WO2014193405A1 - Ensemble obturateur à bille activé dans l'espace annulaire - Google Patents

Ensemble obturateur à bille activé dans l'espace annulaire Download PDF

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Publication number
WO2014193405A1
WO2014193405A1 PCT/US2013/043580 US2013043580W WO2014193405A1 WO 2014193405 A1 WO2014193405 A1 WO 2014193405A1 US 2013043580 W US2013043580 W US 2013043580W WO 2014193405 A1 WO2014193405 A1 WO 2014193405A1
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WO
WIPO (PCT)
Prior art keywords
aabva
ball
housing
ball valve
valve piston
Prior art date
Application number
PCT/US2013/043580
Other languages
English (en)
Inventor
Peter D.W. INGLIS
Original Assignee
Halliburton Energy Services, 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 Halliburton Energy Services, Inc. filed Critical Halliburton Energy Services, Inc.
Priority to PCT/US2013/043580 priority Critical patent/WO2014193405A1/fr
Publication of WO2014193405A1 publication Critical patent/WO2014193405A1/fr

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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
    • E21B34/08—Valve arrangements for boreholes or wells in wells responsive to flow or pressure of the fluid obtained
    • 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
    • E21B34/063—Valve or closure with destructible element, e.g. frangible disc
    • 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
    • E21B2200/00—Special features related to earth drilling for obtaining oil, gas or water
    • E21B2200/04—Ball valves

Definitions

  • a wellbore servicing tool comprising a housing generally defining an axial flowbore and comprising an exterior housing portion and an interior housing portion, a medial chamber generally defined by the exterior housing portion and the interior housing portion, and a first port providing a route of fluid communication from the exterior of the housing to the medial chamber, a ball positioned within the axial flowbore of the housing, wherein the ball is transitional between a first orientation and a second orientation relative to a rotational axis, wherein when the ball is in the first orientation, the ball disallows a route of fluid communication through the axial flowbore, and wherein when the ball is in the second orientation, the ball allows a route of fluid communication through the axial flowbore, and a ball valve piston operably coupled to the ball and slidably positioned within the medial chamber of the housing so as to be transitional from a first position to a second position with respect to the housing upon the application of a fluid pressure of at least a pressure threshold to the ball valve
  • a wellbore servicing method comprising the steps of providing an annulus activated ball valve assembly (AABVA) incorporated within a tubular string disposed within a wellbore in a first configuration, wherein, when the AABVA is in the is in the first configuration, the AABVA disallows a route of fluid communication through an axial flowbore of the tubular string, transitioning the AABVA from the first configuration to a second configuration, wherein transitioning the AABVA from the first configuration to the second configuration comprises applying a fluid pressure to a medial chamber within the AABVA via a route of fluid communication, releasing a fluid pressure applied to the medial within the AABVA via the route of fluid communication, or combinations thereof, wherein the route of fluid communication comprises at least a portion of the axial flowbore of the tubular string, at least a portion of an annular space surrounding the AABVA, and the medial chamber, and wherein, when the AABVA is in the second configuration, the AABVA allows a route of fluid communication through an axial flow
  • a wellbore servicing system comprising a first tubular string disposed within the wellbore, a second tubular string disposed within the first tubular string and having an annulus activated ball valve assembly (AABVA) incorporated therein, wherein the AABVA comprises a housing generally defining an axial flowbore and comprising an exterior housing portion and an interior housing portion, a medial chamber generally defined by the exterior housing portion and the interior housing portion, and a first port providing a route of fluid communication from the exterior of the housing to the medial chamber, a ball positioned within the axial flowbore of the housing, wherein the ball is transitional between a first orientation and a second orientation relative to a rotational axis, wherein when the ball is in the first orientation, the ball disallows a route of fluid communication through the axial flowbore, and wherein when the ball is in the second orientation, the ball allows a route of fluid communication through the axial flowbore, and a ball valve piston operably coupled to the ball and
  • FIG. 1 is a partial cutaway view of an embodiment of an operating environment associated with an annulus activated ball valve assembly
  • FIG. 2 is a cutaway view of an embodiment of an annulus activated ball valve assembly in a first configuration
  • FIG. 3 is a cutaway view of an embodiment of an annulus activated ball valve assembly in a second configuration
  • FIG. 4 is a schematic exploded perspective view of an embodiment of a portion of an annulus activated ball valve assembly.
  • FIG. 5 is a flowchart of an embodiment of a wellbore servicing method employing an annulus activated ball valve assembly.
  • subterranean formation shall be construed as encompassing both areas below exposed earth and areas below earth covered by water such as ocean or fresh water.
  • AABVA annulus activated ball valve assembly
  • the AABVA may be incorporated within a tubular string and may be generally configured so as to selectively allow or disallow a route of fluid communication through the tubular string (e.g., a production string, a completion string, etc.), for example, to selectively provide a barrier to fluid movement and/or a protection barrier so as to substantially reduce the unintended movement of fluid during the performance of a wellbore servicing operation (e.g., a completion string, a subterranean formation stimulation operation, the like, or combinations thereof).
  • a route of fluid communication through the tubular string e.g., a production string, a completion string, etc.
  • a protection barrier e.g., a barrier to fluid movement and/or a protection barrier so as to substantially reduce the unintended movement of fluid during the performance of a wellbore servicing operation (e.g., a completion string, a subterranean formation stimulation operation, the like, or combinations thereof).
  • an AABVA as will be disclosed herein may be configured so as to be transitioned from a configuration in which the AABVA does not allow fluid communication through the tubular string to a configuration in which the AABVA does allow fluid communication through the tubular string upon the application of a pressure of at least a pressure threshold (alternatively, one or more cycles including the application of a pressure and the release of the pressure) to a route of fluid communication comprising at least a portion of an axial flowbore of the tubular string and at least a portion of the annular space surrounding the AABVA and/or the tubular string.
  • the operating environment generally comprises a wellbore 114 that penetrates a subterranean formation 102 for the purpose of recovering hydrocarbons, storing hydrocarbons, disposing of carbon dioxide, or the like.
  • the wellbore 114 may be drilled into the subterranean formation 102 using any suitable drilling technique.
  • a drilling or servicing rig 106 disposed at the surface 104 comprises a derrick 108 with a rig floor 110 through which a tubular string (e.g., a work string, a drill string, a tool string, a casing string or liner, a segmented tubing string, a jointed tubing string, a coiled tubing string, any other suitable conveyance, or combinations thereof) generally defining an axial flowbore may be positioned within or partially within wellbore 114.
  • a tubular string may comprise two or more concentrically positioned strings of pipe or tubing (e.g., a first tubular string may be positioned within a second tubular string).
  • the drilling or servicing rig may be conventional and may comprise a motor driven winch and other associated equipment for lowering the tubular string into wellbore 114.
  • a mobile workover rig, a wellbore servicing unit (e.g., coiled tubing units), or the like may be used to lower the tubular string into the wellbore 114.
  • the tubular string may be utilized in drilling, stimulating, completing, or otherwise servicing the wellbore, or combinations thereof.
  • the wellbore 114 may extend substantially vertically away from the earth's surface over a vertical wellbore portion, or may deviate at any angle from the earth's surface 104 over a deviated or horizontal wellbore portion 118. In alternative operating environments, portions or substantially all of wellbore 114 may be vertical, deviated, horizontal, and/or curved and such wellbore may be cased, uncased, or combinations thereof. In some instances, at least a portion of the wellbore 114 may comprise a casing string 190 that is secured into position against the formation 102 in a conventional manner using cement 122. In the embodiment of FIG. 1, the deviated wellbore portion 118 includes the casing string 190.
  • the wellbore 114 may be partially cased and cemented thereby resulting in a portion of the wellbore 114 being uncased.
  • a portion of wellbore 114 may remain uncemented, but may employ one or more packers (e.g., mechanical and/or swellable packers) to secure the casing string within the wellbore and/or to isolate two or more adjacent portions or zones within wellbore 114.
  • packers e.g., mechanical and/or swellable packers
  • the wellbore servicing system 100 comprises an AABVA 200 incorporated within a production string 150 having an axial flowbore 115 and positioned within an axial flowbore 192 of the casing string 190 disposed within the wellbore 114.
  • the AABVA 200 and/or the production string 150 may employ one or more packers 170 (e.g., mechanical and/or swellable packers) to isolate two or more adjacent portions or zones within the casing string 190.
  • the AABVA 200 and/or the production string 150 may be secured within the casing string 190 via the one or more packers 170.
  • the production string 150 comprises a packer 170 disposed about the production string 150 down-hole (e.g., relatively close to the "toe" of the wellbore 114) of the AABVA 200.
  • the production string 150 may further comprise one or more packers disposed about the production string 150 up-hole (e.g., relatively close to the "heel" of the wellbore 114) of the AABVA 200.
  • the one or more packers 170 are configured to provide a barrier to fluid communication between two or more portions of an annular region 191 formed around the production string 150 (e.g., the annular region between the exterior of the production string 150 and the interior of the casing string 190).
  • FIG. 1 illustrates a wellbore servicing system 100 comprising the AABVA 200 incorporated within a production string 150
  • a similar wellbore servicing system may be similarly incorporated within any other suitable type of string (e.g., a work string, a drill string, a tool string, a segmented tubing string, a jointed tubing string, a casing string or liner, a coiled-tubing string, or any other suitable conveyance, or combinations thereof), working environment, as may be appropriate for a given servicing operation.
  • a work string e.g., a drill string, a tool string, a segmented tubing string, a jointed tubing string, a casing string or liner, a coiled-tubing string, or any other suitable conveyance, or combinations thereof
  • working environment e.g., a work string, a drill string, a tool string, a segmented tubing string, a jointed tubing string, a casing string or liner, a
  • an AABVA 200 may be configured to be actuated while disposed within a wellbore like wellbore 114, for example, so as to be transitioned from a first configuration to a second configuration and/or vice versa, as will be disclosed herein.
  • an embodiment of an AABVA 200 is illustrated in a first configuration.
  • the AABVA 200 is configured to disallow a route of fluid communication via (e.g., through) an axial flowbore 220 of the AABVA 200, as will be disclosed herein.
  • an embodiment of an AABVA 200 is illustrated in a second configuration. In the second configuration, the AABVA 200 is configured to allow a route of fluid communication via (e.g., through) the axial flowbore 220 of the AABVA 200, as will be disclosed herein.
  • the AABVA 200 generally comprises a housing 210, a ball 222, and a ball valve piston 226. While an embodiment of the AABVA 200 is disclosed with respect to FIGS. 2 and 3, one of skill in the art upon viewing this disclosure, will recognize suitable alternative configurations. As such, while embodiments of an AABVA may be disclosed with reference to a given configuration (e.g., AABVA 200 as will be disclosed with respect to FIGS. 2 and 3), this disclosure should not be construed as limited only to such embodiments.
  • the housing 210 may be characterized as a generally tubular body, for example, as illustrated in FIGS. 2 and 3.
  • the housing 210 may be characterized as generally defining the axial flowbore 220.
  • the housing 210 may comprise a unitary structure; alternatively, the housing 210 may be made up of two or more operably connected components.
  • the housing 210 comprises an interior housing portion 210a and an exterior housing portion 210b. In the embodiment of FIGS.
  • the outer housing portion 210b comprises a recess 211 within an inner cylindrical surface thereof, for example, such that when the interior housing portion 210a is coaxially disposed (e.g., secured, via a suitable connection and/or interface) within the exterior housing portion 210b, a medial chamber 216 is at least partially defined between an exterior or outer cylindrical surface of the interior housing portion 210a and the interior or inner cylindrical surface of the exterior housing portion 210b.
  • a medial chamber 216 is at least partially defined between an exterior or outer cylindrical surface of the interior housing portion 210a and the interior or inner cylindrical surface of the exterior housing portion 210b.
  • the medial chamber 216 generally comprises a space (e.g., an annular space or, alternatively, a portion of an annular space) extending between an upper shoulder 211a and a lower shoulder 211b (e.g., of the exterior housing portion 210b).
  • the housing 210 may further comprise one more suitable seals (e.g., an O-ring, a T-seal, a snap ring, a gasket, etc.), for example, disposed at one or more interfaces between the interior housing portion 210a and the exterior housing portion 210b, for example, for the purpose of prohibiting and/or restricting fluid movement via such an interface.
  • the housing 210 may be configured for connection to and/or incorporation within a tubular string, such as the production string 150, for example, the housing 210 may comprise a suitable means of connection to the production string 150.
  • the housing 210 may comprise internally and/or externally threaded surfaces as may be suitably employed in making a threaded connection to the production string 150.
  • an AABVA like AABVA 200, may be incorporated within a production string, like production string 150, by any suitable connection, for example, via one or more quick-connector type connections. Suitable connections to a tubular member will be known to those of skill in the art upon viewing this disclosure.
  • the AABVA 200 may be integrated and/or incorporated with the production string 150 such that the axial flowbore 220 may be in fluid communication with the axial flowbore 115 defined by the production string 150, for example, such that a fluid communicated via the axial flowbore 115 of the production string 150 will flow into and through the axial flowbore 220 of the AABVA 200 (e.g., depending upon the configuration of the AABVA 200, as will be disclosed herein).
  • the housing 210 may be configured to allow one or more pistons (e.g., a piston, for example, a sleeve, such as the ball valve piston 226) to be slidably positioned therein.
  • a piston e.g., a piston, for example, a sleeve, such as the ball valve piston 2266
  • the housing 210 may be configured such that the ball valve piston 226 may be slidably positioned within the medial chamber 216 of the housing 210, or a portion thereof, as will be disclosed herein.
  • a housing of an AABVA 200 may comprise any suitable structure; such suitable structures will be appreciated by those of skill in the art with the aid of this disclosure.
  • the housing 210 may comprise a first set of ports 212.
  • the first ports 212 may be positioned up-hole of the ball 222 and may penetrate and/or extend through the housing 210 (e.g., through the exterior housing portion 210b and the interior housing portion 210a) and, thereby provide a route of fluid communication between the axial flowbore 220 of the housing 210 (e.g., a portion of the axial flowbore above the ball 222) and an exterior of the housing (e.g., the annular region 191). While the embodiment of FIGS.
  • a port or ports or, alternatively, any other suitable route of fluid communication between the axial flowbore 220 and an exterior of the AABVA 200
  • the first ports 212 may be present within a sub-assembly or well tool located generally above (e.g., uphole relative to) the AABVA 200.
  • the first ports 212 may be absent from the housing 210 of the AABVA 200.
  • the housing 210 may further comprise a second set of ports 214.
  • the second ports 214 may be positioned down-hole of (e.g., below) the ball 222 and may be configured to penetrate and/or extend through the exterior housing portion 210b and, thereby provide a route of fluid communication from the exterior of the housing 210 (e.g., the annular region 191) to the medial chamber 216 or a portion thereof of the housing 210. While the embodiment of FIGS.
  • first ports 212 and/or the second ports 214 may comprise only a single first port 212 and a single second port 214 similarly configured.
  • the first ports 212 and/or the second ports 214 may further comprise a destructible member (e.g., a burst disk).
  • the destructible member may be configured to disallow fluid communication via one or more ports (e.g., the first port 212 and/or the second port 214), for example, while running-in and/or positioning the AABVA 200 within the casing string 190 and/or the wellbore 114.
  • the destructible member may be configured to be ruptured or opened, for example, upon experiencing a fluid pressure of at least a lower threshold and, thereby allow fluid communication via the one or more ports (e.g., the first port 212 and/or the second port 214).
  • the first port 212 and/or the second port 214 may further comprise one or more fluidic control devices, for example, a check valve, a metering check valve, a fluid restrictor (e.g., unidirectional or bidirectional flow restrictor), or combinations thereof.
  • the second ports 214 may comprise a combination of fluidic control devices comprising a check valve configured to allow unidirectional fluid communication from the annular region 191 into the medial chamber 216 and a fluid restrictor configured to allow bidirectional fluid communication between the annular region 191 and the medial chamber 216 at a predetermined rate.
  • the ports e.g., the first port 212 and/or the second port 2114 may comprise any other suitable fluid flow control mechanisms and/or configurations as would be appreciated by one of ordinary skill in the art upon viewing this disclosure.
  • the ball valve piston 226 may generally comprise a suitable structure such that the ball valve piston 226 may be movably (e.g., slidably) disposed within the medial chamber 216.
  • the ball valve piston 226 may comprise a cylindrical or tubular structure.
  • the ball valve piston 226 may comprise any suitable cross-sectional shape, for example, so as to be complementary to the cross- sectional shape of the medial chamber 216.
  • the ball valve piston 226 may comprise any suitable combination of operably connected components, as will be appreciated by one of skill in the art upon viewing this disclosure.
  • the ball valve piston 226 may be positioned within the medial chamber 216 such that the medial chamber 216 is divided into at least two sub-chambers.
  • the ball valve piston 226 is positioned within the medial chamber 216 so as to provide a partition between a first sub-chamber 234 and a second sub-chamber 224.
  • FIGS. 1 and 3 the embodiment of FIGS.
  • ball valve piston 226 may also be positioned within the medial chamber 216 such that the second sub-chamber 224 is in fluid communication with the second ports 214 (e.g., the ball valve piston is above and/or uphole relative to the second ports 214), as will be disclosed herein (e.g., via a third sub-chamber, as will also be disclosed herein).
  • the ball valve piston 226 may comprise one more suitable seals (e.g., an O-ring, a T-seal, a snap ring, a gasket, etc.) disposed about the ball valve piston 226, for example, for the purpose of prohibiting and/or restricting fluid movement via an interface between the ball valve piston 226 and the housing 210 (e.g., the interior housing portion 210a and/or the exterior housing portion 210b).
  • the ball valve piston 226 may be configured to provide fluid and/or pressure isolation between adjacent portions of the medial chamber 216.
  • the ball valve piston 226 is configured to provide fluid and/or pressure isolation between the first sub-chamber 234 and the second sub-chamber 224.
  • the ball valve piston 226 may be slidably positioned within the medial chamber 216, for example, between various longitudinal positions with respect to the housing 210.
  • the ball valve piston 226 may be transitional from a first position to a second position with respect to the housing 210 and/or vice versa.
  • the relative longitudinal position of the ball valve piston 226 with respect to the housing 210 may determine the configuration of the AABVA 200.
  • the ball valve piston 226 may interact with the ball 222 to control the orientation of the ball 222 dependent upon the relative longitudinal position of the ball valve piston 226. For example, in FIG.
  • the ball 222 may be in a first orientation or "closed” position and, in FIG. 3, where the ball valve piston 226 is in the second orientation, the ball 222 may be in the second orientation or "open" position.
  • the ball valve piston 226 may be configured to transition from the first position to the second position with respect to the housing 210, as disclosed herein, upon experiencing an application of force (e.g., an application of a fluid pressure).
  • an application of force e.g., an application of a fluid pressure
  • the ball valve piston 226 may be configured such that the application of at least a given magnitude and/or duration of force (e.g., a fluid pressure of at least a lower pressure threshold), for example, onto a downward facing contact surface 226a of the ball valve piston 226, may result in a differential in the force (e.g., as a result of the differential in pressures) applied to the ball valve piston 226 in the direction of the first position and the direction of the second position, thereby causing the ball valve piston 226 to move in the direction of the second position (e.g., in an up-hole direction).
  • a given magnitude and/or duration of force e.g., a fluid pressure of at least a lower pressure threshold
  • a differential in the force e.g., as a result of the differential in pressures
  • the first sub-chamber 234 may be maintained at a pressure less than the pressure which may be applied to the second sub-chamber 224 (e.g., via the second ports, as will be disclosed herein), thereby resulting in such a differential pressure applied to the ball valve piston 226.
  • the first sub- chamber may comprise an "atmospheric chamber.”
  • the first sub-chamber 234 may comprise a vacuum or a compressible fluid.
  • a ball valve piston like the ball valve piston 226 disclosed herein may be configured to transition from the first position to the second position with respect to the housing (e.g., like housing 210) upon experiencing an application of fluid pressure and the subsequent release of that fluid pressure.
  • the ball valve piston may (and/or the AABVA) be configured to transition from the first position to the second position upon experiencing one or more pressure cycles (e.g., two, three, four, or more pressure cycles) including the application of a fluid pressure and the release of that fluid pressure.
  • the second position may be downward relative to the first position.
  • a chamber e.g., like the first sub-chamber 234 may be maintained at a pressure greater than the pressure which may be applied to another chamber (e.g., like the second sub- chamber 224) upon the release of pressure therefrom, for example, so as to result in a differential in force (e.g., as a result of the differential in pressures) applied to the ball valve piston, thereby causing the ball valve piston to move in the direction of the second position (e.g., in the downhole direction).
  • a differential in force e.g., as a result of the differential in pressures
  • an AABVA may further comprise one or more biasing members (e.g., springs), J-slots, or the like, for example, for the purpose of guiding the movement of the ball valve piston 226 with respect to the housing and/or providing a force to move the ball valve piston 226.
  • biasing members e.g., springs
  • J-slots or the like
  • the ball valve piston 226 may be configured so as to be selectively retained within the first position, the second position, or both.
  • the ball valve piston 226 and/or the housing 210 may further comprise one or more slots, grooves, bores, or the like, generally configured to receive a shear-pin, a snap-ring, ratchet teeth, or other like mechanism.
  • the AABVA 200 may further comprise a secondary sleeve 218.
  • the secondary sleeve 218 may generally comprise a structure positioned (e.g., secured and/or fixed) within the medial chamber 216.
  • the secondary sleeve 218 may comprise a cylindrical or tubular structure.
  • the secondary sleeve 218 may comprise any suitable cross-sectional shape, for example, so as to be complementary to the cross-sectional shape of the medial chamber 216.
  • the secondary sleeve 218 may be positioned within the medial chamber 216 so as to further define a third sub-chamber 230.
  • the secondary sleeve 218 is positioned (e.g., secured) within the medial chamber 216 so as to provide a partition between the second sub-chamber 224 and the third sub- chamber 230.
  • the secondary sleeve 218 may be positioned within the medial chamber 216 such that the third sub-chamber 230 is in fluid communication with the second ports 214 and the second sub-chamber 224 is in fluid communication with the second ports 214 via the secondary sleeve 218.
  • the secondary sleeve may 218 comprise at least one flow channel 219 extending longitudinally therethrough.
  • the secondary sleeve 218 comprises flow channels 219 extending through the secondary sleeve 218 generally parallel to the rotational and/or longitudinal axis of the secondary sleeve 218.
  • the flow channel may further comprise one or more fluidic control devices, for example, a check valve, a metering check valve, a fluid restrictor (e.g., unidirectional or bidirectional flow restrictor), or combinations thereof.
  • the flow channels 219 may comprise a combination of fluidic control devices comprising a check valve configured to allow unidirectional fluid communication through the secondary sleeve 218 (e.g., from the third sub-chamber 230 to the second sub-chamber 224) and a fluid restrictor configured to allow bidirectional fluid communication the secondary sleeve 218 at a predetermined rate (e.g., between the third sub-chamber 230 and the second sub-chamber 224).
  • the flow channels 219 may comprise any other suitable fluid flow control mechanisms and/or configurations as would be appreciated by one of ordinary skill in the art upon viewing this disclosure.
  • the secondary sleeve 218 may comprise one more suitable seals (e.g., an O-ring, a T-seal, a snap ring, a gasket, etc.) disposed about the secondary sleeve 218, for example, for the purpose of prohibiting and/or restricting fluid movement via such an interface.
  • the secondary sleeve 218 may be configured to provide fluid and/or pressure isolation between adjacent portions of the medial chamber 216. For example, in the embodiment of FIGS.
  • the secondary sleeve 218 is configured to provide fluid and/or pressure isolation between the third sub-chamber 230 and the second sub-chamber 224 (e.g., such that fluid will only move between the second and third sub-chambers 224 and 230 via the flow channels).
  • a secondary sleeve such as the secondary sleeve 218 illustrated in the embodiment of FIGS. 2 and 3, may be absent.
  • the medial chamber 216 may comprise only two sub- chambers (e.g., like the first sub-chamber 234 and the second sub-chamber 224).
  • the ball 222 may comprise any suitable structure and/or configuration as would be appreciated by those of ordinary skill in the art.
  • the ball 222 may be generally configured as described in U.S. Pat. No. 5,865,246, which is hereby incorporated by reference.
  • the ball 222 generally comprises a spherical structure comprising a communication passage 254 (e.g., a flowbore) extending therethrough which allows fluid communication via the ball 222, when the ball 222 is so- configured, as will be disclosed herein.
  • the ball 222 comprises cylindrical journals (e.g., pegs, rods, etc.) 252 extending outward from opposing ends of the ball 222 along a rotational axis 400, generally perpendicular to the communication passage 254. Additionally or alternatively, the ball 222 may comprise one or more holes (e.g., bores) having cylindrical journals (e.g., like journals 252) disposed therein. Additionally, the ball 222 may comprise radially extending key ways 440 extending radially outward from the cylindrical journals 252, for example, to facilitate the rotation of the ball 222.
  • cylindrical journals e.g., pegs, rods, etc.
  • the ball 222 may comprise one or more holes (e.g., bores) having cylindrical journals (e.g., like journals 252) disposed therein. Additionally, the ball 222 may comprise radially extending key ways 440 extending radially outward from the cylindrical journals 252, for example, to facilitate the rotation of the ball 222.
  • the ball 222 may be rotationally positioned within the AABVA 200, for example, within the flowbore 220 of the AABVA 200.
  • the ball 222 is positioned within the AABVA 200 such that each of the cylindrical journals 252 extends through a slot 445 within the interior housing portion 210a and into or through a bearing 455 or cylindrical bore within the ball valve piston 226. Therefore, in such an embodiment, the ball 222 may be configured so as to be rotatable about the rotational axis 400 (e.g., about the cylindrical journals within the bearing 455), for example, rotatable between a first or "open” orientation and a second or "closed” orientation.
  • the ball 222 when the ball 222 is in the first orientation or "closed" position, the ball 222 is configured to close and/or seal the axial flowbore 220 of the housing 210 thereby prohibiting fluid communication there-through, for example, in that the flow passage 254 through the ball 222 is not in fluid communication with (e.g., is misaligned with respect to) the axial flowbore 220 of the AABVA. Additionally, in the embodiment of FIG.
  • the ball 222 when the ball 222 is configured in the second orientation or "open" position, the ball 222 is configured to allow fluid communication via the communication passage 254 of the ball 222 and the axial flowbore 220 of the housing 210, for example, in that the flow passage 254 through the ball 222 is in fluid communication with (e.g., is aligned with respect to) the axial flowbore 220 of the AABVA 200.
  • the first orientation and the second orientation may be about 90 degrees rotationally apart about the rotational axis 400.
  • the ball 222 may be configured such that, upon the longitudinal movement of the ball valve piston 226 with respect to the housing 210 (e.g., the interior housing portion 210a), the ball 222 may be rotated from the first orientation to the second orientation or from the second orientation to the first orientation.
  • the housing 210 e.g., the interior housing portion 210a
  • the housing 210 further comprises one or more drive pins 450 extending generally radially inward, for example, into the axial flowbore 220.
  • the drive pin 450 extends generally parallel to the rotational axis 400 of the ball 222 and is radially offset from the rotational axis 400.
  • the ball 222 may be positioned within the AABVA 200 such that each of the drive pins 450 extends into/within the radially extending keyways 440, for example, through a bearing 449 which engage the keyways 440.
  • FIG. 4 illustrates a particular embodiment of a ball 222 (e.g., which may be transitioned from a first orientation to a second orientation, for example, so as to selectively disallow/allow fluid communication therethrough), one of skill in the art, upon viewing this disclosure, will appreciate one or more additional or alternative configurations of a ball as may be similarly employed.
  • a ball 222 e.g., which may be transitioned from a first orientation to a second orientation, for example, so as to selectively disallow/allow fluid communication therethrough
  • the ball 222 may comprise one more suitable seals (e.g., an O-ring, a T-seal, a snap ring, a gasket, etc.), for example disposed about one or more surfaces of the ball 222 (or a portion thereof), for example, for the purpose of prohibiting and/or restricting fluid movement via such an interface about such surfaces.
  • suitable seals e.g., an O-ring, a T-seal, a snap ring, a gasket, etc.
  • the AABVA 200 may further comprise a tool interface 228.
  • the tool interface 228 may be configured to engage with a suitable wellbore servicing tool, for example, a shifting tool, a mechanical tool, an obturating member, etc.
  • the tool interface may comprise one or more profiled surfaces and may be configured to engage one or more surfaces of a wellbore servicing tool.
  • the tool interface may comprise one or more grooves, slots, lugs, or the like, generally configured to engage and/or be engaged with a shifting tool (e.g., a mechanically actuated shifting tool).
  • the tool interface 228 may be positioned up-hole of the ball 222 and may be coupled to and/or integrated with the ball valve piston 226, for example, via one or more pins 256 extending through generally longitudinal slots within the interior housing portion 210a.
  • the tool interface may be slidably positionable along an interior surface of the interior housing portion 210a.
  • the tool interface 228 is configured such that a force and/or movement of the tool interface 228 are transferred to the ball valve piston 226, for example, such that movement of the tool interface 228 may similarly transition the ball valve piston 226 between the first position and the second position with respect to the housing 210.
  • the tool interface 228 may be configured to transition the ball valve piston 226 from the first position to the second position upon experiencing an application of force in the up-hole direction (e.g., via a shifting tool as will be disclosed).
  • the tool interface 228 may be configured to transition the ball valve piston 226 from the second position to the first position with respect to the housing 210 upon experiencing an application of force in the down-hole direction.
  • the wellbore servicing method 300 may generally comprise the steps of providing the AABVA (e.g., such as AABVA 200) 302, applying a fluid pressure to the AABVA 304, and communicating a fluid through the axial flowbore (e.g., axial flowbore 220) of the AABVA 306.
  • AABVA e.g., such as AABVA 200
  • axial flowbore e.g., axial flowbore 220
  • an AABVA such as AABVA 200
  • AABVA 200 may be incorporated within and/or coupled to a production string 150, for example, during "run-in” of the production string 150.
  • the production string 150 comprising the AABVA 200 is positioned or "run-in” within the axial flowbore 192 of the casing string 190 and/or another suitable tubular.
  • a similar AABVA 200 may be run into a wellbore having no tubular disposed therein (e.g., an "open-hole").
  • providing the AABVA 302 may comprise isolating one or more adjacent zones and/or securing the production string 150 (e.g., within the casing string 190 or the formation 102) at a given or desirable depth within the wellbore 114 and/or casing string 190.
  • one or more packers 170 positioned down-hole of AABVA 200 may be employed to couple the production string 150 to the casing string 190.
  • the packers 170 are configured to provide fluid and/or pressure isolation between two or more annular regions (e.g., annular regions 191 and 193).
  • one or more additional packers may also be positioned up-hole of the AABVA 200 and, thereby selectively provide fluid and/or pressure isolation between additional annular regions.
  • the AABVA 200 may be configured in the second configuration, such that a fluid and/or pressure (e.g., from a downhole portion of the wellbore 114) is allowed to flow through the axial flowbore of the AABVA 200.
  • a wellbore servicing tool e.g., a shifting tool
  • the wellbore servicing tool may be engaged with the AABVA 200 (e.g., via the tool interface 228).
  • the wellbore servicing tool may be shifted to transition the AABVA 200 from the second configuration to the first configuration.
  • the wellbore servicing tool may engage the tool interface 228 and apply a downward (e.g., a down-hole) force and thereby transition the AABVA 200 to the first configuration, as illustrated in FIG. 2.
  • Transitioning the AABVA 200 from the second configuration to the first configuration thereby provides a barrier to fluid movement and/or a protection barrier between a down-hole portion and an up-hole portion of the production string 150.
  • an AABVA like AABVA 200 may be similarly incorporated within a tubular string (e.g., like the production string 150) and run into the wellbore in the first configuration, thereby providing a barrier to fluid communication through the production string 150 during placement thereof.
  • a fluid pressure may be applied within the axial flowbore 115 of the production string 150.
  • a fluid may be pumped into the production string 150 via one or more pumps, such that the pressure within the AABVA 200 (e.g., within the second sub-chamber 224) reaches at least a lower pressure threshold.
  • the pressure within the AABVA 200 e.g., within the second sub-chamber 2214 reaches at least a lower pressure threshold.
  • a fluid pressure applied to the axial flowbore 115 of the production string 150 is communicated from the axial flowbore 115 through a portion of the axial flowbore 220 of the AABVA 200 and may be diverted from an upper portion of the axial flowbore portion 220a (e.g., a portion of the axial flowbore above the ball 222) into an annular space surrounding the AABVA 200 (e.g., annular region 191) via the first ports 212.
  • the fluid is further communicated from the annular region 191 to the medial chamber 216 (e.g., the second sub-chamber 224) via the second port 214.
  • the medial chamber 216 e.g., the second sub-chamber 224
  • the fluid pressure may be communicated through the second ports 214 into the third sub-chamber 230 and, from the third sub-chamber 230 to the second sub-chamber 224 (e.g., via flow channels 219 within the secondary sleeve 218) so as to apply a force onto the down-hole facing contact surface 226a of the ball valve piston 226.
  • the application of a fluid pressure of at least a pressure threshold to the ball valve piston 226 may yield a force in the direction of the second position with respect to the housing 210.
  • the application of such a fluid pressure may cause the pressure within the second sub- chamber 224 to exceed the pressure within the first sub-chamber 234 thereby resulting in a differential in the force applied to the ball valve piston 226 in the direction towards the second position (e.g., an upward force) and the force applied to the ball valve piston 226 in the direction away from the second position (e.g., a static or downward force), thereby causing the ball valve piston 226 to move in the direction of the second position.
  • a differential in the force applied to the ball valve piston 226 in the direction towards the second position e.g., an upward force
  • the force applied to the ball valve piston 226 in the direction away from the second position e.g., a static or downward force
  • the pressure threshold may be at least about 3,000 p.s.L, alternatively, at least about 4,000 p.s.i., alternatively, at least about 6,000 p.s.i., alternatively, at least about 8,000 p.s.i., alternatively, at least about 10,000 p.s.i., alternatively, at least about 12,000 p.s.i., alternatively, at least about 15,000 p.s.i., alternatively, any suitable pressure about equal to or less than the pressure at which the production string 150 is rated.
  • the hydraulic fluid pressure may be of a sufficient magnitude to exert a force in the direction of the second position sufficient to shear the one or more shear pins.
  • the application of such a hydraulic fluid pressure (e.g., via an application of a fluid pressure) may be effective to transition the ball valve piston 226 from the first position to the second position with respect to the housing 210.
  • transitioning the AABVA 200 from the first configuration to the second configuration may further comprise releasing a pressure applied to the AABVA 200 via the route of fluid communication comprising, for example, the axial flowbore 115 and, optionally, a portion of the axial flowbore 220 of the AABVA 200, an annular space surrounding the AABVA 200 (e.g., annular region 191), and the first ports 212.
  • the pressure may be release such that the pressure applied to the ball valve piston 226 (alternatively, to a component operably coupled to the ball valve piston 226) falls below the pressure threshold, alternatively, below a second, lower pressure threshold.
  • the second or lower pressure threshold may be less than about 500 p.s.L, alternatively, less than about 750 p.s.i., alternatively, less than about 1,000 p.s.i., alternatively, less than about 1,500 p.s.i., alternatively, less than about 2,000 p.s.i., alternatively, less than about 2,500 p.s.i., alternatively, less than about 3,000 p.s.i., alternatively, less than about 4,000 p.s.i., alternatively, less than about 5,000 p.s.i.
  • transitioning the AABVA 200 from the first configuration to the second configuration may comprise one or more pressure cycles, for example, one or more applications of a fluid pressure to the AABVA 200 (e.g., via a route of fluid communication, as disclosed herein), followed by the release of such an application of fluid pressure.
  • transitioning the AABVA 200 from the first configuration to the second configuration may comprise one, two, three, four, five, six, seven, eight, or any suitable number of such pressure cycles.
  • the ball valve piston 226 may continue to move in the direction of the second position with respect to the housing 210 while applying a rotational force onto the ball 222, thereby transitioning the AABVA 200 from the first configuration to the second configuration.
  • the barrier to fluid movement and/or protective barrier between the down-hole portion and the up-hole portion of the production string 150 may no longer be provided and thereby may allow a route of fluid communication between the down-hole portion and the up-hole portion of the production string 150.
  • the wellbore servicing operation may further comprise communicating a wellbore servicing fluid, for example, for the purposes of performing a formation stimulation operation via one or more wellbore servicing tools incorporated within the casing string. Additionally or alternatively, in an embodiment, the wellbore servicing method may further comprise producing a formation fluid (for example, a hydrocarbon, such as oil and/or gas) from the subterranean formation 102 via the wellbore 114.
  • a formation fluid for example, a hydrocarbon, such as oil and/or gas
  • the AABVA 200 may be actuated or further actuated via a shifting tool.
  • a shifting tool may be introduced or reintroduced into the axial flowbore 115 of the production string 150.
  • the wellbore servicing tool may engage the AABVA 200 (e.g., via the tool interface 228).
  • the wellbore servicing tool may be moved relative to the AABVA 200 so as to transition the AABVA 200 from the first configuration to the second configuration.
  • the shifting tool may engage the tool interface 228 and apply a force (e.g., an upward force or, alternatively, a downward force) onto the tool interface 228 and, thereby transitioning the AABVA 200 from the first configuration to the second configuration and allowing fluid communication via the axial flowbore 220 of the AABVA 200.
  • a force e.g., an upward force or, alternatively, a downward force
  • the shifting tool may be moved relative to the AABVA 200 to transition the AABVA 200 from the second configuration to the first configuration, for example, for the purpose of recycling the AABVA 200.
  • the shifting tool may engage the tool interface 228 and apply a force (e.g., a downward force or, alternatively, an upward force) onto the tool interface 228 in the opposite direction and, thereby transitioning the AABVA 200 from the second configuration to the first configuration and disallowing fluid communication via the axial flowbore 220 of the AABVA 200.
  • a force e.g., a downward force or, alternatively, an upward force
  • an AABVA 200 may be advantageously employed to selectively provide a barrier to fluid movement and/or a protective barrier to substantially reduce and/or prevent the potential for the unintended movement of fluid through a tubular string.
  • an AABVA like AABVA 200 enables the remote actuation of a well tool without requiring precise fluid and/or pressure control of both an interior flowpath (e.g., an axial flowbore) and an exterior flowpath of the well tool. Conventional tools, systems, and/or methods may be difficult to use without the use of precise fluid and/or pressure control.
  • conventional remote actuation methods require precise fluid and/or pressure control of both an interior portion and an exterior portion of the well tool to generate a differential pressure and, thereby actuate the well tool.
  • conventional tools, systems, and/or methods may be difficult to control and unreliable for remote actuation of a well tool. Therefore, the methods disclosed herein provide a means by which remotely actuating a well tool only requiring an application of fluid pressure to the axial flowbore of the well tool.
  • a first embodiment which is a wellbore servicing tool comprising:
  • a housing generally defining an axial flowbore and comprising:
  • a medial chamber generally defined by the exterior housing portion and the interior housing portion;
  • a first port providing a route of fluid communication from the exterior of the housing to the medial chamber
  • a ball valve piston operably coupled to the ball and slidably positioned within the medial chamber of the housing so as to be transitional from a first position to a second position with respect to the housing upon the application of a fluid pressure of at least a pressure threshold to the ball valve piston via the second port, upon the release of a fluid pressure applied to the ball valve piston via the second port, or combinations thereof;
  • a second embodiment which is the wellbore servicing tool of the first embodiment, wherein the housing further comprises a second port providing a route of fluid communication between the axial flowbore and an exterior of the housing.
  • a third embodiment which is the wellbore servicing tool of the second embodiment, wherein the second port is positioned up-hole of the ball.
  • a fourth embodiment which is the wellbore servicing tool of any of the first through third embodiments, wherein the first port is positioned down-hole of the ball.
  • a fifth embodiment which is the wellbore servicing tool of any of the first through fourth embodiments, further comprising a secondary sleeve disposed within the medial chamber between the ball valve piston and the first port.
  • a sixth embodiment which is the wellbore servicing tool of any of the fifth embodiment, wherein the secondary sleeve comprises a fluid control device disposed within the secondary sleeve and configured to allow a fluid pressure of at least a lower pressure threshold to be communicated from a first sub-chamber of the medial chamber to a second sub-chamber of the medial chamber.
  • a seventh embodiment which is the wellbore servicing tool of any of the first through sixth embodiments, further comprising a tool interface disposed along a portion of an interior surface of the housing and coupled to the ball valve piston; wherein the tool interface is configured to transition the ball valve piston between the first position and the second position with respect to the housing via an application of force by a shifting tool.
  • An eighth embodiment which is a wellbore servicing method comprising the steps of:
  • AABVA annulus activated ball valve assembly
  • transitioning the AABVA from the first configuration to a second configuration comprises applying a fluid pressure to a medial chamber within the AABVA via a route of fluid communication, releasing a fluid pressure applied to the medial within the AABVA via the route of fluid communication, or combinations thereof,
  • route of fluid communication comprises at least a portion of the axial flowbore of the tubular string, at least a portion of an annular space surrounding the
  • AABVA and the medial chamber
  • the AABVA when the AABVA is in the second configuration, the AABVA allows a route of fluid communication through the axial flowbore of the tubular string; and communicating a fluid through the axial flowbore of the AABVA.
  • a ninth embodiment which is the wellbore servicing method of the eighth embodiment, wherein providing the AABVA further comprises positioning the AABVA within the wellbore in the second configuration and transitioning the AABVA from the second configuration to the first configuration upon positioning the AABVA.
  • a tenth embodiment which is the wellbore servicing method of any of the eighth through ninth embodiments, wherein providing the AABVA further comprises setting one or more packers down-hole relative to the AABVA.
  • An eleventh embodiment which is the wellbore servicing method of the tenth embodiment, further comprising setting one or more packers up-hole relative to the AABVA.
  • a twelfth embodiment which is the wellbore servicing method of any of the eighth through eleventh embodiments, wherein transitioning the AABVA from the first configuration to a second configuration transitions the ball valve piston from a first position to a second position with respect to a housing of the AABVA.
  • a thirteenth embodiment which is the wellbore servicing method of the twelfth embodiment, wherein transitioning the ball valve piston from the first position to the second position with respect to the housing of the AABVA causes a ball to transition from a first orientation to a second orientation with respect to a rotational axis;
  • the ball when the ball is configured in the first orientation, the ball is configured to disallow fluid communication via the axial flowbore of the tubular string;
  • the ball when the ball is configured in the second orientation, the ball is configured to allow fluid communication via the axial flowbore of the tubular string.
  • a fourteenth embodiment which is a wellbore servicing system comprising:
  • AABVA annulus activated ball valve assembly
  • a medial chamber generally defined by the exterior housing portion and the interior housing portion;
  • a first port providing a route of fluid communication from the exterior of the housing to the medial chamber
  • a ball valve piston operably coupled to the ball and slidably positioned within the medial chamber of the housing so as to be transitional from a first position to a second position with respect to the housing upon the application of a fluid pressure of at least a pressure threshold to the ball valve piston via the second port, upon the release of a fluid pressure applied to the ball valve piston via the second port, or combinations thereof;
  • a packer disposed about the second tubular string downhole relative to the AABVA.
  • a fifteenth embodiment which is the wellbore servicing system of the fourteenth embodiment, wherein the housing further comprises a second port providing a route of fluid communication between the axial flowbore and an exterior of the housing.
  • a sixteenth embodiment which is the wellbore servicing system of any of the fourteenth through fifteenth embodiments, further comprising a second packer disposed about the second tubular string uphole relative to the AABVA.
  • a seventeenth embodiment which is the wellbore servicing system of any of the fourteenth through sixteenth embodiments, wherein the AABVA further comprises a tool interface disposed along a portion of an interior surface of the housing and coupled to the ball valve piston.
  • An eighteenth embodiment which is the wellbore servicing system of any of the fourteenth through seventeenth embodiments, wherein the AABVA further comprises a secondary sleeve disposed within the medial chamber between the ball valve piston and the first port.
  • a nineteenth embodiment which is the wellbore servicing system of the eighteenth embodiment, wherein the secondary sleeve comprises a fluid control device disposed within the secondary sleeve and configured to allow a fluid pressure of at least a lower pressure threshold to be communicated from a first sub-chamber of the medial chamber to a second sub-chamber of the medial chamber.
  • R R u +k* (R u -Ri), wherein k is a variable ranging from 1 percent to 100 percent with a 1 percent increment, i.e., k is 1 percent, 2 percent, 3 percent, 4 percent, 5 percent, 50 percent, 51 percent, 52 percent, , 95 percent, 96 percent, 97 percent, 98 percent, 99 percent, or 100 percent.
  • R R u +k* (R u -Ri)
  • k is a variable ranging from 1 percent to 100 percent with a 1 percent increment, i.e., k is 1 percent, 2 percent, 3 percent, 4 percent, 5 percent, 50 percent, 51 percent, 52 percent, , 95 percent, 96 percent, 97 percent, 98 percent, 99 percent, or 100 percent.
  • any numerical range defined by two R numbers as defined in the above is also specifically disclosed.

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  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Taps Or Cocks (AREA)

Abstract

Cette invention concerne un outil, comprenant un boîtier définissant un alésage d'écoulement, une chambre médiane, un premier port assurant la communication fluidique entre l'extérieur du boîtier et la chambre médiane, une bille disposée dans l'alésage d'écoulement axial du boîtier en transition entre une première orientation et une seconde orientation, ladite bille empêchant la communication fluidique à travers l'alésage d'écoulement dans la première orientation et permettant la communication fluidique à travers l'alésage d'écoulement dans la seconde orientation, et un piston transitant entre une première position et une seconde position par l'application d'une pression fluidique sur le piston par l'intermédiaire d'un premier orifice et/ou par la libération de la pression fluidique appliquée sur le piston par l'intermédiaire du premier port, ledit piston étant fonctionnellement relié à la bille de telle manière que, dans la première position, la bille est dans la première orientation et dans la seconde position la bille est dans la seconde orientation.
PCT/US2013/043580 2013-05-31 2013-05-31 Ensemble obturateur à bille activé dans l'espace annulaire WO2014193405A1 (fr)

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WO2016178757A1 (fr) * 2015-05-05 2016-11-10 Weatherford Technology Holdings, Llc Siège de rotule à utiliser dans un trou de forage
WO2017060707A1 (fr) * 2015-10-08 2017-04-13 Welleng Science And Technology Ltd Vanne de fond de trou
WO2018104726A1 (fr) 2016-12-06 2018-06-14 Daliburgh Subsea Ltd Ensemble vanne
WO2019162651A1 (fr) * 2018-02-21 2019-08-29 Weatherford U.K. Limited Appareil de fond de trou
CN110905456A (zh) * 2018-09-18 2020-03-24 中国石油天然气股份有限公司 加压延时投球装置

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US7963339B2 (en) * 2004-10-16 2011-06-21 Enovate Systems Limited Bearing mounted ball valve and method of use
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US4440230A (en) * 1980-12-23 1984-04-03 Schlumberger Technology Corporation Full-bore well tester with hydrostatic bias
US6708946B1 (en) * 1998-09-15 2004-03-23 Expro North Sea Limited Ball valve
US7963339B2 (en) * 2004-10-16 2011-06-21 Enovate Systems Limited Bearing mounted ball valve and method of use
US20100206579A1 (en) * 2009-02-19 2010-08-19 Schlumberger Technology Corporation Fail as is mechanism and method
US20120018172A1 (en) * 2010-06-01 2012-01-26 Smith International, Inc. Liner hanger fluid diverter tool and related methods

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* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2016178757A1 (fr) * 2015-05-05 2016-11-10 Weatherford Technology Holdings, Llc Siège de rotule à utiliser dans un trou de forage
US9708887B2 (en) 2015-05-05 2017-07-18 Weatherford Technology Holdings, Llc Ball seat for use in a wellbore
GB2554277A (en) * 2015-05-05 2018-03-28 Weatherford Tech Holdings Llc Ball seat for use in a wellbore
GB2554277B (en) * 2015-05-05 2019-06-12 Weatherford Tech Holdings Llc Ball seat for use in a wellbore
WO2017060707A1 (fr) * 2015-10-08 2017-04-13 Welleng Science And Technology Ltd Vanne de fond de trou
US10895127B2 (en) 2015-10-08 2021-01-19 Welleng Science And Technology Ltd. Downhole valve
WO2018104726A1 (fr) 2016-12-06 2018-06-14 Daliburgh Subsea Ltd Ensemble vanne
WO2019162651A1 (fr) * 2018-02-21 2019-08-29 Weatherford U.K. Limited Appareil de fond de trou
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CN110905456A (zh) * 2018-09-18 2020-03-24 中国石油天然气股份有限公司 加压延时投球装置

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