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BR-122022024369-B1 - SYSTEM

BR122022024369B1BR 122022024369 B1BR122022024369 B1BR 122022024369B1BR-122022024369-B1

Abstract

SYSTEM. The present invention relates to a subsea wellhead assembly having an arrangement of primary well barriers provided in the equipment that is located within the well and/or wellhead compartment. All well barriers may be located within the tubing hanger and/or the production tubing string extending into the wellbore. The subsea wellhead assembly also includes a flowline connection body positioned atop the wellhead compartment and fluidly coupled to the tubing hanger. None of the primary well barriers are located in the flowline connection body.

Inventors

  • CHRIS D. BARTLETT
  • DANIEL J. MCLAUCHLIN
  • RAY GUILLORY
  • BLAKE T. DEBERRY
  • MARCUS SMEDLEY

Assignees

  • INNOVEX INTERNATIONAL, INC

Dates

Publication Date
20260310
Application Date
20191204
Priority Date
20181205

Claims (8)

  1. 1. System (100), characterized in that: a pipe hanger (104) positioned in a wellhead compartment (102); a production pipe string (112) coupled to and extending from the pipe hanger (104) to a well; a flow line connection body (108) fluidly coupled to the pipe hanger (104) and disposed on top of the wellhead compartment (102); at least two primary production barrier valves (118A) located upstream of the pipe hanger (104) within the production pipe string (112); and a flow module (302) coupled to and disposed above the flow line connection body (108), wherein the flow module (302) comprises a production side valve (206A) disposed along a production flow path (120A) within the flow module (302).
  2. 2. System (100), according to claim 1, characterized in that it further comprises a barrier valve (118B) disposed along an annular flow path (126B) within the flow line connection body (108).
  3. 3. System (100), according to claim 1, characterized in that it further comprises an annular access valve (402) disposed along an annular flow path (120B) within the pipe hanger (104).
  4. 4. System (100), according to claim 1, characterized in that it further comprises a production piston valve (130A) disposed along a production flow path (126A) within the flow line connection body (108).
  5. 5. System (100), according to claim 1, characterized in that the flow module (302) further comprises: a connecting valve (204) disposed along an annular flow path (126B) within the flow module (302), wherein the annular flow path (126B) within the flow module (302) couples to the production flow path (120A) within the flow module (302) downstream of the production side valve (206A).
  6. 6. System (100), according to claim 1, characterized in that the flow module (302) further comprises a third primary production barrier valve.
  7. 7. System (100), according to claim 1, characterized in that it further comprises a bridge tube (304) and a collector (202), wherein the bridge tube (304) couples the collector (202) to the flow module (302).
  8. 8. System (100), according to claim 1, characterized in that the flow module (302) further comprises: a pressure control valve (208) disposed along the production flow path (120A) within the flow module (302) downstream of the production side valve (206A); and a process shut-off valve (210) disposed along the production flow path (120A) within the flow module (302) downstream of the pressure control valve (208).

Description

[0001] Split order BR112021010586-7, filed on December 4, 2019. Cross-reference to related requests. [0002] This application claims priority over U.S. Provisional Application Serial No. 62/775,672 filed December 5, 2018, which is incorporated herein by reference in its entirety. Technical Field [0003] The present invention relates generally to wellhead systems and, more particularly, to an arrangement of wellbore barriers in a wellhead assembly. Background [0004] Conventional wellhead systems include a wellhead compartment mounted at the upper end of a subsurface casing string that extends into the wellbore. During a drilling procedure, a drilling riser and BOP are installed above a wellhead compartment (casing head) to provide pressure control as the casing is installed, with each casing string having a casing hanger at its upper end to rest on a shoulder within the wellhead compartment. The casing string is then installed through the wellbore. A casing hanger that can be connected to the upper end of the casing string is supported within the wellhead compartment above the casing hanger(s) to suspend the casing string within the casing string(s). After completion of this process, the well is temporarily suspended by means of a temporary barrier. The temporary barrier could be a steel cable plug, a downhole isolation valve that is pressure-cycled open, a downhole safety valve, heavy finishing fluid, or any combination of the above. The temporary barrier will provide a barrier between the well and the environment before well control devices, such as the blowout preventer (BOP) and marine riser, are disconnected from the well. [0005] Once removed, the BOP is replaced with a permanent well control device, in the form of a subsea Christmas tree installed above the wellhead compartment, with the tree having a valve to allow oil or gas to be produced and directed into flowlines for transport to a desired facility. Temporary well barriers are removed after the subsea tree is installed. The subsea tree then acts as a primary well control device while the tree is in production. The subsea tree has at least two well barriers in the production flow borehole that allow the well to be shut off remotely if there is a situation on the platform or anywhere downstream of the tree that requires well isolation. [0006] If the subsea tree needs to be recovered, one or more temporary barriers are reinstalled in the well. This is typically achieved by installing an extension string and/or riser that allows heavy completion fluid to be pumped into the wellbore, and a wire rope plug is installed on the pipe hanger. Once these barriers are in place, the subsea tree can be removed. If an isolation valve that operates closed by applying pressure cycles (e.g., full-bore isolation valve, or FBIV) is used during the initial installation, it cannot be remotely closed again. Thus, a different barrier will be installed in place of the FBIV, typically a wire rope plug. [0007] This process of defining additional barriers in the flow borehole before recovering a subsea tree from the wellhead is time-consuming and expensive. It is now recognized that systems and methods to simplify or reduce the cost of such wellhead installation/maintenance operations are desirable. Brief Description of the Drawings [0008] For a more complete understanding of the present disclosure and its characteristics and advantages, reference is now made to the following description, considered in conjunction with the attached drawings, in which: [0009] Figure 1 is a partial cross-sectional view of components of a subsea production system having an arrangement of wellbore barriers within a pipe hanger, according to an embodiment of the present disclosure; [0010] Figure 2 is a schematic diagram of components of a subsea production system that includes a manifold and a wellhead arrangement of well barriers, a pipe hanger, and/or a well termination string, according to an embodiment of this disclosure; [0011] Figure 3 is a schematic diagram of components of a subsea production system that includes a flow module, a manifold, and an arrangement of wellbore barriers disposed at the wellhead, pipe hanger, and/or well termination string, according to an embodiment of this disclosure; and [0012] Figure 4 is a schematic diagram of components of a subsea production system that includes a flow module located on the upper surface of the flowline connection body, a manifold, and a wellbore array arranged in the wellhead and/or well termination string, according to an embodiment of this disclosure. Detailed Description [0013] The illustrative embodiments of this disclosure are described herein in detail. For the sake of clarity, not all features of an actual implementation are described in this descriptive report. It will be noted, of course, that in the development of any actual embodiment, numerous specific implementation decisions must be made to achieve the specific objectives of th