Subsea system and method for high pressure high temperature wells

Patent metadata

Field	Value
Publication number	US-10697264-B2
Application number	US-201916543414-A
Country	US
Kind code	B2
Filing date	Aug 16, 2019
Priority date	Sep 25, 2015
Publication date	Jun 30, 2020
Grant date	Jun 30, 2020

Abstract

A subsea production system and method for installing the same are provided. The subsea production system includes a high pressure subsea wellhead, a tubing hanger landed proximate the wellhead, a production tree disposed above the wellhead downstream of the tubing hanger, a riser, a subsea flowline system coupled between the production tree and the riser, at least one barrier located downstream of the tubing hanger, and a secondary barrier valve disposed within the tubing hanger or in line with and upstream of the tubing hanger. The at least one barrier provides a pressure barrier that controls pressure of fluid flowing from components of the subsea production system located upstream of the barrier to components of the subsea production system located downstream of the barrier, and the secondary barrier valve is remotely actuable between a closed position and an open position.

First claim

What is claimed is:

1. A method, comprising:
installing a subsea production system comprising a wellhead, a tubing hanger, a production tree, a riser, and a subsea flowline system by:
landing the tubing hanger proximate the wellhead, wherein a secondary barrier valve is disposed within the tubing hanger;
installing the production tree above the wellhead downstream of the tubing hanger with the secondary barrier valve being in a closed position;
remotely actuating the secondary barrier valve from the closed position to an open position after installing the production tree;
coupling the production tree to at least one barrier located downstream of the tubing hanger, wherein the at least one barrier comprises a high integrity pipeline protection system (HIPPS) module; and
coupling the production tree to the riser via the subsea flowline system;

producing hydrocarbons from a subsea reservoir to a topsides production facility via the subsea production system; and
controlling the at least one barrier in the subsea production system to control a pressure of fluid flowing from components of the subsea production system located upstream of the barrier to components of the subsea production system located downstream of the barrier.

2. The method of claim 1 , wherein remotely actuating the secondary barrier valve closes off an inner diameter of a production tubing string extending from the tubing hanger, a bore of the tubing hanger, or both.

3. The method of claim 1 , wherein the secondary barrier valve comprises a threaded portion that is threaded directly into a bottom of the tubing hanger.

4. The method of claim 1 , wherein the secondary barrier valve is threaded onto or integrated with a portion of a tubing string extending from the tubing hanger.

5. The method of claim 1 , wherein the secondary barrier valve is integrated directly into the tubing hanger.

6. The method of claim 1 , wherein the secondary barrier valve comprises a flapper valve, a ball valve, a gate valve, or a shuttle valve.

7. The method of claim 1 , wherein installing the production tree comprises lowering the production tree toward the wellhead and installing the production tree via a wireline cable when the secondary barrier valve is in the closed position.

8. The method of claim 1 , wherein the subsea reservoir comprises a high pressure and/or high temperature reservoir having a maximum reservoir pressure in excess of approximately 15,000 psi, a maximum temperature in excess of approximately 350 degrees F., or both.

9. The method of claim 1 , wherein at least one of the components located downstream of the barrier is rated for a first maximum pressure, temperature, or flow rate, and wherein all of the components located upstream of the barrier are rated for a second maximum pressure, temperature, or flow rate that is greater than the first maximum pressure, temperature, or flow rate.

10. The method of claim 1 , further comprising:
installing a tubing head spool (THS) on the wellhead;
landing the tubing hanger within the THS; and
installing the production tree on the THS.

11. The method of claim 1 , further comprising:
landing the tubing hanger within the wellhead; and
installing the production tree on the wellhead.

12. A subsea production system, comprising:
a high pressure subsea wellhead;
a tubing hanger landed proximate the wellhead;
a production tree disposed above the wellhead and downstream of the tubing hanger;
a riser;
a subsea flowline system coupled between the production tree and the riser;
at least one barrier, wherein the barrier is located downstream of the tubing hanger, providing a pressure barrier that controls pressure of fluid flowing from components of the subsea production system located upstream of the barrier to components of the subsea production system located downstream of the barrier, wherein the at least one barrier comprises a high integrity pipeline protection system (HIPPS) module; and
a secondary barrier valve disposed within the tubing hanger, wherein the secondary barrier valve is remotely actuable between a closed position and an open position.

13. The subsea production system of claim 12 , wherein remotely actuating the secondary barrier valve closes off an inner diameter of a production tubing string extending from the tubing hanger, a bore of the tubing hanger, or both.

14. The subsea production system of claim 12 , wherein the secondary barrier valve comprises a threaded portion that is threaded directly into a bottom of the tubing hanger.

15. The subsea production system of claim 12 , wherein the secondary barrier valve is threaded onto or integrated with a portion of a tubing string extending from the tubing hanger.

16. The subsea production system of claim 12 , wherein the secondary barrier valve is integrated directly into the tubing hanger.

17. The subsea production system of claim 12 , wherein the secondary barrier valve comprises a flapper valve, a ball valve, a gate valve, or a shuttle valve.

18. The subsea production system of claim 12 , wherein at least one of the components located downstream of the barrier is rated for a first maximum pressure, temperature, or flow rate, and wherein all of the components located upstream of the barrier are rated for a second maximum pressure, temperature, or flow rate that is greater than the first maximum pressure, temperature, or flow rate.

Assignees

• Dril Quip Inc

Inventors

• Witwer Bruce Joseph
• Morse Justin Edward
• Mclaughlin Daniel J
• Williams Gregory Dale
• Bower James R

Classifications

• E21B33/038 Primary

  Connectors used on well heads, e.g. for connecting blow-out preventer and riser · CPC title

• E21B33/064

  specially adapted for underwater well heads · CPC title

• E21B43/013

  Connecting a production flow line to an underwater well head · CPC title

• E21B41/0007

  for underwater installations (E21B41/005, E21B41/04, E21B41/06, E21B41/08, E21B41/10 take precedence) · CPC title

• E21B33/04

  Casing heads; Suspending casings or tubings in well heads · CPC title