WO2011002676A2 - Tubular valve system and method - Google Patents

Tubular valve system and method Download PDF

Info

Publication number
WO2011002676A2
WO2011002676A2 PCT/US2010/039946 US2010039946W WO2011002676A2 WO 2011002676 A2 WO2011002676 A2 WO 2011002676A2 US 2010039946 W US2010039946 W US 2010039946W WO 2011002676 A2 WO2011002676 A2 WO 2011002676A2
Authority
WO
WIPO (PCT)
Prior art keywords
tubular
valve
port
contingency
sleeve
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Ceased
Application number
PCT/US2010/039946
Other languages
French (fr)
Other versions
WO2011002676A3 (en
Inventor
Paul Joseph
John R. Abarca
Luis E. Mendez
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Baker Hughes Holdings LLC
Original Assignee
Baker Hughes Inc
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Baker Hughes Inc filed Critical Baker Hughes Inc
Priority to CN201080029492.7A priority Critical patent/CN102472395B/en
Priority to AU2010266517A priority patent/AU2010266517B2/en
Priority to BR112012000005-5A priority patent/BR112012000005B1/en
Priority to EP20100794580 priority patent/EP2449293B1/en
Priority to EA201200088A priority patent/EA021887B1/en
Priority to DK10794580T priority patent/DK2449293T3/en
Publication of WO2011002676A2 publication Critical patent/WO2011002676A2/en
Publication of WO2011002676A3 publication Critical patent/WO2011002676A3/en
Priority to EG2011122175A priority patent/EG26539A/en
Anticipated expiration legal-status Critical
Ceased legal-status Critical Current

Links

Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B34/00—Valve arrangements for boreholes or wells
    • E21B34/06—Valve arrangements for boreholes or wells in wells
    • E21B34/066—Valve arrangements for boreholes or wells in wells electrically actuated
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F04—POSITIVE - DISPLACEMENT MACHINES FOR LIQUIDS; PUMPS FOR LIQUIDS OR ELASTIC FLUIDS
    • F04B—POSITIVE-DISPLACEMENT MACHINES FOR LIQUIDS; PUMPS
    • F04B47/00—Pumps or pumping installations specially adapted for raising fluids from great depths, e.g. well pumps
    • F04B47/02—Pumps or pumping installations specially adapted for raising fluids from great depths, e.g. well pumps the driving mechanisms being situated at ground level
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y10—TECHNICAL SUBJECTS COVERED BY FORMER USPC
    • Y10T—TECHNICAL SUBJECTS COVERED BY FORMER US CLASSIFICATION
    • Y10T137/00—Fluid handling
    • Y10T137/8593—Systems
    • Y10T137/87265—Dividing into parallel flow paths with recombining
    • Y10T137/87499—Fluid actuated or retarded

Definitions

  • Tubular valves that control occlusion of ports that fluidically connect an inner bore of a tubular with an outside of the tubular are commonly used in several industries including the downhole completion industry. Such valves are deployed in boreholes to control fluid flow in both directions, inside to outside of the tubular as well as outside to inside of the tubular, through the ports. Remote control of these valves provides advantages in operational efficiencies, in comparison to valves that require active interventive actuation, and have thus become quite popular. Remotely controlled valves, however, can malfunction. Costs associated with removal of the valves from the borehole to repair or replace the valve, in addition to the cost of lost production while the well is not producing, are a few of the concerns associated with use of these valves. Systems and methods that overcome the foregoing concerns would be well received in the art.
  • a tubular valve system Disclosed herein is a tubular valve system.
  • the system includes, a tubular, a primary valve actuatable to control occlusion of at least one port fluidically connecting an inner bore of the tubular with an outside of the tubular, and a contingency valve actuatable to control occlusion of at least one port fluidically connecting the inner bore with the outside of the tubular.
  • a method of valving a tubular includes, actively actuating a primary valve disposed at the tubular, and maintaining a contingency valve disposed at the tubular in reserve.
  • FIG. 1 depicts a partial cross sectional view of a tubular valve system disclosed herein with the primary valve open and the contingency valve closed;
  • FIG. 2 depicts a perspective view of the tubular valve system of FIG. 1;
  • FIG. 3 depicts a partial cross sectional view of the tubular valve system of FIG. 1 with the primary valve closed and the contingency valve open;
  • FIG. 4 depicts a partial cross sectional view of an alternate tubular valve system disclosed herein with the primary valve closed and the contingency valve closed;
  • FIG. 5 depicts a partial cross sectional view of the tubular valve system of FIG. 4 with the primary valve open and the contingency valve open.
  • the valve system 10 includes, a tubular 14 with a primary valve 18 and a contingency valve 22 disposed thereat.
  • the tubular 14 includes at least one first port 26 and at least one second port 30 that both fluidically connect an inner bore 34 of the tubular 14 with an outside 38 of the tubular 14.
  • the primary valve 18 is configured to control occlusion of the first port 26 while the contingency valve 22 is configured to control occlusion of at least the second port 30, with additional control of occlusion of the first port 26 by the contingency valve 22 being optional.
  • the contingency valve 22 has a sleeve 40 that is slidably engaged with the tubular 14.
  • the sleeve 40 is positioned within the inner bore 34 of the tubular 14.
  • the sleeve 40 is movable relative to the tubular 14 such that movement of the sleeve 40 can fully occlude the second port 30.
  • the sleeve 40 can be passive so that it is moved by mechanical engagement therewith by a shifting tool (not shown), for example. Additionally, an alternate actuator such as an actuator that uses an atmospheric chamber that is collapsed during actuation could shift the sleeve 40.
  • the primary valve 18 is an actively controlled valve and as such is configured to be controlled remotely as will be described in detail below.
  • the foregoing construction allows an operator to control the primary valve 18 and directly control the contingency valve 22.
  • the primary valve 18 can be used by an operator to control flow between the inner bore 34 and the outside 38 indefinitely, while maintaining the contingency valve 22 in reserve.
  • the contingency valve 22 can be employed to control flow between the inner bore 34 and the outside 38 at any time, including when the primary valve 18 fails to operate properly, due to jamming by contamination, for example.
  • the primary valve 18, in this embodiment, includes an elongated member 42 with a bore 46 that extends longitudinally therethrough.
  • a first port 50 and a second port 54 in the elongated member 42 align with the first port 26 and the second port 30 in the tubular 14 and fluidically connect with the bore 46.
  • both ports 26 and 30 are in fluidic communication with the outside 38 through the ports 50 and 54 and the bore 46.
  • Seals 58 and 62 illustrated herein as o-rings, seal the elongated member 42 to the tubular 14 to prevent leakage of fluid from the ports 50 and 54 to the outside 38 from between the elongated member 42 and the tubular 14.
  • a valve stem 66 is movable within a portion 46A of the bore 46 into sealable engagement with a shoulder 70 of the bore 46, thereby occluding fluidic communication between the inner bore 34 and the outside 38 through the first ports 26 and 50.
  • the valve stem 66 in this view is shown in a position that is not sealed to the shoulder 70 and thus the inner bore 34 is in fluidic communication with the outside 38 through the first ports 26 and 50.
  • the valve stem 66 in this embodiment, is driven by an actuator 74, depicted herein as an electric actuator, that is controlled by electrical power supplied via a signal carrier 78, depicted herein as an electric supply line or control line.
  • the signal carrier 78 can extend indefinitely in either or both directions along the tubular 14 from the valve system 10.
  • the signal carrier 78 may extend to a surface in applications wherein the valve system 10 is deployed within a wellbore (not shown) in an earth formation to allow remote control operation of the valve system 10 from the surface.
  • Other embodiments can use alternate actuators 74 to actuate the primary valve 18, such as, a hydraulic actuator (not shown) that can be supplied hydraulic power through a signal carrier 78 that includes fluidic supply lines.
  • the sleeve 40 of the contingency valve 22 is illustrated in this view in a position that fully occludes the second ports 30 and 54.
  • a pair of seals 82 shown herein as o-rings, slidably seal walls 84 of the sleeve 40 to walls 86 of the tubular 14 on either longitudinal side of the second port 30.
  • At least one second port 90 through the walls 84 of the sleeve 40 is shown located longitudinally outboard of both seals 82 and is therefore fruidically isolated from the second ports 30 and 54, and therefore maintains the contingency valve 22 in a closed position.
  • the sleeve 40 in this view, is illustrated in a position such that the second port 90 is longitudinally aligned with the second ports 30 and 54 thereby fruidically connects the inner bore 34 with the outside 38 maintaining the contingency valve 22 in an open position.
  • the sleeve 40 in this embodiment, also includes an optional collet 94 with collet fingers 98 that are biasingly engagable with a pair of recesses 102 formed in the walls 86 of the tubular 14. This engagement discourages unintentional movement of the sleeve 40 by positively maintaining the sleeve in one of the positions defined by the engagement of the collet fingers 98 within the recesses 102. Although the recesses 102 in this embodiment are located to maintain the sleeve 40 to either fully occlude the second port 30 with the sleeve 40 or to leave the second port 30 fully open to the second port 90.
  • a profile 106 also formed in the walls 84 of the sleeve 40 provide a detail that is engagable with a shifting tool (not shown) to facilitated positive latching between the shifting tool and the sleeve 40 to facilitate movement of the sleeve 40.
  • An optional collar 110 with similar features to those of the sleeve 40 can be employed to be mechanically shifted to occlude the first port 26. Shifting the collar 110 may be desirable in the event that the valve stem 66 of the primary valve 18 ceases in an open position. Such a malfunction would present a permanent fluidic connection between the inner bore 34 and the outside 38. The collar 110 could then be used to permanently occlude the first port 26 to thereby allow control of fluid communication between the inner bore 34 and the outside 38 via mechanical shifting of the contingency valve 22 thereafter.
  • the collar 110 is illustrated in FIG. 1 with a first port 114 through walls 118 thereof being longitudinally aligned with the first port 26, thereby providing fluid communication between the inner bore 34 and the outside 38 therethrough.
  • the collar 110 is movable through contact with the sleeve 40 during movement of the sleeve 40 in a direction toward the collar 110. In alternate embodiments not illustrated herein the collar 110 could be moved by direct mechanical engagement with a shifting tool.
  • Collet fingers 130 on a collet 134 of the collar 110 are biasingly engagable with recesses 138 in the walls 86 to discourage unintended movement of the collar 110 with respect to the tubular 14.
  • Seals 142 slidably sealingly engage the walls 86 to the walls 118 a longitudinal dimension apart that spans at least the longitudinal dimension of the first port 26. As such, when the collar 110 is shifted to the position illustrated in FIG. 3, the seals 142 effectively fluidically deadhead the first port 26 to the walls 118 between the seals 142 thereby occluding fluid communication between the inner bore 34 and the outside 38.
  • valve system 210 has only the single first port 26 and not the second port 54, as are both included in the valve system 10.
  • the valve system 210 having only the first port 26 negates the need for both the sleeve 40 and the collar 110, as are incorporated in the valve system 10 to selectively close the second port 54 and the first port 26, respectively.
  • the sleeve 40 in the valve system 210 therefore, is used to selectively close the first port 26 and, as such, the valve system 210 does not include the collar 54.

Landscapes

  • Engineering & Computer Science (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Mining & Mineral Resources (AREA)
  • Geology (AREA)
  • Fluid Mechanics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Physics & Mathematics (AREA)
  • General Engineering & Computer Science (AREA)
  • Mechanical Engineering (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Lift Valve (AREA)
  • Multiple-Way Valves (AREA)
  • Pipe Accessories (AREA)
  • Quick-Acting Or Multi-Walled Pipe Joints (AREA)

Abstract

A tubular valve system includes, a tubular, a primary valve actuatable to control occlusion of at least one port fluidically connecting an inner bore of the tubular with an outside of the tubular, and a contingency valve actuatable to control occlusion of at least one port fluidically connecting the inner bore with the outside of the tubular.

Description

TUBULAR VALVE SYSTEM AND METHOD
CROSS REFERENCE TO RELATED APPLICATIONS
[0001] This application contains subject matter related to the subject matter of co- pending applications, which are assigned to the same assignee as this application, Baker Hughes Incorporated of Houston, Texas. The below listed applications are hereby incorporated by reference in their entirety:
[0002] U.S. Patent Application Attorney Docket No. 274-49265-US, entitled MODULAR VALVE BODY AND METHOD OF MAKING; and
[0003] U.S. Patent Application Attorney Docket No. 274-49268-US, entitled TUBULAR VALVING SYSTEM AND METHOD.
BACKGROUND
[0004] Tubular valves that control occlusion of ports that fluidically connect an inner bore of a tubular with an outside of the tubular are commonly used in several industries including the downhole completion industry. Such valves are deployed in boreholes to control fluid flow in both directions, inside to outside of the tubular as well as outside to inside of the tubular, through the ports. Remote control of these valves provides advantages in operational efficiencies, in comparison to valves that require active interventive actuation, and have thus become quite popular. Remotely controlled valves, however, can malfunction. Costs associated with removal of the valves from the borehole to repair or replace the valve, in addition to the cost of lost production while the well is not producing, are a few of the concerns associated with use of these valves. Systems and methods that overcome the foregoing concerns would be well received in the art.
BRIEF DESCRIPTION
[0005] Disclosed herein is a tubular valve system. The system includes, a tubular, a primary valve actuatable to control occlusion of at least one port fluidically connecting an inner bore of the tubular with an outside of the tubular, and a contingency valve actuatable to control occlusion of at least one port fluidically connecting the inner bore with the outside of the tubular.
[0006] Further disclosed herein is a method of valving a tubular. The method includes, actively actuating a primary valve disposed at the tubular, and maintaining a contingency valve disposed at the tubular in reserve. BRIEF DESCRIPTION OF THE DRAWINGS
[0007] The following descriptions should not be considered limiting in any way. With reference to the accompanying drawings, like elements are numbered alike:
[0008] FIG. 1 depicts a partial cross sectional view of a tubular valve system disclosed herein with the primary valve open and the contingency valve closed;
[0009] FIG. 2 depicts a perspective view of the tubular valve system of FIG. 1;
[0010] FIG. 3 depicts a partial cross sectional view of the tubular valve system of FIG. 1 with the primary valve closed and the contingency valve open;
[0011] FIG. 4 depicts a partial cross sectional view of an alternate tubular valve system disclosed herein with the primary valve closed and the contingency valve closed; and
[0012] FIG. 5 depicts a partial cross sectional view of the tubular valve system of FIG. 4 with the primary valve open and the contingency valve open.
DETAILED DESCRIPTION
[0013] A detailed description of one or more embodiments of the disclosed apparatus and method are presented herein by way of exemplification and not limitation with reference to the Figures.
[0014] Referring to FIG. 1, an embodiment of a tubular valve system disclosed herein is illustrated generally at 10. The valve system 10 includes, a tubular 14 with a primary valve 18 and a contingency valve 22 disposed thereat. The tubular 14 includes at least one first port 26 and at least one second port 30 that both fluidically connect an inner bore 34 of the tubular 14 with an outside 38 of the tubular 14. The primary valve 18 is configured to control occlusion of the first port 26 while the contingency valve 22 is configured to control occlusion of at least the second port 30, with additional control of occlusion of the first port 26 by the contingency valve 22 being optional. The contingency valve 22 has a sleeve 40 that is slidably engaged with the tubular 14. In this embodiment, the sleeve 40 is positioned within the inner bore 34 of the tubular 14. The sleeve 40 is movable relative to the tubular 14 such that movement of the sleeve 40 can fully occlude the second port 30. The sleeve 40 can be passive so that it is moved by mechanical engagement therewith by a shifting tool (not shown), for example. Additionally, an alternate actuator such as an actuator that uses an atmospheric chamber that is collapsed during actuation could shift the sleeve 40.
[0015] In this embodiment, the primary valve 18 is an actively controlled valve and as such is configured to be controlled remotely as will be described in detail below. The foregoing construction allows an operator to control the primary valve 18 and directly control the contingency valve 22. As such, the primary valve 18 can be used by an operator to control flow between the inner bore 34 and the outside 38 indefinitely, while maintaining the contingency valve 22 in reserve. The contingency valve 22 can be employed to control flow between the inner bore 34 and the outside 38 at any time, including when the primary valve 18 fails to operate properly, due to jamming by contamination, for example.
[0016] The primary valve 18, in this embodiment, includes an elongated member 42 with a bore 46 that extends longitudinally therethrough. A first port 50 and a second port 54 in the elongated member 42 align with the first port 26 and the second port 30 in the tubular 14 and fluidically connect with the bore 46. As such, both ports 26 and 30 are in fluidic communication with the outside 38 through the ports 50 and 54 and the bore 46. Seals 58 and 62, illustrated herein as o-rings, seal the elongated member 42 to the tubular 14 to prevent leakage of fluid from the ports 50 and 54 to the outside 38 from between the elongated member 42 and the tubular 14. A valve stem 66 is movable within a portion 46A of the bore 46 into sealable engagement with a shoulder 70 of the bore 46, thereby occluding fluidic communication between the inner bore 34 and the outside 38 through the first ports 26 and 50. The valve stem 66 in this view is shown in a position that is not sealed to the shoulder 70 and thus the inner bore 34 is in fluidic communication with the outside 38 through the first ports 26 and 50.
[0017] Referring to FIG. 2, the valve stem 66, in this embodiment, is driven by an actuator 74, depicted herein as an electric actuator, that is controlled by electrical power supplied via a signal carrier 78, depicted herein as an electric supply line or control line. The signal carrier 78 can extend indefinitely in either or both directions along the tubular 14 from the valve system 10. For example, the signal carrier 78 may extend to a surface in applications wherein the valve system 10 is deployed within a wellbore (not shown) in an earth formation to allow remote control operation of the valve system 10 from the surface. Other embodiments can use alternate actuators 74 to actuate the primary valve 18, such as, a hydraulic actuator (not shown) that can be supplied hydraulic power through a signal carrier 78 that includes fluidic supply lines.
[0018] Referring again to FIG. 1, the sleeve 40 of the contingency valve 22 is illustrated in this view in a position that fully occludes the second ports 30 and 54. A pair of seals 82, shown herein as o-rings, slidably seal walls 84 of the sleeve 40 to walls 86 of the tubular 14 on either longitudinal side of the second port 30. At least one second port 90 through the walls 84 of the sleeve 40, in this view, is shown located longitudinally outboard of both seals 82 and is therefore fruidically isolated from the second ports 30 and 54, and therefore maintains the contingency valve 22 in a closed position.
[0019] Referring to FIG. 3, the sleeve 40, in this view, is illustrated in a position such that the second port 90 is longitudinally aligned with the second ports 30 and 54 thereby fruidically connects the inner bore 34 with the outside 38 maintaining the contingency valve 22 in an open position. A recess 92 defined by a portion of the sleeve 40 having a reduced radial dimension, is longitudinally aligned with the second port 90 to create an annular space 93 between the sleeve 40 and the tubular 14 to allow fluid to flow in the annular space 93 from between the at least one second port 90 and the second port 30 when the second port 90 is longitudinally aligned with the second port 30.
[0020] The sleeve 40, in this embodiment, also includes an optional collet 94 with collet fingers 98 that are biasingly engagable with a pair of recesses 102 formed in the walls 86 of the tubular 14. This engagement discourages unintentional movement of the sleeve 40 by positively maintaining the sleeve in one of the positions defined by the engagement of the collet fingers 98 within the recesses 102. Although the recesses 102 in this embodiment are located to maintain the sleeve 40 to either fully occlude the second port 30 with the sleeve 40 or to leave the second port 30 fully open to the second port 90. A profile 106 also formed in the walls 84 of the sleeve 40 provide a detail that is engagable with a shifting tool (not shown) to facilitated positive latching between the shifting tool and the sleeve 40 to facilitate movement of the sleeve 40.
[0021] An optional collar 110 with similar features to those of the sleeve 40 can be employed to be mechanically shifted to occlude the first port 26. Shifting the collar 110 may be desirable in the event that the valve stem 66 of the primary valve 18 ceases in an open position. Such a malfunction would present a permanent fluidic connection between the inner bore 34 and the outside 38. The collar 110 could then be used to permanently occlude the first port 26 to thereby allow control of fluid communication between the inner bore 34 and the outside 38 via mechanical shifting of the contingency valve 22 thereafter. The collar 110 is illustrated in FIG. 1 with a first port 114 through walls 118 thereof being longitudinally aligned with the first port 26, thereby providing fluid communication between the inner bore 34 and the outside 38 therethrough. A recess 122 defined by a reduced radial dimension of the walls 118 in longitudinal alignment with the first port 114 creates an annular space 126 between the collar 110 and the tubular 14 to permit fluid flow to flow therethrough between any of the first ports 114 and the first port 26. [0022] The collar 110 is movable through contact with the sleeve 40 during movement of the sleeve 40 in a direction toward the collar 110. In alternate embodiments not illustrated herein the collar 110 could be moved by direct mechanical engagement with a shifting tool. Collet fingers 130 on a collet 134 of the collar 110 are biasingly engagable with recesses 138 in the walls 86 to discourage unintended movement of the collar 110 with respect to the tubular 14. Seals 142 slidably sealingly engage the walls 86 to the walls 118 a longitudinal dimension apart that spans at least the longitudinal dimension of the first port 26. As such, when the collar 110 is shifted to the position illustrated in FIG. 3, the seals 142 effectively fluidically deadhead the first port 26 to the walls 118 between the seals 142 thereby occluding fluid communication between the inner bore 34 and the outside 38.
[0023] Referring to Figures 4 and 5, an alternate embodiment of a tubular valve system disclosed herein is illustrated generally at 210. Due to the similarities between the valve system 210 and the valve system 10, many items are identical and, as such, are numbered alike and are not described again in detail hereunder. A primary difference between the two valve systems 210 and 10 is that the valve system 210 has only the single first port 26 and not the second port 54, as are both included in the valve system 10. The valve system 210, having only the first port 26 negates the need for both the sleeve 40 and the collar 110, as are incorporated in the valve system 10 to selectively close the second port 54 and the first port 26, respectively. The sleeve 40 in the valve system 210, therefore, is used to selectively close the first port 26 and, as such, the valve system 210 does not include the collar 54.
[0024] In Figure 4 the first port 26, as illustrated, is fully occluded by the contingency valve 222. In contrast, as illustrated in Figure 5, the second ports 90 of the sleeve 40 are aligned with the first port 26, and the contingency valve 222 provides not blockage of the first port 26.
[0025] While the invention has been described with reference to an exemplary embodiment or embodiments, it will be understood by those skilled in the art that various changes may be made and equivalents may be substituted for elements thereof without departing from the scope of the invention. In addition, many modifications may be made to adapt a particular situation or material to the teachings of the invention without departing from the essential scope thereof. Therefore, it is intended that the invention not be limited to the particular embodiment disclosed as the best mode contemplated for carrying out this invention, but that the invention will include all embodiments falling within the scope of the claims. Also, in the drawings and the description, there have been disclosed exemplary embodiments of the invention and, although specific terms may have been employed, they are unless otherwise stated used in a generic and descriptive sense only and not for purposes of limitation, the scope of the invention therefore not being so limited. Moreover, the use of the terms first, second, etc. do not denote any order or importance, but rather the terms first, second, etc. are used to distinguish one element from another. Furthermore, the use of the terms a, an, etc. do not denote a limitation of quantity, but rather denote the presence of at least one of the referenced item.

Claims

CLAIMS What is claimed is:
1. A tubular valve system, comprising:
a tubular;
a primary valve actuatable to control occlusion of at least one port fluidically connecting an inner bore of the tubular with an outside of the tubular; and
a contingency valve actuatable to control occlusion of at least one port fluidically connecting the inner bore with the outside of the tubular.
2. The tubular valve system of claim 1, wherein the primary valve is actively controlled and the contingency valve is passively controlled.
3. The tubular valve system of claim 1, wherein the tubular valve system is deployable within a wellbore.
4. The tubular valve system of claim 1, wherein the primary valve is controlled by one of electrical power and hydraulic pressure.
5. The tubular valve system of claim 1, wherein the contingency valve is controlled by mechanical actuation.
6. The tubular valve system of claim 1, wherein the contingency valve includes a sleeve that is movable relative to the tubular.
7. The tubular valve system of claim 6, wherein the sleeve has at least one contingency opening that can be aligned with the at least one port to open the at least one port or misaligned with the at least one port to occlude the at least one port.
8. The tubular valve system of claim 6, wherein the sleeve is slidably sealingly engaged with the tubular.
9. The tubular valve system of claim 6, further comprising a collet in operable communication with the sleeve and the tubular to maintain the sleeve in a position relative to the tubular when the sleeve is not being moved.
10. The tubular valve system of claim 6, wherein the sleeve includes a profile engagable with a shifting tool.
11. The tubular valve system of claim 1 , further comprising a collar having at least one primary opening positionable at least between a first position aligning the primary opening with the at least one port and a second position misaligning the primary opening with the at least one port to occlude the at least one port.
12. The tubular valve system of claim 11, wherein the collar is movable from the first position to the second position by actuation of the contingency valve.
13. The tubular valve system of claim 1, further comprising a collar valve configured to defeat the primary valve upon actuation thereof.
14. The tubular valve system of claim 1, wherein the primary valve is configured to control occlusion of at least one first port and the contingency valve is configured to control occlusion of at least one second port and the at least one first port is not the at least one second port.
15. A method of valving a tubular, comprising:
actively actuating a primary valve disposed at the tubular; and
maintaining a contingency valve disposed at the tubular in reserve.
16. The method of valving a tubular of claim 15, further comprising actuating the contingency valve upon loss of performance of the primary valve.
17. The method of valving a tubular of claim 16, wherein the actuating the contingency valve is via mechanical actuation.
18. The method of valving a tubular of claim 15, further comprising engaging the contingency valve with a shifting tool.
19. The method of valving a tubular of claim 15, further comprising moving a sleeve relative to the tubular.
20. The method of valving a tubular of claim 19, further comprising moving a collar relative to the tubular.
21. The method of valving a tubular of claim 15, further comprising actuating the contingency valve to open the contingency valve.
22. The method of valving a tubular of claim 21, wherein the actuating the contingency valve includes closing the primary valve.
23. The method of valving a tubular of claim 21, further comprising defeating the primary valve with the actuating of the contingency valve.
PCT/US2010/039946 2009-07-02 2010-06-25 Tubular valve system and method Ceased WO2011002676A2 (en)

Priority Applications (7)

Application Number Priority Date Filing Date Title
CN201080029492.7A CN102472395B (en) 2009-07-02 2010-06-25 Tubular valve system and method
AU2010266517A AU2010266517B2 (en) 2009-07-02 2010-06-25 Tubular valve system and method
BR112012000005-5A BR112012000005B1 (en) 2009-07-02 2010-06-25 tubular valve system and method
EP20100794580 EP2449293B1 (en) 2009-07-02 2010-06-25 Tubular valve system and method
EA201200088A EA021887B1 (en) 2009-07-02 2010-06-25 Tubular valve system and method of valving a tubular
DK10794580T DK2449293T3 (en) 2009-07-02 2010-06-25 Pipe valve system and method therefore
EG2011122175A EG26539A (en) 2009-07-02 2011-12-28 Tubular valve system and method

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US12/497,076 2009-07-02
US12/497,076 US8281865B2 (en) 2009-07-02 2009-07-02 Tubular valve system and method

Publications (2)

Publication Number Publication Date
WO2011002676A2 true WO2011002676A2 (en) 2011-01-06
WO2011002676A3 WO2011002676A3 (en) 2011-03-31

Family

ID=43411678

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/US2010/039946 Ceased WO2011002676A2 (en) 2009-07-02 2010-06-25 Tubular valve system and method

Country Status (10)

Country Link
US (1) US8281865B2 (en)
EP (1) EP2449293B1 (en)
CN (1) CN102472395B (en)
AU (1) AU2010266517B2 (en)
BR (1) BR112012000005B1 (en)
DK (1) DK2449293T3 (en)
EA (1) EA021887B1 (en)
EG (1) EG26539A (en)
MY (1) MY157337A (en)
WO (1) WO2011002676A2 (en)

Cited By (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US8261817B2 (en) 2009-11-13 2012-09-11 Baker Hughes Incorporated Modular hydraulic operator for a subterranean tool
GB2495504A (en) * 2011-10-11 2013-04-17 Red Spider Technology Ltd Downhole bypass valve assembly
GB2497506A (en) * 2011-10-11 2013-06-19 Red Spider Technology Ltd Downhole contingency apparatus
US9376891B2 (en) 2011-10-11 2016-06-28 Halliburton Manufacturing & Services Limited Valve actuating apparatus
US9482074B2 (en) 2011-10-11 2016-11-01 Halliburton Manufacturing & Services Limited Valve actuating apparatus
US10697270B2 (en) 2015-07-03 2020-06-30 Aker Solutions As Annulus isolation valve assembly

Families Citing this family (17)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20100319928A1 (en) * 2009-06-22 2010-12-23 Baker Hughes Incorporated Through tubing intelligent completion and method
US20110000660A1 (en) * 2009-07-02 2011-01-06 Baker Hughes Incorporated Modular valve body and method of making
US20110000674A1 (en) * 2009-07-02 2011-01-06 Baker Hughes Incorporated Remotely controllable manifold
US8281865B2 (en) 2009-07-02 2012-10-09 Baker Hughes Incorporated Tubular valve system and method
US20110000547A1 (en) * 2009-07-02 2011-01-06 Baker Hughes Incorporated Tubular valving system and method
US8267180B2 (en) * 2009-07-02 2012-09-18 Baker Hughes Incorporated Remotely controllable variable flow control configuration and method
US20110073323A1 (en) * 2009-09-29 2011-03-31 Baker Hughes Incorporated Line retention arrangement and method
US9051809B2 (en) 2011-04-29 2015-06-09 Weatherford Technology Holdings, Llc Casing relief valve
WO2012149433A2 (en) * 2011-04-29 2012-11-01 Weatherford/Lamb, Inc. Annular relief valve
CA2834230C (en) 2011-04-29 2016-06-14 Weatherford/Lamb, Inc. Annular pressure release sub
US9574422B2 (en) 2012-07-13 2017-02-21 Baker Hughes Incorporated Formation treatment system
US10151173B2 (en) * 2012-09-13 2018-12-11 Switchfloat Holdings Limited Float valve hold open devices and methods therefor
US9863221B2 (en) * 2013-05-29 2018-01-09 Tubel Energy, Llc Downhole integrated well management system
US10119365B2 (en) 2015-01-26 2018-11-06 Baker Hughes, A Ge Company, Llc Tubular actuation system and method
AU2016397557B2 (en) 2016-03-14 2022-03-17 Halliburton Energy Services, Inc. Mechanisms for transferring hydraulic regulation from a primary safety valve to a secondary safety valve
WO2018076119A1 (en) * 2016-10-28 2018-05-03 Ncs Multistage Inc. Apparatus, systems and methods for isolation during multistage hydraulic fracturing
WO2022119728A1 (en) 2020-12-04 2022-06-09 Schlumberger Technology Corporation Dual ball seat system

Citations (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20040118564A1 (en) 2002-08-21 2004-06-24 Packers Plus Energy Services Inc. Method and apparatus for wellbore fluid treatment
DE102005060008A1 (en) 2004-12-14 2006-06-22 Schlumberger Technology B.V. Apparatus and method for use in a wellbore with multiple well zones
US20060207763A1 (en) 2005-03-15 2006-09-21 Peak Completion Technologies, Inc. Cemented open hole selective fracing system
US20070127227A1 (en) 2005-12-07 2007-06-07 Rohm Co., Ltd. LED display

Family Cites Families (47)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
DE1550435A1 (en) 1966-02-25 1970-08-13 Wilhelm Odendahl Throttle device
US3980135A (en) 1971-08-18 1976-09-14 Schlumberger Technology Corporation Self-contained, retrievable valving assembly
US4066128A (en) * 1975-07-14 1978-01-03 Otis Engineering Corporation Well flow control apparatus and method
US4026363A (en) * 1975-12-09 1977-05-31 Otis Engineering Corporation Apparatus and method for performing a desired operation at a specified location in a well
US4357952A (en) 1979-08-29 1982-11-09 Teledyne Adams Tubular valve device and method of assembly
US4360064A (en) 1980-11-12 1982-11-23 Exxon Production Research Co. Circulating valve for wells
US4441558A (en) 1982-04-15 1984-04-10 Otis Engineering Corporation Valve
US4629002A (en) 1985-10-18 1986-12-16 Camco, Incorporated Equalizing means for a subsurface well safety valve
US4790378A (en) * 1987-02-06 1988-12-13 Otis Engineering Corporation Well testing apparatus
US4976314A (en) 1988-02-03 1990-12-11 Crawford William B T-slot mandrel and kickover tool
US5018575A (en) 1988-10-25 1991-05-28 Mandrels, Inc. Apparatus for reducing abrasion and corrosion in mandrels
US4951752A (en) 1989-04-20 1990-08-28 Exxon Production Research Company Standing valve
US4962815A (en) 1989-07-17 1990-10-16 Halliburton Company Inflatable straddle packer
US5297634A (en) 1991-08-16 1994-03-29 Baker Hughes Incorporated Method and apparatus for reducing wellbore-fluid pressure differential forces on a settable wellbore tool in a flowing well
US5291947A (en) 1992-06-08 1994-03-08 Atlantic Richfield Company Tubing conveyed wellbore straddle packer system
US5803119A (en) 1995-02-08 1998-09-08 Control Components Inc. Fluid flow control device
US5743497A (en) 1996-02-13 1998-04-28 Michael; Douglas C. Wire installation strip
US5906238A (en) 1996-04-01 1999-05-25 Baker Hughes Incorporated Downhole flow control devices
US5896928A (en) 1996-07-01 1999-04-27 Baker Hughes Incorporated Flow restriction device for use in producing wells
US5803179A (en) 1996-12-31 1998-09-08 Halliburton Energy Services, Inc. Screened well drainage pipe structure with sealed, variable length labyrinth inlet flow control apparatus
AU713643B2 (en) 1997-05-06 1999-12-09 Baker Hughes Incorporated Flow control apparatus and methods
WO1999005395A1 (en) 1997-07-24 1999-02-04 Camco International Inc. Full bore variable flow control device
US6394181B2 (en) 1999-06-18 2002-05-28 Halliburton Energy Services, Inc. Self-regulating lift fluid injection tool and method for use of same
US6382569B1 (en) 2000-01-12 2002-05-07 Graydon Products, Inc. Line holder apparatus
US7255178B2 (en) 2000-06-30 2007-08-14 Bj Services Company Drillable bridge plug
GB2399843B (en) 2000-08-17 2004-12-22 Abb Offshore Systems Ltd Flow control device
US7222676B2 (en) 2000-12-07 2007-05-29 Schlumberger Technology Corporation Well communication system
US6883610B2 (en) 2000-12-20 2005-04-26 Karol Depiak Straddle packer systems
ATE327410T1 (en) 2001-03-20 2006-06-15 Fast S R L WEAR PROTECTION FOR PRODUCTION TUBING
US6644412B2 (en) 2001-04-25 2003-11-11 Weatherford/Lamb, Inc. Flow control apparatus for use in a wellbore
CA2412072C (en) * 2001-11-19 2012-06-19 Packers Plus Energy Services Inc. Method and apparatus for wellbore fluid treatment
US6810955B2 (en) 2002-08-22 2004-11-02 Baker Hughes Incorporated Gas lift mandrel
AU2004225541B2 (en) 2003-03-28 2008-03-13 Shell Internationale Research Maatschappij B.V. Surface flow controlled valve and screen
CN2608681Y (en) * 2003-03-31 2004-03-31 渤海石油实业公司 Automatic reset oil drain apparatus for oil field electric submerged pump production oil well
US7409999B2 (en) 2004-07-30 2008-08-12 Baker Hughes Incorporated Downhole inflow control device with shut-off feature
US7261155B1 (en) 2004-08-23 2007-08-28 Varco I/P Cable side-entry sub with grease injection flow tubes
US7431085B2 (en) 2005-01-14 2008-10-07 Baker Hughes Incorporated Gravel pack multi-pathway tube with control line retention and method for retaining control line
US7464761B2 (en) 2006-01-13 2008-12-16 Schlumberger Technology Corporation Flow control system for use in a well
US7360602B2 (en) 2006-02-03 2008-04-22 Baker Hughes Incorporated Barrier orifice valve for gas lift
US20080041581A1 (en) 2006-08-21 2008-02-21 William Mark Richards Apparatus for controlling the inflow of production fluids from a subterranean well
US7644755B2 (en) 2006-08-23 2010-01-12 Baker Hughes Incorporated Annular electrical wet connect
US20090120647A1 (en) 2006-12-06 2009-05-14 Bj Services Company Flow restriction apparatus and methods
US7900705B2 (en) 2007-03-13 2011-03-08 Schlumberger Technology Corporation Flow control assembly having a fixed flow control device and an adjustable flow control device
US20080283238A1 (en) 2007-05-16 2008-11-20 William Mark Richards Apparatus for autonomously controlling the inflow of production fluids from a subterranean well
US20090095468A1 (en) 2007-10-12 2009-04-16 Baker Hughes Incorporated Method and apparatus for determining a parameter at an inflow control device in a well
US8281865B2 (en) 2009-07-02 2012-10-09 Baker Hughes Incorporated Tubular valve system and method
US20110000660A1 (en) 2009-07-02 2011-01-06 Baker Hughes Incorporated Modular valve body and method of making

Patent Citations (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20040118564A1 (en) 2002-08-21 2004-06-24 Packers Plus Energy Services Inc. Method and apparatus for wellbore fluid treatment
DE102005060008A1 (en) 2004-12-14 2006-06-22 Schlumberger Technology B.V. Apparatus and method for use in a wellbore with multiple well zones
US20060207763A1 (en) 2005-03-15 2006-09-21 Peak Completion Technologies, Inc. Cemented open hole selective fracing system
US20070127227A1 (en) 2005-12-07 2007-06-07 Rohm Co., Ltd. LED display

Non-Patent Citations (1)

* Cited by examiner, † Cited by third party
Title
See also references of EP2449293A4

Cited By (10)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US8261817B2 (en) 2009-11-13 2012-09-11 Baker Hughes Incorporated Modular hydraulic operator for a subterranean tool
GB2495504A (en) * 2011-10-11 2013-04-17 Red Spider Technology Ltd Downhole bypass valve assembly
GB2497506A (en) * 2011-10-11 2013-06-19 Red Spider Technology Ltd Downhole contingency apparatus
US9316088B2 (en) 2011-10-11 2016-04-19 Halliburton Manufacturing & Services Limited Downhole contingency apparatus
US9376891B2 (en) 2011-10-11 2016-06-28 Halliburton Manufacturing & Services Limited Valve actuating apparatus
US9376889B2 (en) 2011-10-11 2016-06-28 Halliburton Manufacturing & Services Limited Downhole valve assembly
US9482074B2 (en) 2011-10-11 2016-11-01 Halliburton Manufacturing & Services Limited Valve actuating apparatus
GB2497506B (en) * 2011-10-11 2017-10-11 Halliburton Mfg & Services Ltd Downhole contingency apparatus
GB2495504B (en) * 2011-10-11 2018-05-23 Halliburton Mfg & Services Limited Downhole valve assembly
US10697270B2 (en) 2015-07-03 2020-06-30 Aker Solutions As Annulus isolation valve assembly

Also Published As

Publication number Publication date
AU2010266517A1 (en) 2012-01-19
BR112012000005A2 (en) 2020-11-03
EP2449293A4 (en) 2012-12-19
BR112012000005B1 (en) 2021-03-09
EG26539A (en) 2014-02-06
EP2449293A2 (en) 2012-05-09
US8281865B2 (en) 2012-10-09
EP2449293B1 (en) 2014-08-27
EA201200088A1 (en) 2012-07-30
CN102472395A (en) 2012-05-23
AU2010266517B2 (en) 2014-08-14
MY157337A (en) 2016-05-31
EA021887B1 (en) 2015-09-30
US20110000679A1 (en) 2011-01-06
DK2449293T3 (en) 2014-10-06
CN102472395B (en) 2014-07-23
WO2011002676A3 (en) 2011-03-31

Similar Documents

Publication Publication Date Title
US8281865B2 (en) Tubular valve system and method
US7150326B2 (en) Bi-directional ball seat system and method
EP3757347B1 (en) Circulation control valve and associated method
US9695679B2 (en) Downhole zone flow control system
US6109357A (en) Control line actuation of multiple downhole components
AU2014229780B2 (en) Downhole shifting tool
WO2014036431A2 (en) Stabilized valve
NO343298B1 (en) Annulus isolation valve assembly and associated method
US20110203805A1 (en) Valving Device and Method of Valving
GB2491140A (en) Downhole flow control
US9316088B2 (en) Downhole contingency apparatus
US10184308B2 (en) Method and apparatus for downhole tool actuation
EP2206878A2 (en) Multi-position hydraulic actuator
US8857454B2 (en) Valving system and method of selectively halting injection of chemicals
EP2834445B1 (en) Actuator for dual drill string valve and drill string valve configurations therefor
WO2010007403A1 (en) Well tool
US20150191995A1 (en) Stacked piston safety valves and related methods
EP3290634B1 (en) Multi-port ball valve for while drilling applications
US20110000547A1 (en) Tubular valving system and method
AU2018298471B2 (en) Downhole fluid control apparatus
EA042252B1 (en) UNDERGROUND COMPLETION SYSTEM

Legal Events

Date Code Title Description
WWE Wipo information: entry into national phase

Ref document number: 201080029492.7

Country of ref document: CN

121 Ep: the epo has been informed by wipo that ep was designated in this application

Ref document number: 10794580

Country of ref document: EP

Kind code of ref document: A2

WWE Wipo information: entry into national phase

Ref document number: 2010266517

Country of ref document: AU

WWE Wipo information: entry into national phase

Ref document number: 2010794580

Country of ref document: EP

WWE Wipo information: entry into national phase

Ref document number: 10283/DELNP/2011

Country of ref document: IN

NENP Non-entry into the national phase

Ref country code: DE

ENP Entry into the national phase

Ref document number: 2010266517

Country of ref document: AU

Date of ref document: 20100625

Kind code of ref document: A

WWE Wipo information: entry into national phase

Ref document number: 201200088

Country of ref document: EA

REG Reference to national code

Ref country code: BR

Ref legal event code: B01A

Ref document number: 112012000005

Country of ref document: BR

ENP Entry into the national phase

Ref document number: 112012000005

Country of ref document: BR

Kind code of ref document: A2

Effective date: 20120102