Delivering fluid to a subsea wellhead

Patent metadata

Field	Value
Publication number	US-12018540-B2
Application number	US-202218050301-A
Country	US
Kind code	B2
Filing date	Oct 27, 2022
Priority date	Nov 22, 2019
Publication date	Jun 25, 2024
Grant date	Jun 25, 2024

Abstract

The invention relates to the introduction of pressurized fluid, e.g. acid, into a subsea well directly from a vessel ( 33 ). A fluid injection assembly ( 20 ) is fitted to the top of a subsea Xmas tree ( 3 ), the assembly ( 20 ) including fail safe closed valve ( 21 ) which is controlled via a hydraulic line ( 31 ) from the vessel. The hose and assembly and valve are designed with an internal bore allowing a large diameter ball to be dropped (required for acid stimulation). The subsea subsea control module ( 8 ) on the Xmas tree is controlled from the producing platform.

First claim

The invention claimed is:

1. A pressurized fluid injection assembly for mounting to a subsea Xmas tree, the Xmas tree having a first conduit communicating with production tubing of a subsea hydrocarbon well, the fluid injection assembly comprising:
a second conduit for delivery of fluid via the Xmas tree to the hydrocarbon well;
a connector at a first end of the second conduit, for connecting the second conduit to the first conduit of the Xmas tree;
a fail-safe close valve in the second conduit;
a fluid delivery connector for connecting to a fluid delivery pipe for supply of fluid to the injection assembly, the fluid delivery connector located at a second end of the second conduit;
wherein the fail-safe close valve has a hydraulic control line for connection to a control unit on a marine vessel, such that the fail-safe close valve is controllable exclusively from the marine vessel.

2. The fluid injection assembly according to claim 1 , suitable for injection of fluid at a rate selected from approximately: 5,000 liters per minute; 6,000 liters per minute; 7,000 liters per minute; 8,000 liters per minute; 9,000 liters per minute; 10,000 liters per minute; 11,000 liters per minute; 12,000 liters per minute; 13,000 liters per minute; 14,000 liters per minute; 15,000 liters per minute; between 5,000 and 15,000 liters per minute; between 8,000 and 12,000 liters per minute; up to 15,000 liters per minute; up to 12,000 liters per minute; and up to 10,000 liters per minute.

3. The fluid injection assembly according to claim 1 , wherein the second conduit and fail-safe close valve have an unobstructed internal diameter selected from: at least 4″, at least 5″, at least 6″, at least 7″, at least 8″, and between 4″ to 6″.

4. The fluid injection assembly according to claim 1 , wherein the second conduit comprises a rigid piping section that has one or more bends selected from approximately: 60 degrees, 70 degrees, 80 degrees, 90 degrees, 100 degrees, 110 degrees, 120 degrees, 130 degrees, 140 degrees, and 150 degrees or more, whereby the fluid delivery connector is provided at an end of the rigid piping section.

5. The fluid injection assembly according to claim 1 , wherein, when the assembly is secured with respect to the seafloor, the fluid delivery connector is directed upwardly.

6. The fluid injection assembly according to claim 5 wherein the fluid delivery connector is also adapted to receive lifting point member, whereby a lifting point for the assembly is provided.

7. The fluid injection assembly according to claim 1 , further comprising a guide funnel for guiding a fluid delivery pipe or lifting point member into position to connect to the fluid connector.

8. A system for injecting pressurized fluid into a subsea hydrocarbon well, the system comprising:
a subsea Xmas tree having a first conduit communicating with production tubing of a subsea hydrocarbon well;
a fluid injection assembly for mounting to the subsea Xmas tree, the fluid injection assembly comprising: (i) a second conduit for delivery of fluid via the Xmas tree to the hydrocarbon well; (ii) a connector at a first end of the second conduit, for connecting the second conduit to the first conduit of the Xmas tree; (iii) a fail-safe close valve in the second conduit; (iv) a fluid delivery connector for connecting to a fluid delivery pipe for supply of fluid to the injection assembly, the fluid delivery connector located at a second end of the second conduit;
a marine vessel including a fluid supply and a control unit;
a fluid delivery pipe including a subsea connector at a first end for connecting to the fluid injection assembly and a connector at a second end for connecting to the fluid supply;
a hydraulic control line extending between the fluid injection assembly and the control unit, for exclusively controlling the fail-safe close valve of the fluid injection assembly.

9. The system according to claim 8 , suitable for injection of fluid at a rate selected from approximately: 5,000 liters per minute; 6,000 liters per minute; 7,000 liters per minute; 8,000 liters per minute; 9,000 liters per minute; 10,000 liters per minute; 11,000 liters per minute; 12,000 liters per minute; 13,000 liters per minute; 14,000 liters per minute; 15,000 liters per minute; between 5,000 and 15,000 liters per minute; between 8,000 and 12,000 liters per minute; up to 15,000 liters per minute; up to 12,000 liters per minute; and up to 10,000 liters per minute.

10. The system according to claim 8 , wherein the fluid delivery pipe has an unobstructed internal diameter selected from at least 4″, at least 5″, at least 6″, at least 7″, at least 8″ and between 4″ to 6″.

11. The system according to claim 8 , wherein the fluid delivery pipe comprises a hose and a rigid connecting pipe having one or more bends selected from approximately: 60 degrees, 70 degrees, 80 degrees, 90 degrees, 100 degrees, 110 degrees, 120 degrees, 130 degrees, 140 degrees, and 150 degrees, the subsea connector being located on an end of the rigid connecting pipe.

12. The system according to claim 8 , wherein the Xmas tree includes a subsea control module for controlling at least a production master valve of the Xmas tree, the subsea control module being adapted to be controlled from a nearby production platform.

13. A method of delivering pressurized fluid to a subsea hydrocarbon wellhead, the method comprising:
a. removing a tree cap from a Xmas tree of a subsea well assembly;
b. fitting a pressurized fluid injection assembly to the Xmas tree, the fluid injection assembly comprising a fail-safe close valve and a connector for a fluid delivery pipe;
c. connecting a first end of a fluid delivery pipe to the connector, a second end of the fluid delivery pipe being connected to a fluid supply apparatus installed on a marine vessel;
d. delivering fluid under pressure, via the fluid delivery pipe and fail-safe valve, to production tubing of a well via the Xmas tree,
wherein the method comprises running a hydraulic control line between the fail-safe close valve and a control unit on the marine vessel such that the fail-safe valve is controllable exclusively from the control unit on the marine vessel.

14. The method according to claim 13 , wherein step b includes lowering the pressurized fluid injection assembly into place on the Xmas tree by crane, using a lifting point member installed in the connector of the assembly, and wherein the lifting point member is removed prior to step c.

15. The method according to claim 13 , wherein the second end of the pipe is connected via a quick release connector to the fluid supply apparatus via a hose, a hose and hose reel, or via some other structure.

16. The method according to claim 13 , including the step of dropping or pumping a ball from the marine vessel through the fluid delivery pipe and into the production tubing of the well.

17. The method according to claim 13 , wherein step c is performed by lowering the first end of the fluid delivery pipe into position using a crane.

18. The method according to claim 13 , a subsea connector being located on an end of the fluid delivery pipe, and wherein step c is performed by:
lowering a hose into a bracket adjacent the Xmas tree;
(ii) lowering the fluid delivery pipe;
(iii) connecting a first end of the fluid delivery pipe to the hose;
(iv) connecting the subsea connector of the fluid delivery pipe to the connector of the fluid injection assembly.

19. The method according to claim 13 , including controlling from a production platform a producti

Assignees

• Conocophillips Co

Inventors

• Kvarme Leif
• Spence John
• Heigre Birger

Classifications

• E21B34/04

  in underwater well heads · CPC title

• E21B19/16

  Connecting or disconnecting pipe couplings or joints (E21B19/20 takes precedence) · CPC title

• E21B19/004

  supporting a riser from a drilling or production platform · CPC title

• E21B43/27

  by use of eroding chemicals, e.g. acids · CPC title

• E21B33/076 Primary

  specially adapted for underwater installations · CPC title