WO2017118579A1 - Système de commande de tête de puits - Google Patents

Système de commande de tête de puits Download PDF

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Publication number
WO2017118579A1
WO2017118579A1 PCT/EP2016/082296 EP2016082296W WO2017118579A1 WO 2017118579 A1 WO2017118579 A1 WO 2017118579A1 EP 2016082296 W EP2016082296 W EP 2016082296W WO 2017118579 A1 WO2017118579 A1 WO 2017118579A1
Authority
WO
WIPO (PCT)
Prior art keywords
pressure
moveable member
region
fluid
control system
Prior art date
Application number
PCT/EP2016/082296
Other languages
English (en)
Inventor
Robert Bell
Original Assignee
Ge Oil & Gas Uk Limited
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 Ge Oil & Gas Uk Limited filed Critical Ge Oil & Gas Uk Limited
Publication of WO2017118579A1 publication Critical patent/WO2017118579A1/fr

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
    • E21B34/02—Valve arrangements for boreholes or wells in well heads
    • 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
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/02—Surface sealing or packing
    • E21B33/03—Well heads; Setting-up thereof

Definitions

  • the present invention relates to a pressure control system. More particularly the present invention provides a pressure control system for an oil or gas well.
  • Oil and gas are typically extracted from beneath the Earth's surface by wells.
  • Such wells are typically constructed by drilling a wellbore deep into the ground.
  • a number of concentrically aligned tubular pipes, known as tubings or casings, are installed within the wellbore which penetrate to different depths below ground in order to facilitate the extraction of oil and gas from hydrocarbon producing formations of the Earth's crust.
  • An annular gap is formed between each layer of the casings, each annulus typically containing pressurised fluid which remains within the annulus as a remnant of the drilling process.
  • the central casing is typically known as a production tubing and is used to channel extracted oil from the well to the Earth's surface.
  • the casings are subjected to high external pressures caused by the weight of the Earth's crust pressing on the casings, and therefore the fluid pressures within the annuli are typically regulated to maintain the pressure at or close to the pressure exerted on the casings by the Earth in order to prevent collapse or rupture of the tubes. Furthermore, leakage of fluid between the annuli and/or thermal expansion of the fluids within the annuli may cause the pressure in the annuli to increase, which may cause damage to the well casings, the wellhead, or the components of the treehead.
  • One way of controlling fluid pressure in the annuli is to provide a sacrificial member configured to mechanically rupture once the pressure of the fluid within a particular annulus rises above a rated pressure of the sacrificial member.
  • a burst disk is typically formed by providing a vent path from the annulus in question, often in the form of a conduit of the treehead, and providing a barrier within the vent path, often in the form of a metal disk or diaphragm, to prevent flow of fluid along the vent path.
  • the barrier deforms in response to the increasing pressure until the barrier mechanically ruptures, thus allowing fluid to vent from the annulus.
  • a pressure control system for an oil or gas well comprising: a moveable member moveable between an open configuration in which fluid is permitted to flow from a first region of the well to a second region of the well and a closed configuration in which fluid flow from the first region to the second region is prevented; a biasing member configured to urge the moveable member towards the closed configuration; and a pressure controller, wherein the pressure controller is arranged to control a pressure that acts on the moveable member to urge the moveable member towards the closed configuration.
  • the pressure that is controlled by the pressure controller may be controlled such that the force resulting from the pressure that urges the moveable member towards the closed configuration is smaller than the force that urges the moveable member towards the open configuration.
  • the pressure that acts to urge the moveable member towards the closed configuration and the pressure that acts to urge the moveable member towards the open configuration generally act in substantially opposite directions. As such, the pressures act against one another such that a net force is produced upon the moveable member that acts to urge the moveable member towards the open configuration.
  • the moveable member will move to the further closed configuration when the pressure in the first fluid region exceeds the pressure in the second fluid region by a substantial amount or when the moveable member is no longer urged by the pressure in the second fluid region.
  • the moveable member will move to the further closed configuration when the pressure in the second fluid region is zero or near-zero.
  • the moveable member may move to the further closed configuration when a treehead of the oil or gas well is removed from the well.
  • the moveable member may be configured to substantially cover a second opening of the flow passage when the moveable member is in the further closed configuration.
  • the second opening of the flow passage may be an opening of the cavity.
  • the first region may be in fluid flow communication with an annulus of the oil or gas well.
  • the first region may be in fluid flow communication with an annulus B of the oil or gas well.
  • the pressure control system may further comprise an isolation valve configured to selectively permit fluid flow from the second region to an environment external to the well.
  • the pressure controller may communicate with the isolation valve to selectively actuate the isolation valve.
  • the pressure controller may selectively actuate the isolation valve based upon a pressure sensed by the pressure sensor.
  • the biasing member may be a spring.
  • the biasing member may be for example a compression spring, a tension spring, a torsion spring or a leaf spring.
  • Figure 4 is a schematic view of a closed configuration of a pressure control system for a well according to a first embodiment of the present invention
  • Figure 5 is a schematic view of an open configuration of a pressure control system for a well according to the first embodiment of the present invention
  • FIG. 2 further shows a pressure control system 10, located partially within the hanger portion 401 of the intermediate casing 4 and partially within the treehead 7.
  • the pressure control system 10 comprises a shuttle valve 100 connected to the annulus B via an inlet conduit 101 and to the isolation sleeve 701 via a first portion 102a of an outlet conduit 102.
  • the first portion of the outlet conduit 102a connects to a corresponding second portion 102b of the outlet conduit 102 formed within the isolation sleeve 701.
  • the outlet conduit 102b is fluidly connected to a pressure sensor 103 and to an isolation valve 104 of the treehead 7.
  • the shuttle valve 100 is configured to selectively permit fluid to flow from the annulus B through the inlet conduit 101 and into the first portion of the outlet conduit 102a.
  • the fluid then passes to the second portion of the outlet conduit 102b, and the increase in fluid pressure is sensed by pressure sensor 103.
  • the isolation valve 104 may be opened in response to the increase in pressure, and fluid within the outlet conduit 102b may be vented from the treehead 7 via the isolation valve 104 to restore the pressure within outlet conduit 102b to a required pressure.
  • the components of the pressure control system 10 such as the inlet conduit 101, the shuttle valve 100, and the outlet conduit 102 are located partially within the hanger portion 401, isolation sleeve 701 and treehead 7, some components of the pressure control system 10 may alternatively be located elsewhere within the well 1.
  • isolation valve 104 may be controlled in any suitable manner.
  • the isolation valve 104 may be a hydraulically-actuated valve actuated by a hydraulic control system in response to a pressure reading from the pressure sensor 103.
  • a biasing member 110 is mounted within the cavity 106 and is configured to urge the movable member 105 towards the closed configuration.
  • the biasing member 110 is typically provided in the form of a compression spring located above the moveable member 105 and is arranged to urge the moveable member 105 along the longitudinal axis of the cavity towards the closed configuration.
  • the biasing member 110 may alternatively be provided in the form of a tension spring configured to pull, rather than push, the moveable member 105 towards the closed configuration.
  • the biasing member 110 may be configured to be at least partially compressed when the moveable member 105 is in the closed configuration, such that the biasing member 110 always exerts a force upon the moveable member.
  • the biasing member 110 may be configured to be uncompressed when the moveable member 105 is in the closed configuration, such that the biasing member 1 10 only exerts a force on the movable member 105 once the moveable member 105 is displaced.
  • the threshold pressure required to urge the moveable member 105 to the open configuration is substantially dependent upon the pressure P2 controlled by the isolation valve 104
  • the geometry and materials of the shuttle valve 100 may also affect the threshold pressure.
  • the threshold pressure may be dependent upon: the material properties of the biasing member 1 10 (in particular the spring constant k); the dimensions of the moveable member 105 (in particular the cross- sectional area A); and the position of the opening 109 relative to the uncompressed dimensions of the biasing member 1 10 (in particular the displacement x).
  • each of these properties may vary depending upon the set-up of the particular well 1 , however the values are chosen such that once the pressure PI reaches the threshold pressure, the moveable member 105 will allow fluid flow through the opening 109.
  • the target pressure set by the control module 120 may be set based upon, in particular: the depth of the well 1 ; pressure exerted by the Earth on the tubing 3 and/or casings 4-5, and the geometry of the tubing 3 and casings 4-5.
  • properties of the biasing member that affect the force applied by the biasing member on the moveable member can be varied based upon the difference between the pressure PI of the first fluid region and the pressure P2 of the second fluid region. It will be appreciated that a force applied by a biasing member is generally a factor of the size of the biasing member and a type of the biasing member. Given that the force applied on the moveable member by the biasing member is reduced, the size and type of the biasing member may be varied. It will be understood that the term "size" in relation to the biasing member 110 may refer to an axial length of the biasing member 110 or may refer to a diameter of the biasing member 110.
  • biasing member may additionally be varied based upon the size of the cross-sectional area of the moveable member 105.
  • the force that the biasing member produces to counteract the net force produced on the moveable member 105 by the first and second fluid regions is equal to the product of the pressure differential between PI and P2, and the cross-sectional area of moveable member 105. Therefore, for a given pressure differential, reducing the size of the cross-sectional area of the moveable member 105 will result in a lower resultant force produced on the moveable member 105 by the pressure differential, and therefore a smaller biasing member 100 may be chosen.
  • Figures 6, 7 and 8 show a second embodiment of the pressure control system 10 of the present invention. It will be appreciated that the features of the invention which are common to both the first embodiment and the second embodiment retain the same reference signs.
  • the force applied to the moveable member 105 by the biasing member 110 also decreases as the net force applied by the first and second fluid regions decreases, and therefore the biasing member 110 extends in response to the reduced net force.
  • the biasing member 110 therefore urges the moveable member 105 towards the closed configuration and the first opening 109 is blocked by the moveable member 105 such that further fluid flow from the first fluid region into the fiuid flow passage 108 is prevented.
  • the pressure of the fluid in the second fluid region P2, the threshold pressure, and the mechanical and geometrical properties of the biasing member 110 may be selected so as to minimise the amount of time in which the moveable member 105 is in the open configuration.
  • the biasing member 110 acts to urge the moveable member 105 towards the closed configuration, once a sufficient amount of fluid has been vented from the first fluid region, the moveable member 105 will return to the closed configuration.
  • the moveable member 105 may only uncover a small portion of the second opening 109 of the fluid flow passage before returning to a closed configuration in which the second opening 109 is fully covered by the moveable member 105.
  • the outlet conduit 102 and the second opening 11 1 of the fluid flow passage 108 are positioned such that when the moveable member 105 is in the deadlock configuration both the outlet conduit 102 and the second opening 111 of the fluid flow passage 108 are blocked by the moveable member 105. As such, fluid flow into or out of the outlet conduit 102 and the fluid flow passage 108 is substantially prevented by the moveable member 105.
  • the fluid in the second fluid region when the fluid in the second fluid region is unpressurised it will have a gauge pressure (i.e. the pressure of the fluid relative to the pressure of the environment surrounding the well 1) of zero.
  • the gauge pressure of the fluid in the second fluid region is zero, it will be appreciated that the absolute pressure of the fluid in the second fluid region may be non-zero.
  • the absolute pressure of the fluid in the second fluid region may be atmospheric pressure.
  • the absolute pressure of the fluid in the second fluid region may be dependent upon the depth of the well 1 below sea level.
  • the fluid in the second fluid region is unpressurised, no resultant force is produced upon the moveable member 105 by the fluid in the second fluid region.
  • the only force acting on the moveable member 105 to urge the moveable member 105 towards the closed configuration is the force applied by the biasing member 110.
  • the magnitude of the force applied by the biasing member 110 is small in comparison to the resultant force produced upon the moveable member 105 by the pressure PI of the fluid in the first fluid region.
  • the moveable member 105 is therefore urged against the biasing member 110 by the pressure PI of the fluid in the first fluid region such that the moveable member 105 covers the opening 111 of the fluid flow passage 108 and the outlet conduit 102.
  • the shuttle valve assemblies 100, 200 are further joined by a common outlet conduit 102 such that both shuttle valve assemblies 100, 200 are in fluid flow communication with a pressure sensor 103 and an isolation valve 104.
  • the pressure sensor 103 and isolation valve 104 are operable to control the pressure P2 of the fluid within the outlet conduit 102.

Landscapes

  • 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)
  • Control Of Fluid Pressure (AREA)

Abstract

L'invention concerne un système de commande de pression (10) pour un puits de pétrole ou de gaz, comprenant : un élément mobile (105, 205), mobile entre une configuration ouverte dans laquelle le fluide peut s'écouler d'une première région du puits vers une seconde région du puits et une configuration fermée dans laquelle l'écoulement de fluide de la première région à la seconde région est empêché ; un élément de sollicitation (110, 210) configuré pour solliciter l'élément mobile vers la configuration fermée ; et un régulateur de pression (120), le régulateur de pression étant conçu pour réguler une pression qui agit sur l'élément mobile afin de pousser l'élément mobile vers la configuration fermée.
PCT/EP2016/082296 2016-01-08 2016-12-22 Système de commande de tête de puits WO2017118579A1 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
GB1600340.2 2016-01-08
GB1600340.2A GB2546100A (en) 2016-01-08 2016-01-08 Wellhead control system

Publications (1)

Publication Number Publication Date
WO2017118579A1 true WO2017118579A1 (fr) 2017-07-13

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Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/EP2016/082296 WO2017118579A1 (fr) 2016-01-08 2016-12-22 Système de commande de tête de puits

Country Status (2)

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GB (1) GB2546100A (fr)
WO (1) WO2017118579A1 (fr)

Families Citing this family (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US11459851B2 (en) * 2020-08-25 2022-10-04 Saudi Arabian Oil Company Relieving high annulus pressure using automatic pressure relief system
US11708736B1 (en) 2022-01-31 2023-07-25 Saudi Arabian Oil Company Cutting wellhead gate valve by water jetting
WO2023233139A1 (fr) 2022-05-30 2023-12-07 ADS Services, LLC Système et procédé pour l'intégrité de puits

Citations (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20110114333A1 (en) * 2009-11-17 2011-05-19 Vetco Gray Inc. Casing Annulus Management
US20140231092A1 (en) * 2013-02-21 2014-08-21 Hunting Energy Services, Inc. Annular Pressure Relief System
US20150083434A1 (en) * 2013-09-20 2015-03-26 Weatherford/Lamb, Inc. Annular relief valve

Family Cites Families (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US9915275B2 (en) * 2014-06-19 2018-03-13 Proserv Operations, Inc. Stacked shuttle valve

Patent Citations (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20110114333A1 (en) * 2009-11-17 2011-05-19 Vetco Gray Inc. Casing Annulus Management
US20140231092A1 (en) * 2013-02-21 2014-08-21 Hunting Energy Services, Inc. Annular Pressure Relief System
US20150083434A1 (en) * 2013-09-20 2015-03-26 Weatherford/Lamb, Inc. Annular relief valve

Non-Patent Citations (1)

* Cited by examiner, † Cited by third party
Title
H L SANTOS ET AL: "OTC-26294-MS APB Mitigation Techniques and Design Procedure", OFFSHORE TECHNOLOGY CONFERENCE, 29 October 2015 (2015-10-29), Rio de Janeiro, Brazil, pages 1 - 13, XP055348504 *

Also Published As

Publication number Publication date
GB2546100A (en) 2017-07-12
GB201600340D0 (en) 2016-02-24

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