WO2020206394A1 - Internal lock-down mechanism for tubing hanger - Google Patents

Internal lock-down mechanism for tubing hanger Download PDF

Info

Publication number
WO2020206394A1
WO2020206394A1 PCT/US2020/026775 US2020026775W WO2020206394A1 WO 2020206394 A1 WO2020206394 A1 WO 2020206394A1 US 2020026775 W US2020026775 W US 2020026775W WO 2020206394 A1 WO2020206394 A1 WO 2020206394A1
Authority
WO
WIPO (PCT)
Prior art keywords
tubing
tubing hanger
flange
longitudinal
annular
Prior art date
Application number
PCT/US2020/026775
Other languages
French (fr)
Inventor
Ray Dicksang Pang
Phu Duc Sy DONG
Moises NAVA
Russell Hamilton
Original Assignee
Seaboard International, Inc.
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Seaboard International, Inc. filed Critical Seaboard International, Inc.
Publication of WO2020206394A1 publication Critical patent/WO2020206394A1/en

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
    • 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
    • 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
    • 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
    • E21B33/035—Well heads; Setting-up thereof specially adapted for underwater installations
    • E21B33/038—Connectors used on well heads, e.g. for connecting blow-out preventer and riser

Definitions

  • the present disclosure relates to oil and gas well drilling and production, and in particular, to an internal lock-down mechanism for a tubing hanger.
  • Oil rigs are used to drive and rotate a drill string with a drilling bit attached at its end to create a well in the ground.
  • the same rig is also used for a second purpose to place casing in the well to provide a conduit from the surface to the producing formation.
  • casing After a well bore has been drilled and lined with casing, the usual practice is to cement the casing in place to protect ground water and the integrity and stability of the well.
  • Conventional cementing techniques involve displacing cement slurry down through the bore of the casing and out a shoe on the bottom thereof so that the cement fills the annulus between the casing and the well bore wall.
  • three to four casing strings are cemented in the wellbore, and a production tubing is installed that will become the fluid conduit with the target formation underground.
  • FIG. 1 is a simplified block diagram illustrating a hydrocarbon production system according to the teachings of the present disclosure.
  • FIG. 2 is a cross-sectional view of an exemplary embodiment of an internal lock-down mechanism for a production tubing hanger according to the teachings of the present disclosure.
  • the well is lined with steel pipes or casings to allow unobstructed access to the target reservoir deep in the ground.
  • Up to four casing strings may be installed and each string is cemented in place to structurally support the wellbore and hydraulically isolate the target reservoir from ground water sources and other formations.
  • the tubing string is the main conductor that brings reservoir fluid to the surface or injects fluid from the surface into the target formation.
  • the tubing string is supported from the wellhead and is hung, anchored or sealed against the cemented casing string by the tubing hanger.
  • the tubing hanger is threaded onto the top of a tubing string and is designed to sit on top of and seal in the tubing head.
  • lock screws also called lock-down screws
  • lock down screws are used to hold down and energize the seals on a tubing hanger.
  • the lock screw is threaded into the tubing head and the thread is located between the wellbore and the packing.
  • the use of these lock screws exposes the wellbore to the atmosphere and the threaded screw bore becomes a potential leak path.
  • the screw thread is also exposed to wellbore fluids that can impede the function of the lock screw. Further, installation of the lock screws is more prone to error, due to incorrect positioning, under- or over-application of torque, improper order of engagement or backing out, and other issues.
  • FIG. 1 is a simplified block diagram illustrating a hydrocarbon production system 10.
  • the system 10 includes a wellhead 12 coupled to a mineral deposit 14 via a well 16, wherein the well 16 includes a wellhead hub 18 and a wellbore 20.
  • the wellhead hub 18 generally includes a large diameter hub that is disposed at the termination of the wellbore 20.
  • the wellhead hub 18 provides for the connection of the wellhead 12 to the well 16.
  • the wellhead 12 typically includes many components that control and regulate activities and conditions associated with the well 16.
  • the wellhead 12 generally includes bodies, valves and seals that route produced hydrocarbons from the mineral deposit, provide for regulating pressure in the well, and provide for the injection of chemicals into the wellbore 20.
  • the wellhead 12 includes a production tree 22, a tubing spool 24, a casing spool 26, and a tubing hanger 28.
  • a blowout preventer (BOP) 30 may be used, either as a part of the tree 22 or as a separate device.
  • the BOP 30 may consist of a variety of valves, fittings and controls to prevent oil, gas, or other fluid from exiting the well in the event of an unintentional release of pressure or an overpressure condition.
  • an inward- biased lock ring 40 and an energizing ring 42 are used to provide an internal locking mechanism to secure the tubing hanger 28.
  • the energizing ring 42 is contoured with an inward facing locking flange 43 so that it engages a circumferential groove 44 formed in the tubing hanger 28 above the shoulder 45.
  • the lock ring 40 is disposed about the energizing ring 42.
  • a plurality of annual seals 47 are disposed at the interface between the tubing hanger 28 and tubing head 46.
  • the tubing head 46 is secured to a casing spool 26 or another structure already in place over the wellbore.
  • the tubing hanger 28 with the lock ring 40 and energizing ring 42 are then inserted into the tubing head 46 using a running tool 48 to install the tubing hanger 28.
  • the running tool 48 pushes on a circumferential flange 50 in the energizing ring 42 and advance it downward to urge the lock ring 40 into a circumferential groove 52 formed in the inner wall of the tubing head 46.
  • the lock ring is thus biased inward to maintains the position of the tubing hanger 28 within the tubing head 46.
  • the running tool 48 includes a longitudinal flange 54 having one or more circumferential internal peaks and valleys that function to exert downward forces on a circumferential longitudinal flange 56 of the tubing hanger 28 with external peaks and valleys to position the tubing hanger in place.
  • the locking ring 40 and energizing ring 42 sit on a circumferential shoulder 45 of the tubing hanger 28, and the longitudinal flange 54 of the running tool 48 also exert forces on the energizing ring 42 to urge it into place.
  • an internal lock-down mechanism (including the lock ring 40 and energizing ring 42) means that external lock screws are no longer needed to secure the tubing portion of the completion.
  • This internal lock-down mechanism (including the lock ring 40 and energizing ring 42) is able to withstand the high internal pressure (15,000 psi) of the wellbore.
  • the lock ring 40 and energizing ring 42 may be fabricated from any suitable elastomer material and/or metal now known or to be developed.
  • the running tool 48 has a threaded coupling 58 at its top end to facilitate its retrieval. The use of the internal lock ring 40 and energizing ring 42 eliminates a potential leak path from the wellbore and thus provides additional safeguards to the wellhead.

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)
  • Earth Drilling (AREA)

Abstract

An internal lock-down mechanism is used to secure a tubing hanger configured to be disposed within a wellbore to support a tubing string. An annular tubing head has a generally cylindrical bore and is configured for installation over the wellbore, and the tubing head defines an annular circumferential groove. The internal lock-down mechanism includes an annular energizing ring disposed circumferentially about the tubing hanger on a shoulder thereof. The energizing ring has an inward-facing flange configured to engage a circumferential groove disposed about the tubing hanger. The internal lock-down mechanism also includes an annular lock ring disposed circumferentially about the energizing ring. The tubing hanger is configured for insertion into the cylindrical bore of the tubing head installed in the wellbore, and the lock ring engages the inner circumferential groove defined in the tubing head and urges the inward-facing flange of the energizing ring to engage the circumferential groove of the tubing hanger, so that the tubing hanger is securely locked in position within the tubing head.

Description

INTERNAL LOCK-DOWN MECHANISM FOR TUBING HANGER
RELATED APPLICATION
[0001] This patent application claims the benefit of U.S. Provisional Patent Application No. 62/830,169 filed on April 5, 2019, incorporated herein by reference.
FIELD
[0002] The present disclosure relates to oil and gas well drilling and production, and in particular, to an internal lock-down mechanism for a tubing hanger.
BACKGROUND
[0003] Oil rigs are used to drive and rotate a drill string with a drilling bit attached at its end to create a well in the ground. The same rig is also used for a second purpose to place casing in the well to provide a conduit from the surface to the producing formation. After a well bore has been drilled and lined with casing, the usual practice is to cement the casing in place to protect ground water and the integrity and stability of the well. Conventional cementing techniques involve displacing cement slurry down through the bore of the casing and out a shoe on the bottom thereof so that the cement fills the annulus between the casing and the well bore wall. Typically, three to four casing strings are cemented in the wellbore, and a production tubing is installed that will become the fluid conduit with the target formation underground.
BRIEF DESCRIPTION OF THE DRAWINGS
[0004] FIG. 1 is a simplified block diagram illustrating a hydrocarbon production system according to the teachings of the present disclosure; and
[0005] FIG. 2 is a cross-sectional view of an exemplary embodiment of an internal lock-down mechanism for a production tubing hanger according to the teachings of the present disclosure. DETAILED DESCRIPTION
[0006] Generally, the well is lined with steel pipes or casings to allow unobstructed access to the target reservoir deep in the ground. Up to four casing strings may be installed and each string is cemented in place to structurally support the wellbore and hydraulically isolate the target reservoir from ground water sources and other formations. In a well, the tubing string is the main conductor that brings reservoir fluid to the surface or injects fluid from the surface into the target formation. The tubing string is supported from the wellhead and is hung, anchored or sealed against the cemented casing string by the tubing hanger. The tubing hanger is threaded onto the top of a tubing string and is designed to sit on top of and seal in the tubing head. The top of a conventional tubing hanger provides a profile to enable the use of external lock screws (also called lock-down screws) to secure the hanger in the tubing head. These lock down screws are used to hold down and energize the seals on a tubing hanger. The lock screw is threaded into the tubing head and the thread is located between the wellbore and the packing. The use of these lock screws exposes the wellbore to the atmosphere and the threaded screw bore becomes a potential leak path. The screw thread is also exposed to wellbore fluids that can impede the function of the lock screw. Further, installation of the lock screws is more prone to error, due to incorrect positioning, under- or over-application of torque, improper order of engagement or backing out, and other issues.
[0007] FIG. 1 is a simplified block diagram illustrating a hydrocarbon production system 10. As illustrated, the system 10 includes a wellhead 12 coupled to a mineral deposit 14 via a well 16, wherein the well 16 includes a wellhead hub 18 and a wellbore 20. The wellhead hub 18 generally includes a large diameter hub that is disposed at the termination of the wellbore 20. The wellhead hub 18 provides for the connection of the wellhead 12 to the well 16. The wellhead 12 typically includes many components that control and regulate activities and conditions associated with the well 16. For example, the wellhead 12 generally includes bodies, valves and seals that route produced hydrocarbons from the mineral deposit, provide for regulating pressure in the well, and provide for the injection of chemicals into the wellbore 20. In the illustrated embodiment, the wellhead 12 includes a production tree 22, a tubing spool 24, a casing spool 26, and a tubing hanger 28. A blowout preventer (BOP) 30 may be used, either as a part of the tree 22 or as a separate device. The BOP 30 may consist of a variety of valves, fittings and controls to prevent oil, gas, or other fluid from exiting the well in the event of an unintentional release of pressure or an overpressure condition.
[0008] Instead of using external lock screws to secure the tubing hanger 28, an inward- biased lock ring 40 and an energizing ring 42 are used to provide an internal locking mechanism to secure the tubing hanger 28. The energizing ring 42 is contoured with an inward facing locking flange 43 so that it engages a circumferential groove 44 formed in the tubing hanger 28 above the shoulder 45. The lock ring 40 is disposed about the energizing ring 42. A plurality of annual seals 47 are disposed at the interface between the tubing hanger 28 and tubing head 46.
[0009] In operation, the tubing head 46 is secured to a casing spool 26 or another structure already in place over the wellbore. The tubing hanger 28 with the lock ring 40 and energizing ring 42 are then inserted into the tubing head 46 using a running tool 48 to install the tubing hanger 28. The running tool 48 pushes on a circumferential flange 50 in the energizing ring 42 and advance it downward to urge the lock ring 40 into a circumferential groove 52 formed in the inner wall of the tubing head 46. The lock ring is thus biased inward to maintains the position of the tubing hanger 28 within the tubing head 46. The running tool 48 includes a longitudinal flange 54 having one or more circumferential internal peaks and valleys that function to exert downward forces on a circumferential longitudinal flange 56 of the tubing hanger 28 with external peaks and valleys to position the tubing hanger in place. The locking ring 40 and energizing ring 42 sit on a circumferential shoulder 45 of the tubing hanger 28, and the longitudinal flange 54 of the running tool 48 also exert forces on the energizing ring 42 to urge it into place. The lock ring 40, wedged in the groove 52 of the tubing head 46, prevents any upward movement of the tubing hanger 28 and energizing ring 42. The use of an internal lock-down mechanism (including the lock ring 40 and energizing ring 42) means that external lock screws are no longer needed to secure the tubing portion of the completion. This internal lock-down mechanism (including the lock ring 40 and energizing ring 42) is able to withstand the high internal pressure (15,000 psi) of the wellbore.
[0010] The lock ring 40 and energizing ring 42 may be fabricated from any suitable elastomer material and/or metal now known or to be developed. The running tool 48 has a threaded coupling 58 at its top end to facilitate its retrieval. The use of the internal lock ring 40 and energizing ring 42 eliminates a potential leak path from the wellbore and thus provides additional safeguards to the wellhead.
[0011] The features of the present invention which are believed to be novel are set forth below with particularity in the appended claims. However, modifications, variations, and changes to the exemplary embodiments described above will be apparent to those skilled in the art, and the internal lock-down mechanism for a tubing hanger described herein thus encompasses such modifications, variations, and changes and are not limited to the specific embodiments described herein.

Claims

WHAT IS CLAIMED IS:
1. An internal lock-down mechanism for a tubing hanger configured to be disposed in a wellbore and support a tubing string, the internal lock-down mechanism comprising:
an annular tubing head having a generally cylindrical bore and configured for installation over the wellbore, the tubing head defining an annular circumferential groove; an annular energizing ring disposed circumferentially about the tubing hanger on a shoulder thereof, the energizing ring having an inward-facing flange configured to engage a circumferential groove disposed about the tubing hanger;
an annular lock ring disposed circumferentially about the energizing ring; and wherein the tubing hanger is configured for insertion into the cylindrical bore of the tubing head installed in the wellbore, and the lock ring engages the inner circumferential groove defined in the tubing head and urges the inward-facing flange of the energizing ring to engage the circumferential groove of the tubing hanger, and thereby securely locking the tubing hanger in position within the tubing head.
2. The internal lock-down mechanism of claim 1, wherein the tubing hanger further comprises a longitudinal annular flange, and a running tool having a longitudinal annular flange disposed about a central bore defined therein, the longitudinal flange being configured to accommodate and engage the longitudinal annular flange of the tubing hanger, and the running tool is configured to urge the tubing hanger and energizing ring into the cylindrical bore of the tubing head.
3. The internal lock-down mechanism of claim 2, wherein the tubing hanger comprises a circumferential shoulder against which the energizing ring and lock ring abut as the running tool is used to insert the tubing hanger.
4. The internal lock-down mechanism of claim 2, wherein the longitudinal annual flange of the tubing hanger comprises at least one outward-facing annular flange configured to engage at least one inward-facing annular groove defined on the longitudinal flange of the running tool.
5. The internal lock-down mechanism of claim 2, wherein the longitudinal annual flange of the tubing hanger comprises at least one outward-facing annular groove configured to engage at least one inward-facing annular flange defined on the longitudinal flange of the running tool.
6. The internal lock-down mechanism of claim 1, wherein the lock ring is inwardly-biased against the energizing ring.
7. The internal lock-down mechanism of claim 2, wherein the running tool further comprises a threaded coupling.
8. An internal lock-down mechanism for a tubing hanger configured to be disposed in a tubing head within a wellbore to support a tubing string, the internal lock-down mechanism comprising:
an annular energizing ring disposed circumferentially about the tubing hanger on a shoulder thereof, the energizing ring having an inward-facing flange configured to engage a circumferential groove disposed about the tubing hanger;
an annular lock ring engagingly disposed circumferentially about the energizing ring; and
wherein the tubing hanger is configured for insertion into a cylindrical bore of the tubing head installed in the wellbore, and the lock ring engages an inner circumferential groove defined in the tubing head and urges the inward-facing flange of the energizing ring to engage the circumferential groove of the tubing hanger, and thereby securely locking the tubing hanger in position within the tubing head.
9. The internal lock-down mechanism of claim 8, wherein the tubing hanger further comprises a longitudinal annular flange, and a running tool having a longitudinal annular flange disposed about a central bore defined therein, the longitudinal bore being configured to accommodate and engage the longitudinal annular flange of the tubing hanger, and the running tool is configured to urge the tubing hanger and energizing ring into the cylindrical bore of the tubing head.
10. The internal lock-down mechanism of claim 9, wherein the tubing hanger comprises a circumferential shoulder against which the energizing ring and lock ring abut as the running tool is used to insert the tubing hanger.
11. The internal lock-down mechanism of claim 9, wherein the longitudinal annual flange of the tubing hanger comprises at least one outward-facing annular flange configured to engage at least one inward-facing annular groove defined on the longitudinal flange of the running tool.
12. The internal lock-down mechanism of claim 9, wherein the longitudinal annual flange of the tubing hanger comprises at least one outward-facing annular groove configured to engage at least one inward-facing annular flange defined on the longitudinal flange of the running tool.
13. The internal lock-down mechanism of claim 8, wherein the lock ring is inwardly-biased against the energizing ring.
14. The internal lock-down mechanism of claim 9, wherein the running tool further comprises a threaded coupling.
15. A tubing spool using an internal lock-down mechanism for a tubing hanger to support and position a tubing string in a wellbore, the tubing spool comprising:
an annular tubing head having a generally cylindrical bore and configured for installation over the wellbore, the tubing head defining an annular circumferential groove; the tubing hanger having a longitudinal annular flange and configured for insertion into the cylindrical bore of the tubing head installed in the wellbore, and
an annular energizing ring disposed circumferentially about the tubing hanger on a shoulder thereof, the energizing ring having an inward-facing flange configured to engage a circumferential groove disposed about the tubing hanger;
an annular lock ring disposed circumferentially about the energizing ring; and wherein the lock ring engages the inner circumferential groove defined in the tubing head and urges the inward-facing flange of the energizing ring to engage the circumferential groove of the tubing hanger, and thereby securely locking the tubing hanger in position within the tubing head.
16. The tubing spool of claim 15, further comprising a running tool having a longitudinal annular flange disposed about a central bore defined therein, the longitudinal flange of the running tool being configured to accommodate and engage the longitudinal annular flange of the tubing hanger, and the running tool is configured to urge the tubing hanger and energizing ring into the cylindrical bore of the tubing head.
17. The tubing spool of claim 16, wherein the tubing hanger comprises a circumferential shoulder against which the energizing ring and lock ring abut as the running tool is used to insert the tubing hanger.
18. The tubing spool of claim 16, wherein the longitudinal annual flange of the tubing hanger comprises at least one outward-facing annular flange configured to engage at least one inward-facing annular groove defined on the longitudinal flange of the running tool.
19. The tubing spool of claim 16, wherein the longitudinal annual flange of the tubing hanger comprises at least one outward-facing annular groove configured to engage at least one inward-facing annular flange defined on the longitudinal flange of the running tool.
20. The tubing spool of claim 15, wherein the lock ring is inwardly-biased against the energizing ring.
PCT/US2020/026775 2019-04-05 2020-04-04 Internal lock-down mechanism for tubing hanger WO2020206394A1 (en)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US201962830169P 2019-04-05 2019-04-05
US62/830,169 2019-04-05

Publications (1)

Publication Number Publication Date
WO2020206394A1 true WO2020206394A1 (en) 2020-10-08

Family

ID=72666290

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/US2020/026775 WO2020206394A1 (en) 2019-04-05 2020-04-04 Internal lock-down mechanism for tubing hanger

Country Status (1)

Country Link
WO (1) WO2020206394A1 (en)

Cited By (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2023038704A1 (en) * 2021-09-09 2023-03-16 Fmc Technologies, Inc. Tubing head spool with adapter bushing

Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20150068725A1 (en) * 2012-05-10 2015-03-12 Vetco Gray Inc. Positive retention lock ring for tubing hanger
US20160032674A1 (en) * 2014-08-01 2016-02-04 Cameron International Corporation System for setting and retrieving a seal assembly
US20160102512A1 (en) * 2014-10-14 2016-04-14 Cameron International Corporation Dual lock system
US20160186523A1 (en) * 2014-12-31 2016-06-30 Cameron International Corporation Hanger lock system
US20170198540A1 (en) * 2016-01-11 2017-07-13 Fmc Technologies, Inc. Hybrid two piece packoff assembly

Patent Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20150068725A1 (en) * 2012-05-10 2015-03-12 Vetco Gray Inc. Positive retention lock ring for tubing hanger
US20160032674A1 (en) * 2014-08-01 2016-02-04 Cameron International Corporation System for setting and retrieving a seal assembly
US20160102512A1 (en) * 2014-10-14 2016-04-14 Cameron International Corporation Dual lock system
US20160186523A1 (en) * 2014-12-31 2016-06-30 Cameron International Corporation Hanger lock system
US20170198540A1 (en) * 2016-01-11 2017-07-13 Fmc Technologies, Inc. Hybrid two piece packoff assembly

Cited By (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2023038704A1 (en) * 2021-09-09 2023-03-16 Fmc Technologies, Inc. Tubing head spool with adapter bushing
US11668151B2 (en) 2021-09-09 2023-06-06 Fmc Technologies, Inc. Tubing head spool with adapter bushing

Similar Documents

Publication Publication Date Title
US6360822B1 (en) Casing annulus monitoring apparatus and method
US8196649B2 (en) Thru diverter wellhead with direct connecting downhole control
US6457528B1 (en) Method for preventing critical annular pressure buildup
US3847215A (en) Underwater well completion method and apparatus
EP2102446B1 (en) Wellhead assembly and method for an injection tubing string
US8950485B2 (en) Drilling/frac adapter and method of use
EP2287439B1 (en) Method of completing a well
US7647973B2 (en) Collapse arrestor tool
US5607019A (en) Adjustable mandrel hanger for a jackup drilling rig
US8789621B2 (en) Hydrocarbon well completion system and method of completing a hydrocarbon well
US4807705A (en) Casing hanger with landing shoulder seal insert
US5025864A (en) Casing hanger wear bushing
NO343190B1 (en) Production assembly to control production from production tubes as well as methods for communicating with a component downhole in a well
US20140060805A1 (en) Fluid Seal with Swellable Material Packing
US10138697B2 (en) Mineral extraction system having multi-barrier lock screw
US6003602A (en) Tree bore protector
US9291022B2 (en) Method and system for temporarily locking a tubular
WO2020206394A1 (en) Internal lock-down mechanism for tubing hanger
WO2018164896A1 (en) Mono-bore wellbore completion with a retrievable portion
US4611663A (en) Casing hanger and running apparatus
US20240167358A1 (en) Mechanical well control barrier in single casing wells
CA2735916C (en) Narrow well bore
US20240328274A1 (en) Big bore low pressure surface wellhead housing systems
US20240254852A1 (en) Fluted rotating tubing hanger for cemented completion applications - btf hanger
US20240060400A1 (en) Performing a wellbore tieback operation

Legal Events

Date Code Title Description
121 Ep: the epo has been informed by wipo that ep was designated in this application

Ref document number: 20783226

Country of ref document: EP

Kind code of ref document: A1

NENP Non-entry into the national phase

Ref country code: DE

122 Ep: pct application non-entry in european phase

Ref document number: 20783226

Country of ref document: EP

Kind code of ref document: A1