US20090301732A1 - Downhole Valve Actuation Methods and Apparatus - Google Patents
Downhole Valve Actuation Methods and Apparatus Download PDFInfo
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- US20090301732A1 US20090301732A1 US12/477,308 US47730809A US2009301732A1 US 20090301732 A1 US20090301732 A1 US 20090301732A1 US 47730809 A US47730809 A US 47730809A US 2009301732 A1 US2009301732 A1 US 2009301732A1
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- shiftable
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- 238000000034 method Methods 0.000 title claims abstract description 42
- 238000004519 manufacturing process Methods 0.000 claims description 31
- 239000012530 fluid Substances 0.000 claims description 13
- 230000008878 coupling Effects 0.000 claims description 7
- 238000010168 coupling process Methods 0.000 claims description 7
- 238000005859 coupling reaction Methods 0.000 claims description 7
- 238000004873 anchoring Methods 0.000 claims 1
- 230000005611 electricity Effects 0.000 claims 1
- 230000008901 benefit Effects 0.000 description 6
- 230000008569 process Effects 0.000 description 4
- 238000011084 recovery Methods 0.000 description 3
- 239000004215 Carbon black (E152) Substances 0.000 description 2
- 230000009471 action Effects 0.000 description 2
- 229930195733 hydrocarbon Natural products 0.000 description 2
- 150000002430 hydrocarbons Chemical class 0.000 description 2
- 238000003780 insertion Methods 0.000 description 2
- 230000037431 insertion Effects 0.000 description 2
- 238000002955 isolation Methods 0.000 description 2
- 238000012986 modification Methods 0.000 description 2
- 230000004048 modification Effects 0.000 description 2
- 238000004891 communication Methods 0.000 description 1
- 238000010276 construction Methods 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
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Classifications
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B23/00—Apparatus for displacing, setting, locking, releasing, or removing tools, packers or the like in the boreholes or wells
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B23/00—Apparatus for displacing, setting, locking, releasing, or removing tools, packers or the like in the boreholes or wells
- E21B23/04—Apparatus for displacing, setting, locking, releasing, or removing tools, packers or the like in the boreholes or wells operated by fluid means, e.g. actuated by explosion
Abstract
Description
- This application claims priority to U.S. provisional patent application Ser. No. 61/058,908 filed Jun. 4, 2008, entitled “Remote Hydraulic Shifting Apparatus, Systems and Methods”, which is hereby incorporated by reference herein in its entirety.
- The present disclosure relates generally to downhole valves and other devices that are movable between positions and, more particularly, to selectively remotely shifting such valves or other devices.
- In hydrocarbon recovery operations in subterranean wells, it is often desirable to selectively shift a valve or other device between positions. For example, there are instances when it is necessary or desirable to selectively close a downhole device to isolate the well, such as to remove, repair or replace equipment. Likewise, there are occasions when it is necessary to shift open the downhole device, such as to allow the recovery of produced fluids.
- In many applications, it may be particularly useful to be able to selectively remotely shift a valve or other device between positions on multiple occasions. For example, in hydrocarbon producing wells having a generally low bottom-hole pressure, an electric submersible pump is often inserted into the well to assist in drawing produced fluids up into the production tubing. However, these pumps typically have a limited useful life-span as compared to the producing life of the well, so operations must be interrupted to replace the pump. In such instances, it is often desirable to isolate the well below the pump by closing one or more valves during removal and replacement of the pump, and thereafter to re-open the valve(s) and continue production.
- Some present techniques for selectively shifting downhole devices require the insertion into the well of a shifting tool carried on pipe, coiled tubing or the like to mechanically shift the valve between positions. This process, which often requires the use of a rig or other equipment, may be time consuming and costly.
- It should be understood that the above-described discussion is provided for illustrative purposes only and is not intended to limit the scope or subject matter of the appended claims or those of any related patent application or patent. Thus, none of the appended claims or claims of any related patent application or patent should be limited by the above discussion or required to address, include or exclude all or any of the above-cited examples, features and/or disadvantages merely because of their mention above.
- Accordingly, there exists a need for improved systems, apparatus and methods capable of shifting a valve or other device disposed in a subterranean well and having one or more of the attributes, capabilities or features described below or in the subsequent sections of this disclosure, or shown in the appended drawings: may be remotely actuated from the surface with hydraulic pressure; may be remotely actuated from the surface with pneumatic pressure; may be remotely actuated from the surface by electric power; may be capable of both opening and closing the shiftable device multiple times as desired; may be capable of selectively repeatedly shifting the shiftable device between at least two positions; may be connected to a production tubing and releasably engageable with the shiftable device; is not part of the lower completion assembly or components; may be disengaged from the shiftable device, removed from the well, reinserted into the well and re-engaged with the device multiple times; may be capable of shifting the shiftable device without requiring the insertion or manipulation of pipe or coiled tubing in the well, or the use of a rig, wet connect or slick line; allows well zone isolation for quickly replacing, adding, removing or servicing equipment or other operations; does not require the engagement of control lines to the shiftable device; may be useful to quickly open and close off the well at will and repeatedly; is easily engageable and disengageable with the shiftable device; is slideably engageable with the shiftable device; allows the well to be sealed before starting operations; or a combination thereof.
- In some embodiments, the present disclosure involves methods of shifting a shiftable device between at least first and second positions with a removable actuator. The shiftable device is anchored within a subterranean well. The actuator is inserted into the well and releasably engaged with the shiftable device. When the shiftable device is in a first position, the actuator may be actuated by providing at least one among hydraulic pressure, pneumatic pressure and electric power thereto to shift the shiftable device into a second position without requiring the use of either a rig or a slick line. The actuator may be disengaged from the shiftable device.
- In various embodiments, the present disclosure involves methods of shifting a shiftable device between at least first and second positions with an actuator. The shiftable device is anchored within a subterranean well. These embodiments include coupling the actuator to a production tubing. After the shiftable member is anchored in the well, the production tubing is inserted into the well and the actuator is slideably engaged with the shiftable device. Whenever and as many times as desired, the actuator may be actuated by providing at least one among hydraulic pressure, pneumatic pressure and electric power to the actuator to shift the shiftable device between positions without requiring the use of either a rig or a slick line.
- There are embodiments of the present disclosure that involve a method of remotely shifting a downhole valve between open and closed positions with a hydraulic valve actuator. These embodiments include inserting the valve actuator into the well and engaging the valve actuator with the valve (in a closed position). Thereafter and whenever the valve is in a closed position, the valve actuator may be hydraulically actuated to shift the valve into an open position. Likewise, when the valve is in an open position, the valve actuator may be hydraulically actuated to shift the valve into a closed position.
- In accordance with the present disclosure, some embodiments involve an apparatus useful for shifting a shiftable device between at least first and second positions. The shiftable device is anchored in a subterranean well. The apparatus includes a housing insertable into and out of the well without disturbing the location of the shiftable device within the well. A hydraulically-driven piston is disposed within the housing. At least two hydraulic control lines are fluidly coupled to the housing and capable of providing hydraulic pressure from the surface to the housing to cause the piston to move up and down within the housing. An engagement arm extends from the piston and is releasably engageable with the shiftable device. The engagement arm moves up and down with the piston and is capable of mechanically shifting the shiftable device between at least first and second positions without requiring the use of either a rig or a slick line. The piston and engagement arm may thus be hydraulically-actuated to selectively remotely shift the shiftable member between positions.
- Accordingly, the present disclosure includes features and advantages which are believed to enable it to advance downhole device shifting technology. Characteristics and potential advantages of the present disclosure described above and additional potential features and benefits will be readily apparent to those skilled in the art upon consideration of the following detailed description of various embodiments and referring to the accompanying drawings.
- The following figures are part of the present specification, included to demonstrate certain aspects of various embodiments of this disclosure and referenced in the detailed description herein:
-
FIG. 1 is a partial schematic and partial cross-sectional view of an embodiment of a valve actuator useful for shifting an example valve disposed in a subterranean well in accordance with an embodiment of the present disclosure; -
FIG. 2 is a cross-sectional view of a portion of an example shifter of an embodiment of a valve actuator in accordance with the present disclosure; -
FIG. 3A is a partial cross-sectional view of a portion of the valve actuator ofFIG. 1 shown with the example valve in a closed position; -
FIG. 3B is a partial cross-sectional view of a portion of the valve actuator ofFIG. 1 shown with the example valve in an open position; -
FIG. 3C is a partial cross-sectional view of a portion of the valve actuator ofFIG. 1 shown with the example valve in a closed position; -
FIG. 3D is a partial cross-sectional view of a portion of the valve actuator ofFIG. 1 shown releasing from the exemplary valve in a closed position; -
FIG. 4A is a partial schematic and partial cross-sectional view of another embodiment of a valve actuator useful for shifting an example sleeve disposed in a subterranean well in accordance with an embodiment of the present disclosure; -
FIG. 4B a partial schematic and partial cross-sectional view of the exemplary valve actuator ofFIG. 4A shown shifting the illustrated sleeve into a closed position; -
FIG. 5A is a partial perspective and partial cross-sectional view of a portion of another embodiment of a valve actuator having an exemplary engagement arm shifting an example sliding sleeve into an open position in accordance with the present invention; -
FIG. 5B shows the exemplary valve actuator ofFIG. 5A after having shifted the illustrated sliding sleeve into an open position. -
FIG. 5C shows the exemplary engagement arm ofFIG. 5A shifting the illustrated sliding sleeve into a closed position; and -
FIG. 5D shows the exemplary valve actuator ofFIG. 5A after having shifted the illustrated sliding sleeve into a closed position. - Characteristics and advantages of the present disclosure and additional features and benefits will be readily apparent to those skilled in the art upon consideration of the following detailed description of exemplary embodiments of the present disclosure and referring to the accompanying figures. It should be understood that the description herein and appended drawings, being of example embodiments, are not intended to limit the appended claims or claims of any patent or patent application claiming priority hereto. On the contrary, the intention is to cover all modifications, equivalents and alternatives falling within the spirit and scope of the claims. Many changes may be made to the particular embodiments and details disclosed herein without departing from such spirit and scope.
- In showing and describing preferred embodiments, common or similar elements are referenced in the appended figures with like or identical reference numerals or are apparent from the figures and/or the description herein. The figures are not necessarily to scale and certain features and certain views of the figures may be shown exaggerated in scale or in schematic in the interest of clarity and conciseness.
- As used herein and throughout various portions (and headings) of this patent application, the terms “invention”, “present invention” and variations thereof are not intended to mean every possible embodiment encompassed by this disclosure or any particular claim(s). Thus, the subject matter of each such reference should not be considered as necessary for, or part of, every embodiment hereof or of any particular claim(s) merely because of such reference. The terms “coupled”, “connected”, “engaged” and the like, and variations thereof, as used herein and in the appended claims are intended to mean either an indirect or direct connection or engagement. Thus, if a first device couples to a second device, that connection may be through a direct connection, or through an indirect connection via other devices and connections. Also, the terms “upward” and “downward” as used herein and in the appended claims may be relative to the top and/or bottom of a component, assembly or space and are not necessarily limited to movement in a vertical axis or plane.
- Certain terms are used herein and in the appended claims to refer to particular components. As one skilled in the art will appreciate, different persons may refer to a component by different names. This document does not intend to distinguish between components that differ in name but not function. Also, the terms “including” and “comprising” are used herein and in the appended claims in an open-ended fashion, and thus should be interpreted to mean “including, but not limited to . . . .” Further, reference herein and in the appended claims to components and aspects in a singular tense does not necessarily limit the present disclosure or appended claims to only one such component or aspect, but should be interpreted generally to mean one or more, as may be suitable and desirable in each particular instance.
- Referring initially to
FIG. 1 , an embodiment of avalve actuator 10 useful for shifting avalve 14 or other device disposed in asubterranean well 12 is shown. The illustrated well 12 is vertically oriented, but could instead be horizontal, deviated or have any other orientation. In this embodiment, thevalve 14 is a mechanicalisolation ball valve 16, which may be shifted between open and closed positions, as desired, with thevalve actuator 10. The illustratedball valve 16 is contained within avalve assembly 18, which is connected within alower completion arrangement 22 coupled to acasing 24, such as with a seal/locator assembly 28 andpacker 30. For example, thelower completion arrangement 22 may be run into and set in the well 12 in one trip with thevalve 14 in a closed position before thevalve actuator 10 is introduced into thewell 12. However, this set of components, configuration and sequence are provided for illustrative purposes only and are not required for, or limiting upon, the present disclosure. - It should be understood that the
valve actuator 10 may be used to move any type or configuration ofvalve 14 or other device between any desired positions. Some examples of such valves and other devices are flapper valves, ball valves, mechanical or hydraulic sliding sleeves, gravel pack closing sleeves and other fluid loss or recovery devices. Thus, the present invention is not limited to use with any particular type of valve or other shiftable device. As used herein and in the appended claims, unless specified otherwise, the term “valve” includes any type of device that is moveable between at least two positions. Further, the present invention is not limited by the number or nature of positions between which the valve may be shifted. Additionally, the valve may be disposed at any desired location in a subterranean well and in any desired downhole arrangement of components. Accordingly, the present disclosure is not limited by the type, configuration, action, purpose or operation of the device(s) that may be shifted in accordance with this disclosure. - Still referring to
FIG. 1 , thevalve actuator 10 may have any desired form, configuration and operation. In this embodiment, thevalve actuator 10 includes ashifter 32 which effectively moves thevalve 14 between positions. In some embodiments, referring toFIG. 2 , theshifter 32 may include at least onebalanced piston 34 and at least oneengagement arm 38 extending therefrom and moveable therewith. Theexemplary piston 34 is disposed and reciprocable within ahousing 42 by surface-controlled hydraulic (or pneumatic) pressurization throughcontrol lines piston 34 may be electrically-actuated. For example, one or more electric power line (not shown) may extend from the surface to an electric motor (not shown) connected with and used for powering thepiston 34. - Still referring to
FIG. 2 , the illustratedpiston 34 is shown in a “down” position after hydraulic fluid pressurization in thehousing 42 via thecontrol line 46. If it is desired to move the exemplary piston 34 (and engagement arm 38) to an “up” position (not shown), sufficient hydraulic fluid pressurization is provided via thecontrol line 48. Thus, thepiston 34 andengagement arm 38 of this embodiment are selectively, remotely moveable via hydraulics (or pneumatics) between “up” and “down” positions. However, thevalve actuator 10 of the present disclosure is not limited to this configuration. For example, a different arrangement and number of control lines may be used. For other examples, the piston 34 (and engagement arm 38) may be moveable between more than two positions or actuated in a different manner (other than hydraulics or pneumatics; e.g. electrical power). Further, thepiston 34 andengagement arm 38 may be separate components coupled together, integrally formed or part of or contained within other components. Also, in many embodiments, theshifter 32 may include different or additional components. Thus, the present invention is not limited by the type, configuration and operation of theshifter 32 or other embodiments of thevalve actuator 10. - Referring back to
FIG. 1 , thevalve actuator 10 may be associated with thevalve assembly 18 in any suitable manner and with any desired components to cause thevalve 14 to move between positions. In this embodiment, for example, theengagement arm 38 is slideable into and out of the upper end of thevalve assembly 18. Theexemplary arm 38 includes at least one profile, or rib, 52 that is engageable with upper and lower collets, or ribs, 56, 58 disposed on aninternal sleeve 60 in thevalve assembly 18. As theengagement arm 38 moves up or down (such as, e.g., by action of thepiston 34 ofFIG. 2 ), theprofile 52 engages and pushes one of thecollets valve 16 between positions. - In
FIG. 3A , for example, theengagement arm 38 is engaged with thevalve assembly 18 and theball valve 16 is in a closed position. This position of theengagement arm 38 is between “up” and “down” positions. As the piston (not shown) is actuated to move from an “up” to a “down” position, it causes theexemplary engagement arm 38 to move down (left to right inFIGS. 3A-D ). The downward movement of thearm 38 causes theprofile 52 to abut thelower collet 58 and push it and theinternal sleeve 60 downwardly.FIG. 3A thus illustrates the position of theexemplary profile 52 as it engages thelower collet 58 to begin opening thevalve 14. - Continued downward movement of the
exemplary arm 38 andinternal sleeve 60 will cause theball valve 16 to be shifted from a closed position to an open position, as shown inFIG. 3B . In this example, with sufficient downward movement to open thevalve 16, thelower collet 58 will seat in a lower undercut 66 in thevalve assembly 18, allowing theprofile 52 to move down past the lower collet 58 (FIG. 3B ), such as, for example, to accommodate any overstroke of the piston (not shown). - In this embodiment, the reverse movement of the piston (not shown) and
engagement arm 38 with cause theprofile 52 to engage theupper collet 56 and drive theinternal sleeve 60 in the upward direction to move thevalve 14 from an open to a closed position. Referring toFIG. 3B , for example, when the illustratedball valve 16 is in an open position, the upward movement of theengagement arm 38 will cause theprofile 52 to pass by the lower collet 58 (if theprofile 52 previously bypassed it) and abut the upper collet 56 (FIG. 3C ), pushing it and theinternal sleeve 60 upwardly. This movement will shift theball valve 16 into a closed position. As shown inFIGS. 3C and 3D , in this example, continued upward movement of theengagement arm 38 will cause theupper collet 56 to seat in an upper undercut 64 in thevalve assembly 18 and the illustratedprofile 52 to pass over theupper collet 56. Theengagement arm 58 and, thus, theshifter 32 may thereafter be slideably disengaged from thevalve assembly 18, allowing the exemplary valve actuator 10 (e.g.FIG. 1 ) to be entirely removable from the well 12 without disturbing the location of thevalve 14 therein. However, the present disclosure is not limited to this particular operation or arrangement of components. - If desired, the
valve actuator 10 may be removed from the well 12, replaced back into the well 12 and again used for shifting thevalve 14. This procedure may be repeated as many times as desired, such as for equipment service or replacement, to isolate the well for conducting other downhole operations, or any other desired purpose. Referring back toFIG. 1 , for example, theexemplary valve actuator 10 is coupled to the lower end of aproduction tubing 74, which also carries an electricsubmersible pump 70. Thepump 70 is useful to assist in drawing produced oil and/or gas up into theproduction tubing 74, such as in a low bottom-hole pressure well, as is and becomes further known. In this arrangement, if it becomes necessary to replace or service the pump 70 (production tubing 74,valve actuator 10, etc.), it may be desirable to close thevalve 14, isolate the well 12 and remove thetubing 74 and associated components from thewell 12. Accordingly, after theexemplary valve actuator 10 is actuated to shift thevalve 14 to a closed position, the production tubing 74 (withsubmersible pump 70 and valve actuator 10) may be retrieved up and out of the well 12. After the pump 70 (or other equipment) is serviced or replaced, thetubing 74 and connected components may be returned into thewell 12. - Still referring to
FIG. 1 , if desired, one ormore re-entry guide 78 may be associated with thevalve actuator 10,tubing 74 or other component to assist in alignment and reinsertion of thetubing 74 andvalve actuator 10. Also, in the illustrated example, as shown inFIG. 3D , thevalve assembly 18 includes aguide 82 to assist in aligning theengagement arm 38 within thevalve assembly 18. After thearm 38 is slideably engaged with thevalve assembly 18, downward movement of the illustratedarm 38 will cause theexemplary profile 52 to bypass theupper collet 56 and eventually engage thelower collet 58 to shift thevalve 16 from a closed to an open position, such as described above. Thevalve actuator 10 may thereafter be used as needed to shift theexemplary valve 16 between open and closed positions, and the entire process may be repeated as desired. - In
FIG. 4A , another embodiment of thevalve actuator 10 is shown in a multi-flow production configuration. In this example, thevalve actuator 10 is useful to open and close amechanical closing sleeve 86. The illustratedvalve actuator 10 is disposed at the end of theproduction tubing 74 and includes ashifter 32 having a piston (not shown) disposed in ahousing 42 and operable such as described above with respect toFIGS. 1 & 2 . In this example, the piston drives a perforatedinner pipe 88 upon which theengagement arm 38 is disposed. The illustratedengagement arm 38 is a support mandrel for at least oneengager 90 that is engageable with thesleeve 86. The engager 90 may be a collet, retractable finger or any other suitable component or member. - Still referring to
FIG. 4A , the illustratedclosing sleeve 86 opens and closes at least oneport 87 formed in thelower completion arrangement 22, or otherwise provided in the well 12 below apacker 30. Theport 87 allows fluid flow from anannulus 92 into theperforated pipe 88 during production, such as shown withflow arrows 94. Thelower completion arrangement 22, shown mounted in the well 12, includes a check, or standing,valve 96 that is liftable off aseat 98 by upward fluid pressure to allow fluid flow through the pipe bore 100 in alower pipe section 102 of thearrangement 22. The illustratedlower pipe section 102 is perforated, so that upwardly flowing fluid may pass both through the bore 100 (e.g. flow arrows 104) and into the annulus 92 (e.g. flow arrows 106). Accordingly,FIG. 4A illustrates the “down” position of theexemplary engagement arm 38 and the open positions of theclosing sleeve 86 andcheck valve 96 during production. - If production ceases or it is desirable to isolate or seal off the well 12 at this interval, such as to replace the
submersible pump 70 or other hardware, or for other operations, the piston (not shown) of theshifter 32 may be actuated from surface to move theperforated pipe 88 andengagement arm 38 upwardly. Referring toFIG. 4B , sufficient upward movement of the illustratedengagement arm 38 causes the engager(s) 90 to engage and close thesleeve 86. In this embodiment, continued upward movement of theengagement arm 38 will allow the engager(s) 90 to collapse or otherwise bypass or move above thesleeve 86, allowing removal of theproduction tubing 74 and all attached equipment (thevalve actuator 10, perforatedinner pipe 88,submersible pump 70, etc.) from thewell 12. Later, theproduction tubing 74 and other components may be reinserted into the well and thevalve actuator 10 used to re-open thesleeve 86 generally similarly as described above with respect to other embodiments. - In
FIGS. 5A-D , another embodiment of anengagement arm 38 in accordance with the present disclosure is shown useful for opening and closing a slidingsleeve 110. The illustrated slidingsleeve 110 includes and at least onepassageway 112 alignable with at least oneport 114 formed in a pipe 116 (or other component), such as to allow fluid flow into or out of abore 117. Thesleeve 110 also includes a B-shifting profile arrangement with upper andlower profiles - The illustrated
engagement arm 38 includes a multi-action, collapsible, B-shiftingbody portion 106 withcollets upper collet 118 is releasably engageable with thelower profile 126 of thesleeve 110 and thelower collet 120 is releasably engageable with theupper profile 124. The illustratedarm 38 is driven by a piston (not shown) as part of ashifter 32 and operates generally similarly as previously described with respect to other embodiments. - In
FIG. 5A , theexemplary engagement arm 38 is shown shifting thesleeve 110 into an open-port position. As thearm 38 is moved downwardly (from left to right inFIGS. 5A-D ), theupper collet 118 engages thelower profile 126 to move thesleeve 110, aligning thepassageway 112 with theport 114, as shown inFIG. 5B . If desired, continued downward movement of thearm 38 may cause thebody 106 of thearm 38 to collapse, if necessary, to allow theupper collet 118 to disengage from and bypass thelower profile 126. - Referring now to
FIGS. 5C-D , theexemplary engagement arm 38 is shown shifting thesleeve 110 into a closed-port position. As thearm 38 is moved upwardly, thelower collet 120 will engage theupper profile 124 and move thesleeve 110 upwardly until thepassageway 112 andport 114 are misaligned and out of fluid communication. If desired, continued upward movement of thearm 38 will cause thebody 106 to collapse, if necessary, to allow thelower collet 120 to disengage from and bypass theupper profile 124 and thearm 38 to disengage completely from thesleeve 110 andpipe 116, if desired. - Preferred embodiments of the present disclosure thus offer advantages over the prior art and are well adapted to carry out one or more of the objects of this disclosure. However, the present invention does not require each of the components and acts described above and is in no way limited to the above-described embodiments, methods of operation. Any one or more of the above components, features and processes may be employed in any suitable configuration without inclusion of other such components, features and processes. Moreover, the present invention includes additional features, capabilities, functions, methods, uses and applications that have not been specifically addressed herein but are, or will become, apparent from the description herein, the appended drawings and claims.
- The methods that are provided in or apparent from the description above or claimed herein, and any other methods which may fall within the scope of the appended claims, may be performed in any desired suitable order and are not necessarily limited to any sequence described herein or as may be listed in the appended claims. Further, the methods of the present invention do not necessarily require use of the particular embodiments shown and described herein, but are equally applicable with any other suitable structure, form and configuration of components.
- While exemplary embodiments of the invention have been shown and described, many variations, modifications and/or changes of the system, apparatus and methods of the present invention, such as in the components, details of construction and operation, arrangement of parts and/or methods of use, are possible, contemplated by the patent applicant(s), within the scope of the appended claims, and may be made and used by one of ordinary skill in the art without departing from the spirit or teachings of the invention and scope of appended claims. Thus, all matter herein set forth or shown in the accompanying drawings should be interpreted as illustrative, and the scope of the disclosure and the appended claims should not be limited to the embodiments described and shown herein.
Claims (23)
Priority Applications (1)
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US12/477,308 US20090301732A1 (en) | 2008-06-04 | 2009-06-03 | Downhole Valve Actuation Methods and Apparatus |
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US5890808P | 2008-06-04 | 2008-06-04 | |
US12/477,308 US20090301732A1 (en) | 2008-06-04 | 2009-06-03 | Downhole Valve Actuation Methods and Apparatus |
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US20090301732A1 true US20090301732A1 (en) | 2009-12-10 |
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US12/477,308 Abandoned US20090301732A1 (en) | 2008-06-04 | 2009-06-03 | Downhole Valve Actuation Methods and Apparatus |
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Cited By (8)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US20100300702A1 (en) * | 2009-05-27 | 2010-12-02 | Baker Hughes Incorporated | Wellbore Shut Off Valve with Hydraulic Actuator System |
US20110005772A1 (en) * | 2009-06-11 | 2011-01-13 | Schlumberger Technology Corporation | System, device, and method of installation of a pump below a formation isolation valve |
US20110114311A1 (en) * | 2008-07-02 | 2011-05-19 | Shell Internationale Research Maatschappij B.V. | Method of producing hydrocarbon fluid from a layer of oil sand |
WO2012054324A3 (en) * | 2010-10-19 | 2012-10-11 | Halliburton Energy Services, Inc. | Remotely controllable fluid flow control assembly |
US9988876B2 (en) | 2016-02-01 | 2018-06-05 | Weatherford Technology Holdings, Llc | Valve operable between open and closed configurations in response to same direction displacement |
US10167700B2 (en) | 2016-02-01 | 2019-01-01 | Weatherford Technology Holdings, Llc | Valve operable in response to engagement of different engagement members |
US20190178065A1 (en) * | 2017-12-12 | 2019-06-13 | Baker Hughes, A Ge Company, Llc | Method for real time flow control adjustment of a flow control device located downhole of an electric submersible pump |
US11761300B2 (en) | 2018-06-22 | 2023-09-19 | Schlumberger Technology Corporation | Full bore electric flow control valve system |
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2009
- 2009-06-03 BR BRPI0902704-1A patent/BRPI0902704A2/en not_active Application Discontinuation
- 2009-06-03 US US12/477,308 patent/US20090301732A1/en not_active Abandoned
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US20110114311A1 (en) * | 2008-07-02 | 2011-05-19 | Shell Internationale Research Maatschappij B.V. | Method of producing hydrocarbon fluid from a layer of oil sand |
US20100300702A1 (en) * | 2009-05-27 | 2010-12-02 | Baker Hughes Incorporated | Wellbore Shut Off Valve with Hydraulic Actuator System |
US20110005772A1 (en) * | 2009-06-11 | 2011-01-13 | Schlumberger Technology Corporation | System, device, and method of installation of a pump below a formation isolation valve |
US8459362B2 (en) * | 2009-06-11 | 2013-06-11 | Schlumberger Technology Corporation | System, device, and method of installation of a pump below a formation isolation valve |
WO2012054324A3 (en) * | 2010-10-19 | 2012-10-11 | Halliburton Energy Services, Inc. | Remotely controllable fluid flow control assembly |
US8596359B2 (en) | 2010-10-19 | 2013-12-03 | Halliburton Energy Services, Inc. | Remotely controllable fluid flow control assembly |
US9988876B2 (en) | 2016-02-01 | 2018-06-05 | Weatherford Technology Holdings, Llc | Valve operable between open and closed configurations in response to same direction displacement |
US10167700B2 (en) | 2016-02-01 | 2019-01-01 | Weatherford Technology Holdings, Llc | Valve operable in response to engagement of different engagement members |
US20190178065A1 (en) * | 2017-12-12 | 2019-06-13 | Baker Hughes, A Ge Company, Llc | Method for real time flow control adjustment of a flow control device located downhole of an electric submersible pump |
US10794162B2 (en) * | 2017-12-12 | 2020-10-06 | Baker Hughes, A Ge Company, Llc | Method for real time flow control adjustment of a flow control device located downhole of an electric submersible pump |
US11761300B2 (en) | 2018-06-22 | 2023-09-19 | Schlumberger Technology Corporation | Full bore electric flow control valve system |
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BRPI0902704A2 (en) | 2010-05-25 |
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