EP1325211B1 - Dispositif de verrouillage dilatable pour soupape de surete souterraine - Google Patents

Dispositif de verrouillage dilatable pour soupape de surete souterraine Download PDF

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Publication number
EP1325211B1
EP1325211B1 EP01974458A EP01974458A EP1325211B1 EP 1325211 B1 EP1325211 B1 EP 1325211B1 EP 01974458 A EP01974458 A EP 01974458A EP 01974458 A EP01974458 A EP 01974458A EP 1325211 B1 EP1325211 B1 EP 1325211B1
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EP
European Patent Office
Prior art keywords
sleeve
valve
wellbore
expanded
expansion tool
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.)
Expired - Lifetime
Application number
EP01974458A
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German (de)
English (en)
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EP1325211A1 (fr
Inventor
Thomas G. Hill
Robert James Anderson
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Weatherford Lamb Inc
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Weatherford Lamb Inc
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Publication of EP1325211A1 publication Critical patent/EP1325211A1/fr
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Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • 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
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/02—Subsoil filtering
    • E21B43/10—Setting of casings, screens, liners or the like in wells
    • E21B43/103—Setting of casings, screens, liners or the like in wells of expandable casings, screens, liners, or the like
    • E21B43/105—Expanding tools specially adapted therefor
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B2200/00—Special features related to earth drilling for obtaining oil, gas or water
    • E21B2200/04—Ball valves
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B2200/00—Special features related to earth drilling for obtaining oil, gas or water
    • E21B2200/05—Flapper valves

Definitions

  • the invention relates to methods and apparatus for locking a wellbore valve in an open position. More particularly, the invention relates to methods and apparatus for permanently locking a subsurface safety valve in an open position through the use of expandable tubulars.
  • redundant safety devices typically include a valve located about 500 feet (152 m) below the ocean mud line sealably connected to the production tubing string through which production fluids pass.
  • the valve typically referred to as a subsurface safety valve, ensures that if the fluid conduit between the ocean floor and the platform is disrupted (by a passing vessel for instance) that the flow of production fluid from the sub-sea well head will be cut off and the ocean will not be contaminated with production fluid. If the subsurface safety valve malfunctions during its operational life, it may become necessary to permanently lock out the valve in an open position. This is particularly necessary when the safety valve has malfunctioned and closed, commonly due to a control line break or hydraulic chamber leak.
  • SCSSV surface controlled subsurface safety valve
  • SCSSVs are required by regulatory agencies in all offshore wells worldwide. SCSSVs may also be used in land wells where the risk of wellhead damage and uncontrolled blowout of the well is high.
  • subsurface safety valves include flapper (as shown in Figure 6), ball (as shown in Figure 7), and annulus type valves.
  • Safety valves are typically actuated by a reciprocating flow tube or choke. In the case of a flapper type valve, the flapper pivots about a hinge to close and block the flow of fluid through the valve.
  • SCSSVs are "normally closed" downhole valves which are operated by pressurized hydraulic fluid in a small diameter control line extending from an actuator integral to the valve to a control panel on the earth's surface. Pressure in the control line exerted by the control panel holds the SCSSV in the open position, permitting fluid to pass through the valve and to the surface of the well for collection. Disruption of that pressure for any reason causes the valve to close. For example, if a control line or hydraulic seal failure occurs, loss of hydraulic pressure causes inadvertent closure of the flapper.
  • Valves including SCSSVs, may be held in an open position by placing a spring metal band which expands from a contracted, run-in position to a radially enlarged locking position adjacent the flapper thereby holding the valve member open.
  • U.S. Pat. No. 4,577,694 which is hereby incorporated by reference, discloses a running tool that holds a metal band spring in the collapsed position for placement in the well. When released, the spring expands into contact with the valve member, thereby holding it in the open position.
  • One disadvantage to a metal band spring is that hydrocarbons flowing past the metal band spring cause eddies and low pressure areas that can cause the spring to inadvertently collapse and flow upward with production. This action can permit the "permanently locked out" SCSSV to inadvertently shut, thereby stopping the flow of hydrocarbons from the well. This results in costly remedial workover operations and lost production.
  • Insertable locking devices for safety valves are also hampered by the physical characteristics of wellbores.
  • Wellbores and inside diameters thereof vary greatly from well to well.
  • the inside diameter of a wellbore may vary at different depths.
  • the "drift" diameter of a wellbore refers to a maximum diameter of a length of bar that will pass unimpeded through the inside diameter of a wellbore. Any insertable locking device must therefore meet limitations in space inherent in a particular wellbore.
  • expandable tubular technology Both slotted and solid tubulars can be expanded in situ to enlarge a fluid path through the tubular and also to fix a smaller tubular within the inner diameter of a larger tubular therearound.
  • Tubulars are expanded by the use of a cone-shaped mandrel or by an expansion tool with expandable, fluid actuated members disposed on a body and run into the wellbore on a tubular string. During expansion of a tubular, the tubular walls are expanded past their elastic limit. Examples of expandable tubulars include slotted screen, joints, packers, and liners.
  • Figures 1a and 1b are perspective and cross-sectional views of an exemplary expansion tool 100 and Figure lc is an exploded view thereof.
  • the expansion tool 100 has a body 102 which is hollow and generally tubular with connectors 104 and 106 for connection to other components (not shown) of a downhole assembly.
  • the connectors 104 and 106 are of a reduced diameter (compared to the outside diameter of the longitudinally central body part 108 of the tool 100), and together with three longitudinal flutes 110 on the central body part 108, allow the passage of fluids between the outside of the tool 100 and the interior of a tubular therearound (not shown).
  • the central body part 108 has three lands 112 defined between the three flutes 110, each land 112 being formed with a respective recess 114 to hold a respective roller 116.
  • Each of the recesses 114 has parallel sides and extends radially from the radially perforated tubular core 115 of the tool 100 to the exterior of the respective land 112.
  • Each of the mutually identical rollers 116 is near-cylindrical and slightly barreled.
  • Each of the rollers 116 is mounted by means of a bearing 118 at each end of the respective roller for rotation about a respective rotational axis which is parallel to the longitudinal axis of the tool 100 and radially offset therefrom at 120-degree mutual circumferential separations around the central body 108.
  • the bearings 118 are formed as integral end members of radially slidable pistons 120, one piston 120 being slidably sealed within each radially extended recess 114.
  • the inner end of each piston 120 ( Figure la) is exposed to the pressure of fluid within the hollow core of the tool 100 by way of the radial perforations in the tubular core 115. In this manner, pressurized fluid provided from the surface of the well, via a tubular, can actuate the pistons 120 and cause them to extend outward and to contact the inner wall of a tubular to be expanded.
  • EP 892 148 discloses a lockout ring which is resiliently compressible. After insertion into a safety valve the ring is permitted to spring back into its uncompressed state.
  • US 4,597,446 discloses a locking system for locking (i.e. positioning) a safety valve in a well.
  • the locking system comprises a split ring into which is screwed a conical ring so as to expand the split ring.
  • a locking assembly for a wellbore valve comprising a cylindrical sleeve insertable into an interior of the valve. After insertion into the valve, the body is expanded into interference with a closing mechanism of the valve, thereby locking the valve in an open position.
  • a method and apparatus for locking out a safety valve in a wellbore in which a tubular, or a lockout sleeve, having an outer diameter substantially equal to or less than a drift diameter of the wellbore and an expansion tool are placed in the wellbore.
  • the safety valve is located and the lockout sleeve and expansion tool are landed adjacent the safety valve. With the valve in an open position, the lockout sleeve and the expansion tool are positioned within an inner diameter thereof.
  • the expansion tool is energized causing extendable members therein to extend radially to contact an inner diameter of the lockout sleeve.
  • the lockout sleeve is expanded into substantial contact with the inner diameter of the safety valve, wherein the inner diameter of the expanded lockout sleeve is substantially equal to or greater than the drift diameter of the wellbore.
  • a method for locking out a safety valve in a wellbore in which a tubular, or lockout sleeve, having an outer diameter substantially equal to or less than a drift diameter of the wellbore and an expansion tool are placed in the wellbore.
  • the lockout sleeve and expansion tool are landed adjacent the safety valve and a flow tube disposed within the safety valve is located. With the valve in an open position, the lockout sleeve and the expansion tool are positioned within an inner diameter thereof.
  • the expansion tool is energized causing extendable members therein to extend radially to contact an inner diameter of the lockout sleeve.
  • the lockout sleeve is expanded into substantial contact with the inner diameter of the safety valve adjacent the flow tube, wherein the inner diameter of the expanded lockout sleeve is substantially equal to or greater than the drift diameter of the wellbore.
  • an apparatus for locking out a safety valve in a wellbore having a tubular, or lockout sleeve, with an outer diameter substantially equal to or less than a drift diameter of the wellbore.
  • the lockout sleeve has one or more surface features.
  • the lockout sleeve is made of a ductile material and the surface features may be slots, holes, ovals, diamonds, perforations, or a combination thereof.
  • an inner diameter of the lockout sleeve is expandable to a diameter substantially equal to or greater than the drift diameter of the wellbore.
  • FIG. 2 is a perspective view of an embodiment of an unexpanded lockout sleeve 10 according to the invention.
  • the lockout sleeve 10 has a generally tubular body having an outer diameter (OD), an inner diameter (ID), and a predetermined length L1.
  • the lockout sleeve 10 is preferably made of a ductile material having sufficient properties to resist forces designed to yield the lockout sleeve, yet able to plastically and/or elastically deform during application of such forces to a larger diameter without breaking or rupturing.
  • the lockout sleeve 10 has a plurality of slots 16 formed in its wall 18.
  • the lockout sleeve may be a solid tubular without any surface features or have a single longitudinal slot extending the length (L1) of the sleeve.
  • the slots 16 are preferably arranged in a longitudinal pattern in an overlapping fashion to facilitate expansion.
  • the slots 16 may be any appropriate shape of configuration to enable the lockout sleeve 10 to expand with the application of a radial force.
  • Other surface features include slits, ellipses, ovals, holes, perforations, irregular shapes, such as dog bone slots, or combinations thereof.
  • the outside diameter 12 of the lockout sleeve 10 Prior to expansion of the lockout sleeve, the outside diameter 12 of the lockout sleeve 10 is substantially equal to or less than the maximum diameter that will drift to a desired location in the wellbore. After expansion of the sleeve, the inside diameter 14 of the lockout sleeve 10 is preferably greater than or equal to the drift diameter of the wellbore.
  • FIG. 3 is a perspective view of an embodiment of an expanded lockout sleeve 10 according to the present invention.
  • the expanded slots 16 form a diamond shape as the lockout sleeve 10 is expanded.
  • the expansion tool 100 is lowered into the wellbore (not shown) to a predetermined position and thereafter pressurized fluid is provided in the run-in tubular 130.
  • some portion of the fluid is passed through an orifice or some other pressure increasing device and into the expansion tool 100 where the fluid urges the rollers 116 outwards to contact the wall of the tubular, or lockout sleeve 10, therearound.
  • the expansion tool 100 exerts forces against the wall of the lockout sleeve 10 therearound while rotating and, optionally, moving axially within the wellbore. The result is the lockout sleeve is expanded past its elastic limits along at least a portion of its outside diameter. Gravity and the weight of the components urges the expansion tool 100 downward in the wellbore even as the rollers 116 of the expander tool 100 are actuated. The expansion can also take place in a "bottom up" fashion by providing an upward force on the run-in tubular string. A tractor (not shown) may be used in a lateral wellbore or in some other circumstance when gravity and the weight of the components are not adequate to cause the actuated expansion tool 100 to move downward along the wellbore.
  • the run-in string of tubulars may include coiled tubing and in that instance, a mud motor may be utilized adjacent the expansion tool to provide rotational force to the tool.
  • the structure of mud motors is well known.
  • the mud motor can be a positive displacement Moineau-type device and includes a lobed rotor that turns within a lobed stator in response to the flow of fluids under pressure in the coiled tubing string.
  • the mud motor provides rotational force to rotate the expansion tool in the wellbore while the rollers are actuated against an inside surface of a tubular therearound.
  • the run-in string may be replaced by wire (or e-line) line providing electrical energy to an electrical motor and also having the strength to hold the weight of the appartus in the wellbore.
  • the electrical motor runs a downhole pump providing a source of pressurized fluid to an expander tool, tractor and/or a mud motor.
  • Figure 4 is a section view of a flapper section 34 of a subsurface safety valve 39 having an expansion tool 100 and an unexpanded lockout sleeve 10 disposed therein.
  • the lockout sleeve 10 and expansion tool 100 are disposed on the end of a run-in string 130, or coil tubing, which may be used to provide hydraulic fluid to the expansion tool 100.
  • the lockout sleeve 10 and expansion tool 100 are shearably connected and are placed in the wellbore as an assembly. The assembly is lowered to a desired location within the safety valve 39.
  • the flapper section 34 of the safety valve 39 rotates about a hinge pin 36 (shown in an open position).
  • the flapper section 34 is opened by the downward force of the assembly on the flapper section 34. Fluid pressure to actuate the rollers 116 of the expansion tool 100 is provided from the surface of the well through the run-in string 130. The rollers 116 are then actuated and extended radially outward to contact the inner diameter 14 of the lockout sleeve 10. The lockout sleeve 10 is then expanded into substantial contact with the inner diameter of the safety valve 39.
  • Figure 5 is a section view of the embodiment shown in Figure 4, wherein the lockout sleeve 10 is expanded into substantial contact with an inner diameter of the safety valve 39.
  • the lockout sleeve 10 in its expanded condition is substantially greater than or equal to the smallest inner diameter of the safety valve 39 or a tubular (not shown) disposed between the safety valve 39 and the wellbore. This allows the locked out safety valve 39 to maintain its full open inner diameter and ensure that no flow capacity is lost with the addition of the lockout sleeve.
  • FIG. 6 is a section view of a flapper type surface controlled subsurface safety valve 30, having an expanded lockout sleeve 10 disposed therein.
  • Hydraulic fluid is provided to the safety valve 30 via a control line 34 operated by a control panel 32 on the earth's surface.
  • a valve operator 35 such as a rod piston, moves downward in response to increasing fluid pressure in the control line 34.
  • a flow tube 40 moves downward in tandem with the movement of the valve operator 35, thereby opening the flapper 34.
  • a return means 38 such as a spring, a gas charge, or a combination thereof, biases the safety valve 30 in the closed position by acting to urge the flow tube 40 upwards, opposing the force of hydraulic pressure.
  • FIG. 7 is a section view of a ball type surface controlled subsurface safety valve, having an expanded tubular according to the invention disposed therein.
  • a valve operator 35 such as an annular piston, moves downward in response to increasing fluid pressure in the control line 34.
  • a flow tube 40 moves downward in tandem with the movement of the valve operator 35, thereby rotating and opening the ball closure mechanism 44.
  • a return means 38 such as a spring, a gas charge, or a combination thereof, biases the safety valve 31 to the closed position by acting to move the flow tube 40 upwards, opposing the force of hydraulic pressure.
  • Reduced hydraulic fluid pressure in the control line 34 serves to move the flow tube 40 upwards thereby closing the safety valve 30.
  • the lockout sleeve 10 has been expanded into a recess 42 above the flow tube 40, thereby preventing any upward movement of the flow tube 40. This causes the ball 44 to remain in the open position, permanently locking out the safety valve 30.
  • the present invention solves problems associated with wellbore valves, especially subsurface safety valves by providing an easy means to permanently opening the valves without substantially restricting the flow capacity of the valve.

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  • Geology (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Mining & Mineral Resources (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • Physics & Mathematics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Safety Valves (AREA)
  • Pipe Accessories (AREA)
  • Earth Drilling (AREA)
  • Preventing Unauthorised Actuation Of Valves (AREA)

Claims (31)

  1. Ensemble de verrouillage (10) pour une soupape de puits de forage (39), comprenant:
    une douille de blocage (10) comportant un corps globalement tubulaire (10), la douille pouvant être insérée dans un corps de soupape lorsqu'elle n'est pas élargie,
       caractérisé en ce que la douille est expansible au moyen d'un outil d'expansion (100) et est construite et configurée pour interférer avec un mécanisme de fermeture (34) du corps de soupape lorsqu'elle est élargie au moyen dudit outil d'expansion.
  2. Ensemble de verrouillage selon la revendication 1, dans lequel la douille comprend des parois comportant au moins une ouverture (16) en leur sein.
  3. Ensemble de verrouillage selon la revendication 2, dans lequel l'au moins une ouverture est en forme de fente avant l'expansion et est en forme de losange après l'expansion de la douille.
  4. Ensemble de verrouillage selon la revendication 2 ou 3, dans lequel l'au moins une ouverture facilite l'expansion de la douille.
  5. Ensemble de verrouillage selon l'une quelconque des revendications précédentes, comprenant en outre un moyen pour élargir les parois (18) de la douille à l'aide d'une force radiale vers l'extérieur.
  6. Ensemble de verrouillage selon l'une quelconque des revendications précédentes, dans lequel la douille élargie est configurée pour entrer en contact avec le mécanisme de fermeture.
  7. Ensemble de verrouillage selon l'une quelconque des revendications 1 à 5, dans lequel la douille élargie n'entre pas en contact avec le mécanisme de fermeture.
  8. Ensemble de verrouillage selon l'une quelconque des revendications 1 à 7, dans lequel la douille a un diamètre extérieur initial sensiblement égal ou inférieur à un diamètre de dérive du puits de forage.
  9. Ensemble selon la revendication 8, dans lequel un diamètre intérieur de la douille est expansible à un diamètre sensiblement égal ou supérieur au diamètre de dérive du puits de forage.
  10. Ensemble selon l'une quelconque de la revendication 8 ou 9, dans lequel la douille comprend un matériau ductile.
  11. Ensemble selon la revendication 8, 9 ou 10, dans lequel la douille est formée de façon à faciliter son expansion.
  12. Ensemble selon la revendication 11, dans lequel la douille comprend un, une ou plusieurs gorges, fentes, trous, ovales, losanges, perforations, ou l'une de leurs combinaisons.
  13. Ensemble selon l'une quelconque des revendications 1 à 12, dans lequel la douille de blocage (10) est configurée pour être élargie au-delà de sa limite élastique par ledit outil d'expansion (100).
  14. Système comprenant un ensemble de verrouillage selon l'une quelconque des revendications 1 à 13, et outil d'expansion pour élargir la douille.
  15. Procédé de verrouillage d'une soupape de puits de forage (39) dans une position ouverte, le procédé comprenant les étapes consistant à:
    insérer une douille de blocage (10) ayant un corps globalement tubulaire (10) à l'intérieur de la soupape;
       caractérisé par l'étape consistant à:
    élargir la douille à l'intérieur au moyen d'un outil d'expansion (100) de sorte que la douille élargie interfère avec un mécanisme de fermeture (34) de la soupape, verrouillant ainsi la soupape dans une position ouverte.
  16. Procédé selon la revendication 15, comprenant en outre l'étape consistant à ouvrir la soupape avant l'insertion de la douille.
  17. Procédé selon la revendication 15 ou 16, dans lequel l'outil d'expansion comprend des éléments s'étendant vers l'extérieur (116,120) actionnés par un fluide.
  18. Procédé selon la revendication 17, dans lequel la douille est élargie par la pression radiale des éléments sur une surface intérieure (14) de la douille.
  19. Procédé selon la revendication 17 ou 18, dans lequel chaque élément comprend un galet (116).
  20. Procédé selon l'une quelconque des revendications 15 à 19, dans lequel la douille est élargie de telle sorte qu'elle entre en contact avec le mécanisme de fermeture.
  21. Procédé selon l'une quelconque des revendications 15 à 19, dans lequel la douille est élargie de telle sorte qu'elle n'entre pas en contact avec le mécanisme de fermeture.
  22. Procédé selon l'une quelconque des revendications 15 à 21, dans lequel la soupape est une soupape à battant.
  23. Procédé selon l'une quelconque des revendications 15 à 21, dans lequel la soupape est une soupape à bille.
  24. Procédé selon la revendication 15, dans lequel la soupape est une soupape de sûreté, le procédé comprenant les étapes consistant à :
    placer la douille dans le puits de forage;
    placer l'outil d'expansion dans le puits de forage;
    déposer la douille et l'outil d'expansion à proximité de la soupape de sûreté;
    positionner la douille et l'outil d'expansion à l'intérieur d'un diamètre intérieur de la soupape de sûreté;
    activer l'outil d'expansion et amener les éléments extensibles à l'intérieur de celui-ci à s'étendre radialement pour entrer en contact avec un diamètre intérieur de la douille; et
    élargir la douille en contact substantiel avec le diamètre intérieur de la soupape de sûreté.
  25. Procédé selon la revendication 24, dans lequel la douille est élargie à un diamètre sensiblement égal ou supérieur au diamètre de dérive du puits de forage.
  26. Procédé selon la revendication 24 ou 25, dans lequel la soupape de sûreté est ouverte mécaniquement avant de positionner la douille et l'outil d'expansion à l'intérieur du diamètre intérieur de la soupape de sûreté.
  27. Procédé selon la revendication 24, 25 ou 26, dans lequel la douille et l'outil d'expansion sont placés dans le puits de forage sur un train de rodage de tubulaires (130).
  28. Procédé selon la revendication 27, dans lequel le train de rodage de tubulaires est une colonne de production en serpentin.
  29. Procédé selon l'une quelconque des revendications 24 à 28, comprenant en outre l'étape consistant à positionner un tube d'écoulement (40) disposé dans la soupape, dans lequel la douille est élargie pour entrer en contact substantiel avec le diamètre intérieur de la soupape de sûreté à proximité du tube d'écoulement.
  30. Procédé selon l'une quelconque des revendications 24 à 29, dans lequel la douille a un diamètre extérieur initial sensiblement égal ou inférieur à un diamètre de dérive du trou de forage.
  31. Procédé selon l'une quelconque des revendications 15 à 30, dans lequel l'expansion de la douille (10) comprend l'expansion de la douille au-delà de sa limite élastique par ledit outil d'expansion (100).
EP01974458A 2000-10-11 2001-10-08 Dispositif de verrouillage dilatable pour soupape de surete souterraine Expired - Lifetime EP1325211B1 (fr)

Applications Claiming Priority (5)

Application Number Priority Date Filing Date Title
US23950600P 2000-10-11 2000-10-11
US239506P 2000-10-11
US09/903,753 US20020040788A1 (en) 2000-10-11 2001-07-12 Expandable lockout apparatus for a subsurface safety valve and method of use
US903753 2001-07-12
PCT/GB2001/004473 WO2002031315A1 (fr) 2000-10-11 2001-10-08 Dispositif de verrouillage dilatable pour soupape de surete souterraine

Publications (2)

Publication Number Publication Date
EP1325211A1 EP1325211A1 (fr) 2003-07-09
EP1325211B1 true EP1325211B1 (fr) 2005-12-28

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EP01974458A Expired - Lifetime EP1325211B1 (fr) 2000-10-11 2001-10-08 Dispositif de verrouillage dilatable pour soupape de surete souterraine

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US (1) US20020040788A1 (fr)
EP (1) EP1325211B1 (fr)
AU (1) AU2001293973A1 (fr)
CA (1) CA2425418C (fr)
DE (1) DE60116349D1 (fr)
WO (1) WO2002031315A1 (fr)

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US6684958B2 (en) * 2002-04-15 2004-02-03 Baker Hughes Incorporated Flapper lock open apparatus
GB0215659D0 (en) * 2002-07-06 2002-08-14 Weatherford Lamb Formed tubulars
US6991040B2 (en) * 2002-07-12 2006-01-31 Weatherford/Lamb, Inc. Method and apparatus for locking out a subsurface safety valve
US7137452B2 (en) * 2002-09-25 2006-11-21 Baker Hughes Incorporated Method of disabling and locking open a safety valve with releasable flow tube for flapper lockout
US7195072B2 (en) * 2003-10-14 2007-03-27 Weatherford/Lamb, Inc. Installation of downhole electrical power cable and safety valve assembly
US7392849B2 (en) * 2005-03-01 2008-07-01 Weatherford/Lamb, Inc. Balance line safety valve with tubing pressure assist
US8113286B2 (en) * 2006-11-09 2012-02-14 Baker Hughes Incorporated Downhole barrier valve
US7810571B2 (en) * 2006-11-09 2010-10-12 Baker Hughes Incorporated Downhole lubricator valve
US8225871B2 (en) * 2006-11-09 2012-07-24 Baker Hughes Incorporated Bidirectional sealing mechanically shifted ball valve for downhole use
CA2616055C (fr) * 2007-01-03 2012-02-21 Weatherford/Lamb, Inc. Systeme et methodes d'expansion tubulaire
US9187988B2 (en) * 2012-05-31 2015-11-17 Weatherford Technology Holdings, Llc Compliant cone system
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Also Published As

Publication number Publication date
WO2002031315A1 (fr) 2002-04-18
EP1325211A1 (fr) 2003-07-09
CA2425418C (fr) 2006-05-09
DE60116349D1 (de) 2006-02-02
CA2425418A1 (fr) 2002-04-18
AU2001293973A1 (en) 2002-04-22
US20020040788A1 (en) 2002-04-11

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