WO2011072121A2 - Soupape barrière d'insert souterrain à commande mécanique ou hydraulique de cycle de marche de câble de forage et siège d'outils de pose associé - Google Patents

Soupape barrière d'insert souterrain à commande mécanique ou hydraulique de cycle de marche de câble de forage et siège d'outils de pose associé Download PDF

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Publication number
WO2011072121A2
WO2011072121A2 PCT/US2010/059682 US2010059682W WO2011072121A2 WO 2011072121 A2 WO2011072121 A2 WO 2011072121A2 US 2010059682 W US2010059682 W US 2010059682W WO 2011072121 A2 WO2011072121 A2 WO 2011072121A2
Authority
WO
WIPO (PCT)
Prior art keywords
tool
landing nipple
valve
shoulder
passage
Prior art date
Application number
PCT/US2010/059682
Other languages
English (en)
Other versions
WO2011072121A3 (fr
Inventor
Ronald J. Garr
Kevin R. Plunkett
Original Assignee
Baker Hughes Incorporated
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Baker Hughes Incorporated filed Critical Baker Hughes Incorporated
Publication of WO2011072121A2 publication Critical patent/WO2011072121A2/fr
Publication of WO2011072121A3 publication Critical patent/WO2011072121A3/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
    • E21B34/10—Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
    • E21B34/105—Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole retrievable, e.g. wire line retrievable, i.e. with an element which can be landed into a landing-nipple provided with a passage for control fluid
    • 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
    • E21B23/00—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells
    • E21B23/02—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for locking the tools or the like in landing nipples or in recesses between adjacent sections of tubing

Definitions

  • the field of the invention is barrier valves for subterranean use and more particularly such valves that can be run in on wireline and latch to a specific landing nipple and which can be subsequently operated mechanically or hydraulically.
  • String mounted barrier valves are made up with a string when the string is run into a subterranean location. If the valve is hydraulically operated such as with one or more control lines, the control lines are made up and run outside the tubular string until the valve is at its proper location. Barrier valves isolate one part of the wellbore from another against flow in either direction.
  • One type of such hydraulically actuated barrier valve that is run in as part of a string is illustrated in US Publication 20080110632.
  • Insert safety valves can be run into a string and latch into a landing nipple with dogs that extend for support off the existing safety valve where the insert valve runs off a control system of the initial safety valve as illustrated in USP 5,862,865.
  • USP 5,496,044 illustrates an annular chamber in a safety valve in a string that is penetrated by a penetrating tool and an insert safety valve is run into the string mounted safety valve and pressure in the penetrated annular chamber communicates to the insert safety valve to subsequently operate it.
  • barrier valves are not initially needed and could be needed in the future. It is economical in these situations for the well operator to delay the purchase of such expensive items as barrier valves until the time they are actually needed downhole.
  • the present invention allows such flexibility by providing a valve that can be run into a predetermined location or locations and latched into position. These locations are landing nipples that have been put into the string initially at desired locations. Preferably they have unique patterns for a valve latching system to engage only on a desired landing nipple that matches the profile of the latch mechanism that mates with it and is mounted on the barrier valve that is preferably run into the wellbore on wireline.
  • the landing nipple or nipples in the string will already have control lines initially installed with the string in a landing nipple or nipples.
  • the barrier valve hydraulic connections are lined up and in a sealing relation to the control line connections in the landing nipple so that the barrier valve can latch in and immediately be operated hydraulically with the control lines.
  • a wireline tool can be run in to open communication to the landing nipple before the barrier valve is run in.
  • a unique landing nipple has spaced control line connections and external control lines running from the surface to those connections.
  • a hydraulic barrier valve such as a ball valve, is run in to a predetermined landing nipple and latched in position where the control line connections are in the right locations to operate the valve.
  • a landing nipple with a latching groove alone can be used with a wireline run barrier valve to latch it into position at the desired location.
  • a shifting tool is used to operate the mechanically actuated valve. More than one valve can be positioned or used in the string at a time or the same valve can also be positioned at different landing nipples at different times to meet the production needs of the well operator.
  • FIG. 1 shows a mechanically operated barrier valve landed in its associated landing nipple and locked to it;
  • FIG. 2 is a close up view of the mechanically operated valve of
  • FIG. 1 A first figure.
  • FIG. 3 shows a hydraulically operated valve and associated landing nipple locked together
  • FIG. 4 is a close up view of the valve shown in FIG. 3 ;
  • FIG. 5 is a close up view at the upper control line connection of the landing nipple and how the landed valve takes pressure from the connection to its operating piston;
  • FIG. 6 is the view of FIG. 5 except at a lower control line connection.
  • FIG. 1 illustrates a mechanically operated barrier valve 10 that is delivered through a string (not shown) into a landing nipple 12 by a wireline 14 that is schematically illustrated.
  • a groove 16 is located in the nipple 12 so that when the valve 10 no goes in the nipple 12 the dogs 18 will line up with the groove 16 and a sleeve 20 can be shifted to back up the dogs 18 into the groove 16 for support of the valve 10.
  • the schematically illustrated wireline 14 can include a jar tool that shifts sleeve 20 into the FIG. 1 position to put surface 22 behind the dogs 18 so that they are firmly supported in the groove 16.
  • a snap ring 24 can snap into a groove in the sleeve 20 after sleeve 20 is shifted so as to retain the locked FIG. 1 position of sleeve 20.
  • Valve 10 is sealed on its exterior to the landing nipple 12 by a seal assembly 26.
  • valve 10 is a barrier valve that has a ball 28 between seat sleeves 30 and 32.
  • a through passage 34 runs through valve 10 through sleeves 30 and 32 and ball 28, shown in FIG. 1 in the closed position.
  • An operating sleeve 36 has opposed shoulders 38 and 40.
  • a shifting tool opens the ball 28 by pushing down on shoulder 40 and closes ball 28 by picking up on shoulder 38.
  • the shifting tool is not shown for clarity for the remaining details but can be of a type that is known in the art.
  • Ball cage 44 has an eccentric connection to ball 28 such that translation of the slide assembly 44 rotates the ball 28 on its own axis.
  • Sleeves 30 and 32 do not move but they maintain a seal on the ball as ball 28 rotates on its own axis.
  • the seats on sleeves 30 and 32 are held against the ball 28 by spring 50 as it is rotated 90 degrees in opposed directions by shifting of sleeve 36.
  • Sleeve 48, biased by spring 50 compensates for dimensional tolerances on makeup of the assembly as bottom sub 52 is put on.
  • a downhole tool or tools (not shown) can be connected to bottom sub 52.
  • FIGS. 3-6 illustrate a hydraulically operated embodiment that latches to a landing nipple 54 using a groove 18 as the latching technique and delivery on wireline is the same as shown in FIG. l.
  • the valve components are similar as far as the ball 28 surrounded by seat sleeves 30 and 32.
  • the ball 28 responds to pressure delivered through control lines 56 or 58 that are connected to connections 60 and 62 on the landing nipple 54.
  • Connection 60 leads to a passage 64 that communicates to a piston assembly 66 that pushes on the slide assembly 44 which is the same as in the FIG. 1 embodiment.
  • On the opposite end of slide assembly 44 is a passage 68 that leads to a piston 70 connected on an opposite side of slide assembly 44 than piston 66.
  • Seals 72 and 74 carried by the valve 76 straddle annular chamber 78 so that delivering the valve 76 on wireline 14 and latching it to the landing nipple 54 at groove 16 with dogs 18 allows pressure in control line 56 to be communicated against piston assembly 66 (which can be one or more pistons) for movement of the ball 28 in a first direction while pressure delivered in line 58 goes through passage 68 to chamber 80 that is isolated by seals 74 and 84 carried on the valve 76 so that pressure in line 58 moves piston assembly 70 (which can be one or more pistons) in an opposed direction to piston assembly 66 to return the ball 28 to a second position which preferably is the closed position shown in FIG. 4.
  • the various seals for the chambers 78 and 80 are more easily seen in FIGS. 5 and 6.
  • a landing nipple 54 can be installed within a string with hydraulic lines connected to it at 60 and 64 without a valve 76 being in position until it is later needed.
  • One or more such landing nipples 54 can be installed in a string with different engaging profiles 16 so that more than one valve at a time can be run in with a wireline 14 and landed in the location where the dog assembly 18 matches the profile 16. While a wireline 14 is illustrated, other forms of conveyance of the valve 10 or 76 are envisioned such as coiled tubing or rigid tubing, for example.
  • valve 76 can have the opposite end of a connection that mates with a connection on the inside of the landing nipple 54 simply by insertion and locking the valve 76 into position.
  • landing nipple can also have tapered guide surfaces to ensure proper orientation of the valve 76 when in locks into groove 16 with dogs 18.
  • the pattern of groove 16 can be a unique pattern in a string where there is more than one landing nipple 54 and the dog pattern on a particular valve can match only one pattern to ensure the intended valve 76 lands in the desired landing nipple 54.
  • valve 76 is illustrated as a ball valve that is hydraulically operated with opposed piston assemblies 66 and assemblies 70 the valve type can vary as can the nature of the hydraulic system that actuates it.
  • valve 76 can be a choke or a sliding sleeve or a plug valve or the device need not even be an isolation valve of any type and can be other downhole tools that operate with hydraulic pressure.
  • Such devices can also operate off a single control line with a pressurized onboard reservoir or spring to push in opposed direction than the action created by application of control line pressure.
  • a tool such as a barrier valve
  • the modular style tools that can be run in and locked into position also allow for rapid deployment and avoidance of the expense of installation until the actual need arises.
  • Such drop in tools as barrier valves can be rapidly deployed by wireline or slickline or other conveyance modes as mentioned above and quickly locked into position with an accessory tool to create relative movement to support the dogs 18 in groove 16.
  • the barrier valve 10 can also be simply operated with a shifting tool (not shown) pushing on shoulder 40 or pulling on shoulder 38.
  • This tool can merely shift sleeve 36 for the open and closed positions of ball 28 and it can also be configured to deliver the valve such as 10 or later retrieve it.
  • fishing neck 100 can be grabbed by a running or fishing tool to pull sleeve 20 by breaking a securing device such as a shear pin that allows sleeve 20 to shift so as to remove support for dogs 18 so that the valve 10 can be removed when no longer needed.
  • Valve 76 or other downhole tools delivered in this manner can be removed as just described.

Landscapes

  • 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)
  • Mechanically-Actuated Valves (AREA)
  • Earth Drilling (AREA)
  • Gripping Jigs, Holding Jigs, And Positioning Jigs (AREA)
  • Flexible Shafts (AREA)
  • Escalators And Moving Walkways (AREA)

Abstract

Un siège d'outils de pose unique est doté de connexions de conduite de commande espacées et de conduites de commande extérieures allant de la surface jusqu'à ces connexions. Une soupape barrière hydraulique, telle qu'un robinet à bille, est associée à un siège d'outils de pose prédéterminé et verrouillée à l'emplacement où les connexions de conduite de commande sont aux emplacements corrects pour actionner la soupape. Un siège d'outils de pose doté d'une seule rainure de verrouillage peut être utilisé avec une soupape barrière de cycle de marche de câble de forage pour un verrouillage à un emplacement souhaité. Un outil de changement de marche est utilisé pour actionner la soupape à commande mécanique. Plus d'une soupape peut être placée ou utilisée à la fois dans la rame ou la même soupape peut également être placée au niveau de différents sièges d'outils de pose à différents moments afin de répondre aux besoins de production de l'opérateur du puits.
PCT/US2010/059682 2009-12-10 2010-12-09 Soupape barrière d'insert souterrain à commande mécanique ou hydraulique de cycle de marche de câble de forage et siège d'outils de pose associé WO2011072121A2 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US12/634,887 2009-12-10
US12/634,887 US20110139437A1 (en) 2009-12-10 2009-12-10 Wireline Run Mechanically or Hydraulically Operated Subterranean Insert Barrier Valve and Associated Landing Nipple

Publications (2)

Publication Number Publication Date
WO2011072121A2 true WO2011072121A2 (fr) 2011-06-16
WO2011072121A3 WO2011072121A3 (fr) 2011-09-22

Family

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Family Applications (1)

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PCT/US2010/059682 WO2011072121A2 (fr) 2009-12-10 2010-12-09 Soupape barrière d'insert souterrain à commande mécanique ou hydraulique de cycle de marche de câble de forage et siège d'outils de pose associé

Country Status (2)

Country Link
US (1) US20110139437A1 (fr)
WO (1) WO2011072121A2 (fr)

Cited By (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2013119251A1 (fr) 2012-02-10 2013-08-15 Halliburton Energy Services, Inc. Découplage d'actionneur distant sur un outil de puits
US11136861B2 (en) 2016-03-14 2021-10-05 Halliburton Energy Services, Inc. Mechanisms for transferring hydraulic regulation from a primary safety valve to a secondary safety valve
WO2023239368A1 (fr) * 2022-06-09 2023-12-14 Halliburton Energy Services, Inc. Soupape de sécurité souterraine à couplage magnétique
WO2023239370A1 (fr) * 2022-06-09 2023-12-14 Halliburton Energy Services, Inc. Dispositif d'étranglement souterrain à couplage magnétique

Citations (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4418750A (en) * 1981-10-13 1983-12-06 Otis Engineering Corporation Well tool
US4524830A (en) * 1983-07-05 1985-06-25 Otis Engineering Corporation Landing nipple with subsurface safety valve
US4605070A (en) * 1985-04-01 1986-08-12 Camco, Incorporated Redundant safety valve system and method
US5862865A (en) * 1996-04-18 1999-01-26 Baker Hughes Incorporated Insert gas lift system

Family Cites Families (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3507329A (en) * 1968-11-25 1970-04-21 Harold Brown Co Locating and anchoring device for well tools
US4854387A (en) * 1988-10-11 1989-08-08 Camco, Incorporated Large bore retrievable well safety valve
US4997043A (en) * 1990-05-04 1991-03-05 Camco International Inc. Well landing nipple and method of operation
US5496044A (en) * 1993-03-24 1996-03-05 Baker Hughes Incorporated Annular chamber seal
US7487830B2 (en) * 2002-11-11 2009-02-10 Baker Hughes Incorporated Method and apparatus to facilitate wet or dry control line connection for the downhole environment
US7810571B2 (en) * 2006-11-09 2010-10-12 Baker Hughes Incorporated Downhole lubricator valve

Patent Citations (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4418750A (en) * 1981-10-13 1983-12-06 Otis Engineering Corporation Well tool
US4524830A (en) * 1983-07-05 1985-06-25 Otis Engineering Corporation Landing nipple with subsurface safety valve
US4605070A (en) * 1985-04-01 1986-08-12 Camco, Incorporated Redundant safety valve system and method
US5862865A (en) * 1996-04-18 1999-01-26 Baker Hughes Incorporated Insert gas lift system

Cited By (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2013119251A1 (fr) 2012-02-10 2013-08-15 Halliburton Energy Services, Inc. Découplage d'actionneur distant sur un outil de puits
EP2812524A4 (fr) * 2012-02-10 2016-06-15 Halliburton Energy Services Inc Découplage d'actionneur distant sur un outil de puits
US11136861B2 (en) 2016-03-14 2021-10-05 Halliburton Energy Services, Inc. Mechanisms for transferring hydraulic regulation from a primary safety valve to a secondary safety valve
WO2023239368A1 (fr) * 2022-06-09 2023-12-14 Halliburton Energy Services, Inc. Soupape de sécurité souterraine à couplage magnétique
WO2023239370A1 (fr) * 2022-06-09 2023-12-14 Halliburton Energy Services, Inc. Dispositif d'étranglement souterrain à couplage magnétique
US11851961B1 (en) 2022-06-09 2023-12-26 Halliburton Energy Services, Inc. Magnetically coupled subsurface choke

Also Published As

Publication number Publication date
WO2011072121A3 (fr) 2011-09-22
US20110139437A1 (en) 2011-06-16

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