EP2702236A2 - Soupape anti-retour sensible à l'effondrement - Google Patents

Soupape anti-retour sensible à l'effondrement

Info

Publication number
EP2702236A2
EP2702236A2 EP12720344.6A EP12720344A EP2702236A2 EP 2702236 A2 EP2702236 A2 EP 2702236A2 EP 12720344 A EP12720344 A EP 12720344A EP 2702236 A2 EP2702236 A2 EP 2702236A2
Authority
EP
European Patent Office
Prior art keywords
valve assembly
sleeve member
tubular
fluid communication
piston area
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.)
Withdrawn
Application number
EP12720344.6A
Other languages
German (de)
English (en)
Inventor
Michael Logiudice
Joshua Vernon SYMMS
Brent J. Lirette
Thad Joseph Scott
Lev Ring
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.)
Weatherford Technology Holdings LLC
Original Assignee
Weatherford Lamb 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 Weatherford Lamb Inc filed Critical Weatherford Lamb Inc
Publication of EP2702236A2 publication Critical patent/EP2702236A2/fr
Withdrawn legal-status Critical Current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
    • E21B34/08—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
    • E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
    • E21B21/10—Valve arrangements in drilling-fluid circulation systems
    • E21B21/103—Down-hole by-pass valve arrangements, i.e. between the inside of the drill string and the annulus
    • 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
    • E21B34/10—Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
    • E21B34/101—Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole with means for equalizing fluid pressure above and below the valve
    • 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
    • E21B2200/06—Sleeve valves
    • 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
    • E21B34/10—Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
    • E21B34/102—Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole with means for locking the closing element in open or closed position
    • E21B34/103—Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole with means for locking the closing element in open or closed position with a shear pin

Definitions

  • Embodiments of the invention generally relate to a pressure relief valve assembly. Description of the Related Art
  • Traditional well construction such as the drilling of an oil or gas well, includes a wellbore or borehole being drilled through a series of formations. Each formation, through which the well passes, must be sealed so as to avoid an undesirable passage of formation fluids, gases or materials out of the formation and into the borehole.
  • Conventional well architecture includes cementing casings in the borehole to isolate or seal each formation. The casings prevent the collapse of the borehole wall and prevent the undesired inflow of fluids from the formation into the borehole.
  • each succeeding casing placed in the wellbore has an outside diameter significantly reduced in size when compared to the casing previously installed.
  • the borehole is drilled in intervals whereby a casing, which is to be installed in a lower borehole interval, is lowered through a previously installed casing of an upper borehole interval and then cemented in the borehole.
  • the purpose of the cement around the casing is to fix the casing in the well and to seal the borehole around the casing in order to prevent vertical flow of fluid alongside the casing towards other formation layers or even to the earth's surface.
  • fluids liquids or gases
  • the fluids may flow into the annuli between previously installed casings and cause undesirable pressure differentials across the casings.
  • the fluids may also flow into the annuli between the casings and other drilling or production tubular members that are disposed in the borehole.
  • Some of the casings and other tubulars, such as the larger diameter casings, may not be rated to handle the unexpected pressure increases, which can result in the collapse or burst of a casing or tubular.
  • a valve assembly comprises a tubular mandrel; a sleeve member disposed within the tubular mandrel; and a biasing member disposed within the tubular mandrel and operable to bias the sleeve member against a shoulder of the tubular mandrel.
  • the sleeve member is movable between a closed position where fluid communication is closed between a bore of the valve assembly and a port disposed through the tubular mandrel, and an open position where fluid communication is open between the bore of the valve assembly and the port disposed through the tubular mandrel.
  • a method of controlling fluid communication between an exterior of a wellbore tubular and an interior of the wellbore tubular comprises providing a valve assembly for coupling to the wellbore tubular, wherein the valve assembly includes a tubular mandrel, a sleeve member movably disposed in the tubular mandrel, and a biasing member for biasing the sleeve member into a closed position; and moving the sleeve member to an open position to open fluid communication between the exterior of the wellbore tubular and the interior of the wellbore in response to a pressure differential exceeding a first predetermined value.
  • Figure 1 is a schematic view of a wellbore.
  • Figure 2 is a cross sectional view of a valve assembly in a closed position.
  • Figure 3 is a cross sectional view of the valve assembly in an open position.
  • Figure 1 illustrates a wellbore 5 formed within an earthen formation 80.
  • the walls of the wellbore 5 are reinforced with a plurality of casings 10, 20, 30 of varying diameters that are structurally supported within the formation 80.
  • the casings 10, 20, 30 are fixed within the formation 80 using a sealing material 15, 25, 35, such as cement, which prevents the migration of fluids from the formation 80 into the annuli between the casings 10, 20, 30.
  • One or more tubular members 40, 45 such as drilling or production tubular members, may also be disposed in the wellbore 5 for conducting wellbore operations.
  • An annulus "A” is formed between the casing 10 and the casing 20, and an annulus “B” is formed between the casing 20 and the tubular member 40. It is important to note that the embodiments described herein may be used with other wellbore arrangements and are not limited to use with the wellbore configuration illustrated in Figure 1 .
  • the wellbore 5 may intersect a high pressure zone 50 within the formation 80. Fluids within the high pressure zone 50 are sealed from the annulus A and B by the sealing material 25 that is disposed between the casing 20 and the wellbore 5 wall. In the event that the sealing material 25 is breached or otherwise compromised, pressurized fluids may migrate upward into the annulus A and cause an unexpected pressure increase. The pressure rise may form a pressure differential across the casings 10, 20 that (if unchecked) may result leakage through or burst of casing 10, and/or leakage through or collapse of the casing 20. A valve assembly 100 is provided to relieve the pressure in the annulus A prior to failure of one or both of the casings 10, 20.
  • FIG. 2 illustrates the valve assembly 100 in a closed position.
  • the valve assembly 100 is shown coupled to the casing 20 in Figure 1 , but each of the casings 10, 20, 30 and/or the tubular members 40, 45 may similarly include one or more of the valve assembly 100 as described herein.
  • the valve assembly 100 may be coupled to the casings 10, 20, 30 and/or the tubular members 40, 45 using a threaded connection, a welded connection, and/or other similar connection arrangements.
  • the valve assembly 100 may comprise a top sub 1 10, a bottom sub 120, a sleeve member 130, and a biasing member 140.
  • the bottom sub 120 is coupled to the top sub 1 10, such as by a threaded connection.
  • the top sub 1 10 and the bottom sub 120 may be integrally formed as a single tubular mandrel.
  • the sleeve member 130 is movably disposed within the top sub 1 10, and may be biased against a shoulder 125 or upper end of the bottom sub 120 by the biasing member 140.
  • the biasing member 140 may be a spring or other similar biasing mechanism.
  • the biasing member 140 is also disposed within the top sub 1 10, and may be positioned between the sleeve member 130 and a shoulder 1 13 of the top sub 1 10.
  • a cover member 145 optionally may be provided to secure the biasing member 140 within the top sub 1 10 and to protect the biasing member 140 from interference with any component(s) that pass through the bore 105 of the valve assembly 100.
  • the inner diameters of the top sub 1 10, the bottom sub 120, the sleeve member 130, and/or the cover member 145 may be equal to provide a substantially uniform inner diameter surface throughout the length of the valve assembly 100.
  • the inner diameter of the bore 105 of the valve assembly 100 (including the top sub 1 10, the bottom sub 120, and/or the sleeve member 130) may be substantially equal to or greater than the inner diameter of the casings 10, 20, 30 and/or the tubular members 40, 45 to which it is attached when assembled.
  • the sleeve member 130 is biased into the closed position.
  • sealing members 131 , 132, 133 When in the closed position, sealing members 131 , 132, 133, such as o- rings, close fluid communication between the bore 105 of the valve assembly 100 and the annulus surrounding the valve assembly 100.
  • the sealing members 131 , 132, 133 seal fluid communication to a first port 1 15 and a second port 1 17 that are disposed through the body of the top sub 1 10.
  • the first port 1 15 is sealed on opposite sides by sealing members 131 and 132.
  • the second port 1 17 is sealed on opposite sides by sealing members 132 and 133.
  • An external piston area 139 such as a shoulder portion, is provided on the sleeve member 130 between sealing members 132 and 133 and is in fluid communication with the second port 1 17.
  • An internal piston area 135 is formed by an end of the sleeve member 130, which is in contact with the biasing member 140 and is in fluid communication with the bore 105 of the valve assembly 100.
  • the sleeve member 130 may be initially coupled to the top sub 1 10 and/or the bottom sub 120 by one or more shearable members, such as shear pins 137 illustrated in Figure 2.
  • the shear pins 137 may retain the sleeve member 130 in a closed position to prevent inadvertent actuation of the sleeve member 130 by a component(s), such as a drilling or production string, that is moved through the bore 105 of the valve assembly 100 during a wellbore operation.
  • the shear pins 137 may be sheared by pressurizing the annulus surrounding the valve assembly 100 to force the sleeve member 130 into the open position as described herein.
  • the force required to shear the shear pins 137 may be greater than the force required to subsequently move the sleeve member 130 to the open position.
  • a tool or other downhole device may be lowered into the bore 105 of the valve assembly 100 and into engagement with the sleeve member 130 to apply a force sufficient to shear the shear pins 137.
  • Figure 3 illustrates the valve assembly 100 in the open position, where the bore 105 of the valve assembly 100 is in fluid communication with the annulus surrounding the valve assembly 100 via the first port 1 15.
  • the pressure in the annulus surrounding the valve assembly 100 may generate a force on the external piston area 139 sufficient to overcome the force on the internal piston area 135.
  • the force on the internal piston area 135 may include the force from the biasing member 140, such as a spring force, plus the force generated by any pressure within the bore 105 acting on the internal piston area 135.
  • the force on the external piston area 139 may move the sleeve member 130 to a position such that the first port 1 15 is open to fluid communication with the bore 105 of the valve assembly 100.
  • the sealing member 131 is moved across the first port 1 15 to open fluid communication.
  • the valve assembly 100 may be operable to control fluid communication between the annulus A and the annulus B.
  • the annulus A surrounds the valve assembly 100, and the annulus B is in fluid communication with the bore 105 of the valve assembly 100.
  • Pressure in the annulus A may act on the external piston area 139 via the second port 1 17 to move the sleeve member 130 against the force of the biasing member 140 and any pressure force in the annulus B acting on the internal piston area 135.
  • pressurized fluid may flow from the annulus A to the annulus B through the first port 1 15 of the valve assembly 100.
  • the valve assembly 100 is thus operable to relieve a pressure that may cause burst of a casing exterior to the casing to which the valve assembly 100 is attached, and/or collapse of a casing to which the valve assembly 100 is attached.
  • the biasing member 140 may move the sleeve member 130 back to the closed position where the sealing members 131 , 132 close fluid communication to the first port 1 15.
  • the valve assembly 100 is operable as a one-way valve in that it will permit fluid flow into the bore 105 of the valve assembly 100 but will prevent fluid flow out of the bore 105 via the first port 1 15.
  • the valve assembly 100 is automatically resettable downhole and may be operated multiple times in response to any pressure fluctuations within the wellbore 5.
  • any of the casings 10, 20, 30 and/or the tubular members 40, 45 may each be provided with one or more valve assemblies 100 to allow fluid flow from a surrounding casing or tubular member to an inner casing or tubular member, while preventing fluid flow in the opposite direction.
  • the valve assembly 100 vents off collapse pressure from the outside of the casings 10, 20, 30 and/or tubular members 40, 45 but allows internal pressurization of the casings 10, 20, 30 and/or tubular members 40, 45.
  • a casing 10, 20, 30 and/or tubular member 40, 45 may be provided with multiple valve assemblies 100 that are spaced apart along the length of the casing or tubular member.
  • the valve assemblies 100 may be operable to open and/or close at different pre-determined pressure setting.
  • One or more of the valve assemblies 100 may be operable to open when a first predetermined pressure acts on the external piston area 139, while one or more of the other valve assemblies 100 may be operable to open when a second predetermined pressure acts on the external piston area 139.
  • the first predetermined pressure may be greater than, less than, or equal to the second predetermined pressure.
  • the valve assembly 100 may be operable to open when a pressure differential across the valve assembly 100 exceeds a first predetermined value.
  • the valve assembly 100 may be operable to close when the pressure differential across the valve assembly 100 decreases below a second predetermined value.
  • the first predetermined value may be greater than or equal to the second predetermined value.
  • the valve assembly 100 may include a detent mechanism and/or a collet assembly configured to retain the valve assembly 100 in the open position until the pressure differential across the valve assembly 100 decreases below the second predetermined value.
  • the detent mechanism may include a c-ring coupled to the sleeve member 130 that engages a shoulder of the top sub 1 10. When moved to the open position, the sleeve member 130 may move the c-ring across the shoulder with minimal resistance, but when moved to the closed position, the sleeve member 130 may encounter a greater resistance to move the c-ring across the shoulder.
  • Other detent arrangements may be use with the embodiments described herein.

Landscapes

  • Engineering & Computer Science (AREA)
  • Life Sciences & Earth Sciences (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)
  • Mechanical Engineering (AREA)
  • Safety Valves (AREA)

Abstract

L'invention porte sur un procédé et un appareil pour un ensemble soupape de sûreté de pression. L'ensemble soupape peut être raccordé à un ou plusieurs tubages et/ou éléments tubulaires régler la communication fluidique entre les deux. L'ensemble soupape est un ensemble soupape unidirectionnelle qui décharge la pression dans un espace annulaire formé entre tubages et/ou éléments tubulaires adjacents pour éviter l'explosion ou l'effondrement des tubages et/ou éléments tubulaires. L'ensemble soupape peut être réarmé en conditions de fond.
EP12720344.6A 2011-04-29 2012-04-27 Soupape anti-retour sensible à l'effondrement Withdrawn EP2702236A2 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US201161481088P 2011-04-29 2011-04-29
PCT/US2012/035589 WO2012149418A2 (fr) 2011-04-29 2012-04-27 Soupape anti-retour sensible à l'effondrement

Publications (1)

Publication Number Publication Date
EP2702236A2 true EP2702236A2 (fr) 2014-03-05

Family

ID=46052897

Family Applications (1)

Application Number Title Priority Date Filing Date
EP12720344.6A Withdrawn EP2702236A2 (fr) 2011-04-29 2012-04-27 Soupape anti-retour sensible à l'effondrement

Country Status (6)

Country Link
US (1) US20120273225A1 (fr)
EP (1) EP2702236A2 (fr)
AU (1) AU2012249426B2 (fr)
BR (1) BR112013027632A2 (fr)
CA (1) CA2834227A1 (fr)
WO (1) WO2012149418A2 (fr)

Families Citing this family (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US10024133B2 (en) 2013-07-26 2018-07-17 Weatherford Technology Holdings, Llc Electronically-actuated, multi-set straddle borehole treatment apparatus

Family Cites Families (16)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US2251977A (en) * 1939-12-23 1941-08-12 Baker Oil Tools Inc Well cementing apparatus
US3193016A (en) * 1962-04-30 1965-07-06 Hydril Co Reverse flow tubing valve
US3292706A (en) * 1963-07-26 1966-12-20 Otis Eng Co Fluid pressure responsive valve
US3583481A (en) * 1969-09-05 1971-06-08 Pan American Petroleum Corp Down hole sidewall tubing valve
US4201364A (en) * 1978-07-27 1980-05-06 Otis Engineering Corporation Radially expandable tubular valve seal
US4602684A (en) * 1984-11-13 1986-07-29 Hughes Tool Company Well cementing valve
US5156220A (en) * 1990-08-27 1992-10-20 Baker Hughes Incorporated Well tool with sealing means
US6230811B1 (en) * 1999-01-27 2001-05-15 Halliburton Energy Services, Inc. Internal pressure operated circulating valve with annulus pressure operated safety mandrel
GB9905279D0 (en) * 1999-03-08 1999-04-28 Petroline Wellsystems Ltd Downhole apparatus
GB0424255D0 (en) * 2004-11-02 2004-12-01 Caledyne Ltd Safety valve
US7467664B2 (en) * 2006-12-22 2008-12-23 Baker Hughes Incorporated Production actuated mud flow back valve
US7918275B2 (en) * 2007-11-27 2011-04-05 Baker Hughes Incorporated Water sensitive adaptive inflow control using couette flow to actuate a valve
US7669661B2 (en) * 2008-06-20 2010-03-02 Baker Hughes Incorporated Thermally expansive fluid actuator devices for downhole tools and methods of actuating downhole tools using same
CA2653254C (fr) * 2009-02-09 2011-11-29 Schlumberger Canada Limited Manchon coulissant mecanique
US8646532B2 (en) * 2010-05-14 2014-02-11 Baker Hughes Incorporated Valve, valving device and method
US8544554B2 (en) * 2010-12-14 2013-10-01 Halliburton Energy Services, Inc. Restricting production of gas or gas condensate into a wellbore

Also Published As

Publication number Publication date
US20120273225A1 (en) 2012-11-01
AU2012249426A1 (en) 2013-11-14
WO2012149418A3 (fr) 2013-10-24
BR112013027632A2 (pt) 2017-02-14
CA2834227A1 (fr) 2012-11-01
AU2012249426B2 (en) 2016-02-04
WO2012149418A2 (fr) 2012-11-01

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