port in said first mentioned flow conductor for sealing between said flow conductor and a wall of a well bore, said second packing means being adapted for movement of said second mentioned flow conductor relative to said first mentioned flow conductor for returning said sleeve to said position cover in g said port.

15. A well tool for circulating fluid between a well bore and a flow conductor disposed therein comprising: a first flow conductor adapted to be disposed within a well bore, said first flow conductor having a port spaced from the lower end thereof; a first sleeve valve movably supported on said first flow conductor for closing said port at a first position and for opening said port at a second position; a second sleeve valve movably supported on said first flow conductor telescopically related with said first sleeve valve for movement to a position closing said port after said first sleeve valve is moved to said position opening said port; inner seal means between said first sleeve valve and said first flow conductor; outer seal means between said first sleeve valve and said second sleeve valve; said inner and outer seal means defining an annular area of said first sleeve valve exposed on one side to pressure within said first flow conductor and on the other side to pressure exterior of said flow conductor whereby a greater pressure within said conductor biases said first sleeve valve toward said position opening said port; seal means between said first flow conductor and said second sleeve valve positioned on a side of said port opposite said inner seal means between said first sleeve valve and said first flow conductor when said first sleeve valve is closing said port and spanning said port for sealing between said second sleeve valve and said flow conductor on opposite sides of said port when said second sleeve valve is closing port; means between said first and second sleeve valves for holding said first sleeve valve over said port when the pressure difierential across said annular area is below a predetermined value; and operator means for moving said second sleeve valve to a position over and closing said port in said How conductor.

16. A well tool as defined in claim 15 including a second flow conductor adapted to be disposed in said well bore for movement relative to said first fiow conductor and means coupling said operator means with said second flow conductor whereby said second sleeve valve is moved along said first flow conductor to said position closing said port in said first flow conductor responsive to movement of said second fiow conductor relative to said first flow conductor.

17. A well tool as defined in claim 16 including means for temporarily closing said first flow conductor below said port therein for developing a pressure within said first flow conductor to apply said pressure diflerential across said annular area of said first sleeve valve for moving said valve to open said port in said first flow conductor.

18. The well tool of claim 17 in combination with a first well packer on said first fiow conductor below said port therein and a second well packer on said first and second flow conductors above said port in said first flow conductor, said second well packer including means for moving said second fiow conductor relative to said first flow conductor for movement of said second sleeve valve to close said port.

19. Circulation means for a well installation having a first long fiow conductor and a second short flow conductor extending in parallel relation in a well, an upper packer for sealing between said fiow conductors and the well and a second packer for sealing between said long flow conductor and the well below the bottom end of said short flow conductor and wherein said short flow conductor has a lower section extending below said upper packer movable downwardly relative to said long flow conductor during the setting of said first packer, said circulation means including: means providing a port in said long flow conductor between said packers for providing communication between said long fiow conductor and the well between said packers; valve means disposed about said first flow conductor and releasably secured thereto in closed position wherein said valve means closes said port, said valve means having means responsive to fiuid pressure in said long flow conductor, the fluid pressure in said flow conductor exerting a force tending to move said valve means to open position, said valve means being movable thereon from said closed position to an open position when the pressure differential between said long flow conductor and the well between said packers exceeds a predetermined value to permit circulation through said port between the well and said long flow conductor before said second flow conductor is set; and co-engageable means on said valve means and said section of said short flow conductor for moving said valve means from open to closed position on said first fiow conductor upon downward movement of said section of said second flow conductor during the setting of said upper packer and for holding said valve means thereafter in closed position.

20. The circulation means of claim 19, and means for closing said long fiow conductor below said port whereby the pressure in said long flow conductor may be increased to cause said valve means to move to open position and permit circulation of fluids down one of said flow conductors into the well between said packer and upwardly from the well between said packers through the other of said flow conductor.

21. A well tool comprising: housing means having means for connecting said housing means to a first flow conductor, said housing means having an opening for receiving tubular conductor means; a tubular conductor means longitudinally slidably disposed in said housing means opening and having means for connecting it to a second flow conductor; said tubular conductor means having port means providing communication between the interior and exterior thereof; one of said tubular conductor means and said housing means being movable longitudinally relative to the other for shifting the relative position of said port means with respect to said housing means; and seal means spaced longitudinally with respect to said housing means disposed for sealing on longitudinally opposite sides of said port means between said tubular conductor means and said housing means when said tubular conductor means is disposed longitudinally with respect to said housing means in a first position with said port means within said housing means whereby flow communication through said port means is closed ofi, said tubular conductor means and said housing means being movable longitudinally relative to each other to a second position in which said port means is disposed to permit flow communication through said port means between the interior and exterior of said tubular conductor means.

22. A well tool comprising: housing means having means for connecting said housing means to a first flow conductor, said housing means having an opening spaced laterally from said means for connecting said housing means to said first flow conductor; a tubular conductor means longitudinally slidably disposed in said housing means opening and having means for connecting it to a second flow conductor; said tubular conductor means having port means providing communication between the interior and exterior thereof; one of said tubular conductor means and said housing means being movable longitudinally relative to the other for shifting the relative position of said port means with respect to said housing means; and seal means spaced longitudinally with respect to said housing means disposed for sealing on longitudinally opposite sides of said port means between said tubular conductor means and said housing means when said tubular conductor means is disposed longitudinally with respect to said housing means in a first position with said port means within said housing means whereby flow communication through said port means is closed ofi, said tubular conductor means and said housing means being movable longitudinally relative to each other to a second position in which said port means is disposed to permit fiow communication through said port means between the interior and exterior of said tubular conductor means.

23. A well tool comprising: a first flow conductor having port means for communication between the interior and exterior thereof; housing means supported on said first flow conductor; one of said first flow conductor and said housing means being movable relative to the other between relative positions at which said port means is within said housing means and said port means is disposed longitudinally from said housing means; said housing means having means for connecting a second flow conductor thereto; and longitudinally spaced seal means for sealing between said housing means and said first flow conductor, said seal means being on longitudinally opposite sides of said port means when said port means is within said housing means for closing ofi? flow communication through said port means.

References Cited UNITED STATES PATENTS 2,667,926 2/ 1954 Alexander 166224 3,193,016 7/1965 Knox 166224 3,319,717 5/1967 Chenoweth 166224 3,358,770 12/1967 Zandmer 166224 JAMES A. LEPPINK, Primary Examiner US. Cl. X.R.