US20120205123A1 - Tubing Hanger and Methods for Testing and Sealing the Tubing Hanger - Google Patents

Tubing Hanger and Methods for Testing and Sealing the Tubing Hanger Download PDF

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Publication number
US20120205123A1
US20120205123A1 US13/027,321 US201113027321A US2012205123A1 US 20120205123 A1 US20120205123 A1 US 20120205123A1 US 201113027321 A US201113027321 A US 201113027321A US 2012205123 A1 US2012205123 A1 US 2012205123A1
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United States
Prior art keywords
mandrel
tubing hanger
seal
test
tubing
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.)
Abandoned
Application number
US13/027,321
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English (en)
Inventor
Jimmy L. Kennedy
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.)
Petrohawk Properties LP
Original Assignee
Petrohawk Properties LP
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Filing date
Publication date
Application filed by Petrohawk Properties LP filed Critical Petrohawk Properties LP
Priority to US13/027,321 priority Critical patent/US20120205123A1/en
Assigned to PETROHAWK PROPERTIES, LP reassignment PETROHAWK PROPERTIES, LP ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: KENNEDY, JIMMY L.
Priority to PCT/US2012/025126 priority patent/WO2012112612A2/fr
Publication of US20120205123A1 publication Critical patent/US20120205123A1/en
Abandoned legal-status Critical Current

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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
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/02—Surface sealing or packing
    • E21B33/03—Well heads; Setting-up thereof
    • E21B33/04—Casing heads; Suspending casings or tubings 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
    • E21B47/00—Survey of boreholes or wells
    • E21B47/10—Locating fluid leaks, intrusions or movements
    • E21B47/117—Detecting leaks, e.g. from tubing, by pressure testing

Definitions

  • This invention relates to the field of wellbore equipment and more specifically to the field of tubing hangers.
  • Tubing hangers are conventionally located in the tubing head and attached to the topmost tubing joint in the wellhead. Typically, the tubing hanger supports the tubing string weight. The tubing hanger also seals the annulus from the upper wellhead and Christmas tree.
  • Tubing hangers have sealing systems and methods for testing seals. Such sealing systems include a variety of seals.
  • Drawbacks to conventional sealing systems include the use of mud to kill the well, with the sealing system then typically being used. Killing the well with mud may be expensive and may also be dangerous to the wellbore.
  • Further drawbacks include adding a frac valve to the top of the tubing hanger, with frac valves typically increasing costs. Additional drawbacks include inefficiencies in testing the sealing system.
  • Drawbacks to conventional testing methods include inefficiencies and the expense involved in testing the tubing hanger.
  • the tubing hanger assembly includes a tubing hanger body having a mandrel receiving body section, a seal receptacle body section, a tubing receiving body section disposed on the opposing end of the tubing hanger body from the mandrel receiving body section, and wherein the seal receptacle body section is disposed between the mandrel receiving body section and the tubing receiving body section.
  • the tubing hanger assembly also includes an interior bore extending longitudinally through the tubing hanger body.
  • the interior bore includes a mandrel bore disposed within the mandrel receiving body section, a seal receptacle bore disposed within the seal receptacle body section, a valve preparation bore disposed within the tubing receiving body section, a tubing bore disposed within the tubing receiving body section, and wherein the valve preparation bore is disposed between the tubing bore and the seal receptacle bore.
  • the tubing hanger assembly includes a test port. The test port extends through the seal receptacle body section to the seal receptacle bore.
  • the mandrel receiving body section has an upper suspension attachment system.
  • the tubing receiving body section has a tubing attachment system.
  • a method for testing and sealing a tubing hanger that includes attaching a test mandrel to the tubing hanger.
  • the tubing hanger has an interior bore and a test port.
  • the method also includes providing a test seal in the interior bore.
  • the test seal is disposed above the test port.
  • the method includes adding pressure to the interior bore through the test port.
  • the method further includes monitoring the pressure.
  • the method includes removing the test mandrel from the tubing hanger and attaching a production mandrel to the tubing hanger.
  • the method includes providing a seal in the interior bore.
  • the seal has an upper seal and a lower seal. The upper seal is disposed above the test port, and the lower seal is disposed below the test port.
  • FIG. 1 illustrates a side cross sectional view of an embodiment of a tubing hanger with a test port
  • FIG. 2 illustrates a side cross sectional view of an embodiment of a tubing hanger with a test port and test mandrel
  • FIG. 3 illustrates an embodiment of a test mandrel with a sealing system
  • FIG. 4 illustrates a side cross sectional view of an embodiment of a tubing hanger and a production mandrel
  • FIG. 5 illustrates an embodiment of a production mandrel with an upper sealing system and a lower sealing system.
  • FIG. 1 illustrates an embodiment of a tubing hanger 5 having tubing hanger body 115 with interior bore 70 .
  • Tubing hanger body 115 includes mandrel receiving body section 75 , seal receptacle body section 95 , and tubing receiving body section 110 .
  • Interior bore 70 includes valve preparation bore 20 , mandrel bore 60 , tubing bore 65 , and seal receptacle bore 100 .
  • Mandrel receiving body section 75 is configured to receive a mandrel in mandrel bore 60 .
  • Tubing receiving body section 110 is configured to receive tubing in tubing bore 65 .
  • tubing hanger 5 includes mandrel receiving body section 75 having upper suspension attachment system 10 .
  • Upper suspension attachment system 10 is disposed on the interior surface of mandrel receiving body section 75 .
  • Upper suspension attachment system 10 includes any means suitable for connection of a mandrel to mandrel receiving body section 75 .
  • upper suspension attachment system 10 includes upper suspension threads or a notch mechanism.
  • upper suspension attachment system 10 includes upper suspension threads. It is to be understood that upper suspension threads refer to helical or spiral ridges. In an embodiment, the upper suspension threads are left-handed threads.
  • left-handed threads refer to threads that connect to a mandrel when the mandrel is rotated in an anti-clockwise direction to connect the mandrel (i.e., rotate the mandrel to screw the mandrel into mandrel bore 60 ), and that allow the mandrel to be removed when the mandrel is rotated in a clockwise direction (i.e., rotate the mandrel to screw the mandrel out of mandrel bore 60 ).
  • upper suspension attachment system 10 is a notch mechanism.
  • the notch mechanism includes a notch disposed in the interior surface of mandrel receiving body section 75 .
  • the notch may have any sufficient configuration to allow a latch on the mandrel to be disposed in the notch.
  • mandrel receiving body section 75 also includes mandrel stop 120 .
  • Mandrel stop 120 includes any suitable means by which further movement of a mandrel into interior bore 70 is stopped.
  • mandrel stop 120 is a portion of mandrel receiving body section 75 that extends outward from the interior surface of mandrel receiving body section 75 .
  • mandrel stop 120 extends outward at about a 90 degree angle from the interior surface.
  • mandrel stop 120 is disposed on the end of mandrel bore 60 proximate seal receptacle bore 100 .
  • an embodiment of tubing hanger 5 includes seal receptacle body section 95 having test port 15 and seal receptacle bore 100 .
  • Seal receptacle bore 100 is configured to receive a portion of a mandrel (i.e., such as a portion having seals).
  • seal receptacle bore 100 has a smaller inside diameter than mandrel bore 60 .
  • seal receptacle bore 100 has about the same inside diameter as the inside diameter of the portion of interior bore 70 between mandrel stop 120 .
  • Test port 15 is an opening through seal receptacle bore section 95 .
  • Test port 15 extends from the outer surface of seal receptacle body section 95 to the interior surface of seal receptacle body section 95 , which provides an opening from outside of tubing hanger body 115 into seal receptacle bore 100 .
  • Test port 15 may extend through seal receptacle body section 95 at any suitable angle for facilitating testing purposes.
  • test port 15 extends through seal receptacle body section 95 about perpendicular to tubing hanger body 115 .
  • Test port 15 is of a sufficient diameter to allow pressure to be added to seal receptacle bore 100 .
  • seal receptacle body section 95 also includes seal receptacle stop 125 .
  • Seal receptacle stop 125 includes any suitable means by which further movement of a mandrel into interior bore 70 is stopped. Seal receptacle stop 125 is on the opposing end of seal receptacle bore 100 from the end of seal receptacle bore 100 that is proximate mandrel stop 120 . In an embodiment, seal receptacle stop 125 is a portion of seal receptacle body section 95 that extends outward from the interior surface of seal receptacle body section 95 . In some embodiments, seal receptacle stop 125 extends outward at about a 90 degree angle from the interior surface.
  • tubing hanger 5 includes tubing receiving body section 110 having valve preparation bore 20 and tubing bore 65 .
  • Valve preparation bore 20 is configured to receive valves such as back pressure valves. Any suitable back pressure valves may be used.
  • suitable valves include H-type back pressure valves and L-type back pressure valves.
  • an H-type back pressure valve and/or a L-type back pressure valve are disposed in valve preparation bore 20 .
  • the back pressure valves prevent pressure (i.e., back pressure) from moving up tubing hanger 5 (i.e., in the direction in tubing hanger 5 distal to tubing bore 65 ).
  • valve preparation bore 20 has a smaller inside diameter than seal receptacle bore 100 .
  • valve preparation bore 20 has about the same inside diameter as the inside diameter of the portion of interior bore 70 between seal receptacle stop 125 .
  • tubing receiving body section 110 also includes tubing stop 130 .
  • Tubing stop 130 includes any suitable means by which further movement of a tubing into interior bore 70 is stopped.
  • Tubing stop 130 is on the opposing end of valve preparation bore 20 from the end of valve preparation bore 20 that is proximate seal receptacle stop 125 .
  • tubing stop 130 is a portion of tubing receiving body section 110 that extends outward from the interior surface of tubing receiving body section 110 .
  • tubing stop 130 extends outward at about a 90 degree angle from the interior surface.
  • an embodiment of tubing hanger 5 includes tubing receiving body section 110 having tubing attachment system 25 .
  • Tubing attachment system 25 is disposed on the interior surface of the portion of tubing receiving body section 110 in which tubing bore 65 is disposed.
  • Tubing attachment system 25 includes any means suitable for connection of a tubing to tubing receiving body section 110 .
  • tubing attachment system 25 is threads or a notch mechanism.
  • tubing attachment system 25 is threads. It is to be understood that threads refer to helical or spiral ridges.
  • tubing attachment system 25 is a tubing notch mechanism.
  • the tubing notch mechanism includes a notch disposed in the interior surface of tubing receiving body section 110 .
  • the notch may have any sufficient configuration to allow a latch on the tubing to be disposed in the notch.
  • FIG. 2 illustrates an embodiment of tubing hanger 5 in which a test mandrel 30 is attached to tubing hanger body 115 .
  • test mandrel 30 is disposed in mandrel bore 60 and in a portion of seal receptacle bore 100 .
  • test mandrel 30 includes upper test mandrel portion 135 and test mandrel seal portion 140 .
  • upper test mandrel portion 135 has a diameter greater than the diameter of test mandrel seal portion 140 .
  • upper test mandrel portion 135 is disposed in mandrel bore 60 .
  • Suspension attachment system 40 includes any means suitable for connection of test mandrel 30 to mandrel receiving body section 75 .
  • suspension attachment system 40 includes threads or a latch (or alternatively latches). It is to be understood that suspension attachment system 40 includes threads in embodiments in which upper suspension attachment system 10 is upper suspension threads, and suspension attachment system 40 includes a latch in embodiments in which upper suspension attachment system 10 is a notch mechanism.
  • suspension attachment system 40 includes threads. The threads sufficiently match the upper suspension threads to allow rotation of test mandrel 30 and/or tubing hanger body 115 to attach test mandrel 30 to tubing hanger 5 .
  • the threads are left-handed threads. It is to be understood that the left-handed threads (i.e., regarding the threads) refer to threads that connect to tubing hanger body 115 when the test mandrel 30 is rotated in an anti-clockwise direction to connect the test mandrel 30 (i.e., rotate test mandrel 30 to screw test mandrel 30 into mandrel bore 60 ), and that allow test mandrel 30 to be removed from mandrel bore 60 when test mandrel 30 is rotated in a clockwise direction.
  • suspension attachment system 40 is a latch. The latch is suitably configured to be disposed in a notch on the interior surface of mandrel receiving body section 75 .
  • Test mandrel seal portion 140 has sealing system 45 .
  • Sealing system 45 is disposed above test port 15 .
  • Sealing system 45 includes any suitable system for sealing mandrel bore 60 from the pressure provided through test port 15 to seal receptacle bore 100 .
  • sealing system 45 includes any suitable type of elastomeric seal for sealing mandrel bore 60 from the pressure provided through test port 15 to seal receptacle bore 100 .
  • suitable elastomeric seals include o-ring seals, dovetail seals, or any combinations thereof.
  • the elastomeric seal is a dovetail seal.
  • Sealing system 45 may include any suitable number of seals to seal mandrel bore 60 from the pressure provided through test port 15 to seal receptacle bore 100 .
  • sealing system 45 has two elastomeric seals, test mandrel seal 35 and test mandrel seal 35 ′.
  • test mandrel seal 35 ′ provides the seal and holds the pressure, with test mandrel seal 35 providing a back-up seal in case test mandrel seal 35 ′ fails.
  • sealing system 45 includes two elastomeric dovetail seals, test mandrel seal 35 and test mandrel seal 35 ′.
  • sealing system 45 has one elastomeric seal.
  • test mandrel 30 has test mandrel shoulder 145 .
  • Test mandrel shoulder 145 is disposed at about where the diameter of test mandrel 30 is reduced from upper test mandrel portion 135 to the reduced diameter of test mandrel seal portion 140 .
  • Test mandrel shoulder 145 has a sufficient diameter and configuration to prevent further movement of test mandrel 30 into interior bore 70 when test mandrel shoulder 145 contacts mandrel stop 120 .
  • Test mandrel shoulder 145 may have any sufficient configuration to contact mandrel stop 120 and prevent the further movement of test mandrel 30 into interior bore 70 .
  • test mandrel shoulder 145 is about perpendicular to the exterior of upper test mandrel portion 135 and the exterior of test mandrel seal portion 140 .
  • test mandrel 30 has test mandrel internal threads 165 .
  • Test mandrel internal threads 165 facilitate attachment of test mandrel 30 to well equipment such as tubing of the wellhead.
  • Test mandrel internal threads 165 are right-handed threads.
  • right-handed threads refer to threads that connect to a well equipment (i.e., tubing) when the test mandrel 30 is rotated in a clockwise direction to connect the test mandrel 30 (i.e., rotate the test mandrel 30 to screw the test mandrel 30 into the tubing), and that allow the test mandrel 30 to be removed from the tubing when the test mandrel 30 is rotated in an anti-clockwise direction.
  • FIG. 4 illustrates an embodiment of tubing hanger 5 in which a production mandrel 80 is attached to tubing hanger body 115 .
  • production mandrel 80 is disposed in mandrel bore 60 and in a portion of seal receptacle bore 100 .
  • production mandrel 80 includes upper production mandrel portion 150 and production mandrel seal portion 155 .
  • upper production mandrel portion 150 has a diameter greater than the diameter of production mandrel seal portion 155 .
  • upper production mandrel portion 150 is disposed in mandrel bore 60 .
  • Production mandrel attachment system 170 includes any means suitable for connection of production mandrel 80 to mandrel receiving body section 75 .
  • production mandrel attachment system 170 is threads or a latch (or alternatively latches). It is to be understood that production mandrel attachment system 170 includes threads in embodiments in which upper suspension attachment system 10 is upper suspension threads, and production mandrel attachment system 170 includes a latch in embodiments in which upper suspension attachment system 10 is a notch mechanism. In an embodiment, production mandrel attachment system 170 includes threads.
  • production mandrel attachment system 170 is a latch.
  • the latch is suitably configured to be disposed in a notch on the interior surface of mandrel receiving body section 75 .
  • Production mandrel seal portion 155 has production mandrel sealing system 175 .
  • Production mandrel sealing system 175 includes any suitable system for sealing mandrel bore 60 and seal receptacle bore 100 .
  • production mandrel sealing system 175 includes any suitable type of elastomeric seal for such sealing.
  • suitable elastomeric seals include o-ring seals, dovetail seals, or any combinations thereof.
  • the elastomeric seal is a dovetail seal. Such seals may be above and/or below test port 15 .
  • Production mandrel sealing system 175 may include any suitable number of seals for sealing.
  • production mandrel sealing system 175 has an upper sealing system 50 and a lower sealing system 55 .
  • upper sealing system 50 is disposed above test port 15
  • lower sealing system 55 is disposed below test port 15
  • lower sealing system 55 is disposed below test port 15 to prevent wellbore fluids from flowing out through test port 15
  • Upper sealing system 50 and lower sealing system 55 may have any suitable number of seals.
  • upper sealing system 50 has upper seals 85 , 85 ′
  • lower sealing system 55 has lower seals 105 , 105 ′.
  • upper sealing system 50 includes two elastomeric dovetail seals (upper seal 85 and upper seal 85 ′)
  • lower sealing system 55 includes two elastomeric dovetail seals (lower seal 105 and lower seal 105 ′).
  • upper sealing system 50 has one elastomeric seal
  • lower sealing system 55 has one elastomeric seal.
  • production mandrel 80 has production mandrel shoulder 160 .
  • Production mandrel shoulder 160 is disposed at about where the diameter of production mandrel 80 is reduced from upper production mandrel portion 150 to the reduced diameter of production mandrel seal portion 155 .
  • Production mandrel shoulder 160 has a sufficient diameter and configuration to prevent further movement of production mandrel 80 into interior bore 70 when production mandrel shoulder 160 contacts mandrel stop 120 .
  • Production mandrel shoulder 160 may have any sufficient configuration to contact mandrel stop 120 and prevent the further movement of production mandrel 80 into interior bore 70 .
  • production mandrel shoulder 160 is about perpendicular to the exterior of upper production mandrel portion 150 and the exterior of production mandrel seal portion 155 .
  • production mandrel 80 has production mandrel seal shoulder 180 .
  • Production mandrel seal shoulder 180 is disposed at the end of production mandrel seal portion 155 distal from production mandrel shoulder 160 .
  • Production mandrel seal shoulder 180 has a sufficient diameter and configuration to prevent further movement of production mandrel 80 into interior bore 70 when production mandrel seal shoulder 180 contacts seal receptacle stop 125 .
  • Production mandrel seal shoulder 180 may have any sufficient configuration to contact seal receptacle stop 125 and prevent the further movement of production mandrel 80 into interior bore 70 .
  • production mandrel seal shoulder 180 is about perpendicular to a longitudinal plane of production mandrel seal portion 155 .
  • production mandrel 80 has production mandrel internal threads 90 . Production mandrel internal threads 90 facilitate attachment of production mandrel 80 to well equipment such as tubing of the wellhead.
  • Production mandrel internal threads 90 are right-handed threads. It is to be understood that right-handed threads for production mandrel 80 refer to threads that connect to well equipment (i.e., tubing) when production mandrel 80 is rotated in a clockwise direction to connect production mandrel 80 (i.e., rotate production mandrel 80 to screw the production mandrel 80 into the tubing), and that allow the production mandrel 80 to be removed from the tubing when the production mandrel 80 is rotated in an anti-clockwise direction.
  • well equipment i.e., tubing
  • test mandrel 30 is inserted into interior bore 70 and attached to tubing hanger 5 .
  • tubing hanger 5 may be disposed in a wellbore and attached to a tubing (i.e., the tubing is attached by tubing attachment system 25 ).
  • test mandrel 30 is screwed into mandrel bore 60 in an anti-clockwise direction (i.e., left-hand direction) until test mandrel shoulder 145 contacts mandrel stop 120 .
  • test mandrel seals 35 , 35 ′ are energized. Pressure is then added to seal receptacle bore 100 through test port 15 .
  • the pressure may be added by any suitable method.
  • the pressure is added by a pump. Any suitable method may be used to determine whether the pressure is being held by the seal.
  • the method may include adding pressure with a pump until a desired pressure is achieved. When the desired pressure is achieved, the pumped is stopped, and the pressure in interior bore 70 is monitored to determine if the pressure decreases.
  • a monitored decrease in pressure may indicate that tubing hanger 5 is not a closed system, and tubing hanger 5 has a pressure leak. If there is no monitored decrease in pressure, tubing hanger 5 is a closed system with no pressure leaks.
  • the pressure may be monitored by any suitable method.
  • a sensor or sensors on the pump monitor the pressure.
  • the sensor is a pressure gauge.
  • tubing hanger 5 may be checked to determine the source of the leak.
  • test mandrel 30 is removed from tubing hanger 5 . For instance, in an embodiment in which suspension attachment system 40 of test mandrel 30 is threads and test mandrel 30 was screwed into tubing hanger 5 , test mandrel 30 is unscrewed to be removed from tubing hanger 5 .
  • embodiments include attaching production mandrel 80 to tubing hanger 5 .
  • production mandrel 80 is screwed into mandrel bore 60 in an anti-clockwise direction (i.e., left-handed direction) until production mandrel shoulder 160 contacts mandrel stop 120 and/or production mandrel seal shoulder 180 contacts seal receptacle stop 125 .
  • production mandrel shoulder 160 contacts mandrel stop 120 and/or production mandrel seal shoulder 180 contacts seal receptacle stop 125
  • production mandrel sealing system 175 has upper sealing system 50 (i.e., upper seals 85 , 85 ′) and lower sealing system 55 (i.e., lower seals 105 , 105 ′)
  • upper seals 85 , 85 ′ and lower seals 105 , 105 ′ are energized.
  • tubing hanger 5 may be pressure tested again. This pressure test may be accomplished in the same manner as the pressure test of tubing hanger 5 with attached test mandrel 30 or may use any other suitable method.
  • a portion of a joint of tubing is disposed outside of interior bore 70 .
  • the pressure is tested around the portion of the joint by applying pressure to the portion of the joint. If no pressure is leaked, production mandrel sealing system 175 is sufficiently energized.
  • the back pressure valves in valve preparation bore 20 are removed. Without limitation, removing the back pressure valves facilitates production through interior bore 70 .

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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)
  • Geophysics (AREA)
  • Examining Or Testing Airtightness (AREA)
US13/027,321 2011-02-15 2011-02-15 Tubing Hanger and Methods for Testing and Sealing the Tubing Hanger Abandoned US20120205123A1 (en)

Priority Applications (2)

Application Number Priority Date Filing Date Title
US13/027,321 US20120205123A1 (en) 2011-02-15 2011-02-15 Tubing Hanger and Methods for Testing and Sealing the Tubing Hanger
PCT/US2012/025126 WO2012112612A2 (fr) 2011-02-15 2012-02-14 Dispositif de suspension de colonne et procédés d'essai et d'étanchéification du dispositif de suspension de colonne

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
US13/027,321 US20120205123A1 (en) 2011-02-15 2011-02-15 Tubing Hanger and Methods for Testing and Sealing the Tubing Hanger

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US13/027,321 Abandoned US20120205123A1 (en) 2011-02-15 2011-02-15 Tubing Hanger and Methods for Testing and Sealing the Tubing Hanger

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Cited By (6)

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Publication number Priority date Publication date Assignee Title
WO2015191417A1 (fr) * 2014-06-09 2015-12-17 Schlumberger Canada Limited Système et méthodologie faisant appel à une soupape d'accès à un espace annulaire
US20170058622A1 (en) * 2015-08-26 2017-03-02 Cameron International Corporation Hanger seal assembly
WO2018005892A1 (fr) * 2016-06-30 2018-01-04 Bowen Jr Billy A Soupape de commande de dispositif de suspension de tubage activée par un orifice de test
US20220081981A1 (en) * 2020-09-17 2022-03-17 Sonic Connectors Ltd. Tubing hanger for wellsite
US11708757B1 (en) * 2019-05-14 2023-07-25 Fortress Downhole Tools, Llc Method and apparatus for testing setting tools and other assemblies used to set downhole plugs and other objects in wellbores
US12000224B2 (en) * 2021-09-16 2024-06-04 Sonic Connectors Ltd. Tubing hanger for wellsite

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US4552213A (en) * 1984-03-08 1985-11-12 Fip, Inc. Wellhead apparatus
US5020590A (en) * 1988-12-01 1991-06-04 Mcleod Roderick D Back pressure plug tool
US6095243A (en) * 1997-06-17 2000-08-01 Plexus Ocean Systems Limited Washout arrangement for a well

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US3353596A (en) * 1965-06-30 1967-11-21 Atlantic Refining Co Tubing hanger and method of testing packing thereon
US4553591A (en) * 1984-04-12 1985-11-19 Mitchell Richard T Oil well drilling apparatus
US4690221A (en) * 1986-07-03 1987-09-01 Shell California Production Inc. Well tubing hanger method and apparatus for use in well control
US20020174991A1 (en) * 2001-05-24 2002-11-28 Borak Eugene A. One-trip wellhead installation systems and methods
US7913754B2 (en) * 2007-01-12 2011-03-29 Bj Services Company, U.S.A. Wellhead assembly and method for an injection tubing string
US20120139184A1 (en) * 2010-12-07 2012-06-07 Petrohawk Properties, Lp Dual Seal Tubing Hanger

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Publication number Priority date Publication date Assignee Title
US4552213A (en) * 1984-03-08 1985-11-12 Fip, Inc. Wellhead apparatus
US5020590A (en) * 1988-12-01 1991-06-04 Mcleod Roderick D Back pressure plug tool
US6095243A (en) * 1997-06-17 2000-08-01 Plexus Ocean Systems Limited Washout arrangement for a well

Cited By (13)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
GB2541592B (en) * 2014-06-09 2020-12-09 Schlumberger Technology Bv System and methodology using annulus access valve
GB2541592A (en) * 2014-06-09 2017-02-22 Schlumberger Technology Bv System and methodology using annulus access valve
US10161244B2 (en) 2014-06-09 2018-12-25 Schlumberger Technology Corporation System and methodology using annulus access valve
WO2015191417A1 (fr) * 2014-06-09 2015-12-17 Schlumberger Canada Limited Système et méthodologie faisant appel à une soupape d'accès à un espace annulaire
US20170058622A1 (en) * 2015-08-26 2017-03-02 Cameron International Corporation Hanger seal assembly
WO2017035545A3 (fr) * 2015-08-26 2017-04-06 Cameron International Corporation Ensemble d'étanchéité de suspension
US10100595B2 (en) * 2015-08-26 2018-10-16 Cameron International Corporation Hanger seal assembly
WO2018005892A1 (fr) * 2016-06-30 2018-01-04 Bowen Jr Billy A Soupape de commande de dispositif de suspension de tubage activée par un orifice de test
GB2566418A (en) * 2016-06-30 2019-03-13 A Bowen Billy JR Test-port activated tubing hanger control valve
US10669809B2 (en) 2016-06-30 2020-06-02 Billy A Bowen, JR. Test-port activated tubing hanger control valve
US11708757B1 (en) * 2019-05-14 2023-07-25 Fortress Downhole Tools, Llc Method and apparatus for testing setting tools and other assemblies used to set downhole plugs and other objects in wellbores
US20220081981A1 (en) * 2020-09-17 2022-03-17 Sonic Connectors Ltd. Tubing hanger for wellsite
US12000224B2 (en) * 2021-09-16 2024-06-04 Sonic Connectors Ltd. Tubing hanger for wellsite

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WO2012112612A2 (fr) 2012-08-23
WO2012112612A3 (fr) 2012-10-18

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