Subsea mechanism to circulate fluid between a riser and tubing string

• US 10,006,270 B2
• Filed: 08/11/2014
• Issued: 06/26/2018
• Est. Priority Date: 08/11/2014
• Status: Active Grant

• Current Assignee: Halliburton Energy Services Incorporated (Halliburton Company)
• Original Assignee: Halliburton Energy Services Incorporated (Halliburton Company)
• Inventors: Schwendemann, Kenneth L., Perkins, Donald H.
• Primary Examiner(s): Sayre, James G
• Application Number:
  US15/311,239
• Publication Number:
  US 20170074069A1
• Time in Patent Office: 1,415 Days
• CPC Class Codes: E21B 17/01 Risers
• CPC Class Codes: E21B 2200/06 Sleeve valves
• CPC Class Codes: E21B 33/035 specially adapted for underwater installations E21B33/043, E21B33/064, E21B33/076 take precedence
• CPC Class Codes: E21B 33/064 specially adapted for underwater well heads
• CPC Class Codes: E21B 34/045 adapted to be lowered on a tubular string into position within a blow-out preventer stack, e.g. so-called test trees
• CPC Class Codes: E21B 34/12 operated by movement of casings or tubings

Abstract

A circulation mechanism in a subsea assembly is selectively actuated to allow fluid communication between the riser annulus and tubing string to immediately kill the well using heavy-weight fluid in the riser annulus; perform well control operations by adjusting the weight or other properties of fluid in the tubing string or riser annulus; and/or to circulate the riser of a deep-water well undergoing well testing or intervention.

Claims

1. A subsea assembly, comprising:

a riser extending through a body of water and connected to a blow-out preventer (“

BOP”

) positioned at a sea floor;

a tubing string extending within the riser such that a riser annulus is defined between the tubing string and the riser;

a subsea test tree (“

SSTT”

) positioned along the tubing string;

a work string extending below the sea floor to a formation depth and defining a tubing volume therein;

a riser fluid disposed in the riser annulus, the riser fluid in the riser annulus having a fluid volume at least equal to the tubing volume; and

a circulation mechanism positioned along the tubing string above the SSTT to allow selective communication of the riser fluid between the tubing string and the riser annulus through a port defined through the tubing string.

2. A subsea assembly as defined in claim 1, wherein the circulation mechanism comprises:

a sliding sleeve positioned around the tubing string to move between an open and closed position in relation to the port, the open position allowing fluid to communicate between the tubing string and the riser annulus, the closed position preventing fluid from communicating between the tubing string and the riser annulus.

3. A subsea assembly as defined in claim 1, wherein the circulation mechanism is surface-controlled.

4. A subsea assembly as defined in claim 1, wherein the circulation mechanism is positioned above the BOP.

5. A subsea assembly as defined in claim 1, wherein the riser fluid is a heavy-weight kill fluid.

6. A subsea assembly as defined in claim 1, further comprising a tubing closure mechanism positioned as part of the tubing string, wherein the circulation mechanism is positioned above or below the tubing closure mechanism.

7. A subsea assembly as defined in claim 6, wherein the tubing closure mechanism is a ball valve, retainer valve or circulation valve.

8. A subsea assembly as defined in claim 1, further comprising a tubing closure mechanism positioned as part of the tubing string, wherein the circulation mechanism is positioned above the tubing closure mechanism and a second circulation mechanism is positioned below the tubing closure mechanism.

9. A method of using a subsea assembly, the method comprising:

deploying a tubing string into a riser to define a riser annulus between the tubing string and the riser, the riser being connected to a blow-out preventer (“

BOP”

) positioned at a sea floor above a well;

filling the riser annulus with a sufficient volume of a riser fluid to fill a tubing volume of a work string extending to a formation depth into the well below the sea floor;

actuating a circulation mechanism to allow communication of the riser fluid between the riser annulus and the tubing string, the circulation mechanism being positioned as part of the tubing string above a subsea test tree (“

SSTT”

); and

filling the tubing volume with the riser fluid by flowing the riser fluid from the riser annulus into the work string through the tubing string.

10. A method as defined in claim 9, wherein actuating the circulation mechanism comprises:

opening a sliding sleeve to allow the riser fluid to communicate between the riser annulus and the tubing string;

or

closing the sliding sleeve to prevent the riser fluid from communicating between the riser annulus and the tubing string.

11. A method as defined in claim 9, wherein:

filing the riser annulus with riser fluid comprises filling the riser annulus with a heavy-weight kill fluid; and

actuating the circulation mechanism comprises opening the circulation mechanism to allow the heavy-weight kill fluid to flow from the riser annulus into the tubing string,

the method further comprising killing the well using the heavy-weight kill fluid.

12. A method as defined in claim 9, wherein:

the SSTT is closed;

filling the riser annulus with riser fluid comprises filling the riser annulus with a heavy-weight kill fluid; and

actuating the circulation mechanism comprises opening the circulation mechanism to allow the heavy-weight kill fluid to flow from the riser annulus into the tubing string, thereby causing returns to flow up through the tubing string,

the method further comprising;

opening the SSTT; and

killing the well using the heavy-weight kill fluid.

13. A method as defined in claim 12, wherein, before the SSTT is closed, the tubing string is filled with gas or a fluid lighter than the heavy-weight kill fluid.

14. A method as defined in claim 9, wherein:

the SSTT is closed; and

actuating the circulation mechanism comprises opening the circulation mechanism,

the method further comprising;

pumping gas down the tubing string and out into the riser annulus;

closing the circulation mechanism; and

opening the SSTT to allow production of well fluids.

15. A method as defined in claim 9, further comprising:

preventing fluid flow up the tubing string using a tubing closure mechanism positioned above the circulation mechanism, wherein actuating the circulation mechanism comprises opening the circulation mechanism to allow the riser fluid to flow from the riser annulus into the tubing string, the riser fluid being a heavy-weight kill fluid;

killing the well using the heavy-weight kill fluid; and

closing the SSTT.

16. A method as defined in claim 9, wherein actuating the circulation mechanism comprises opening the circulation mechanism to:

adjust a weight of the riser fluid;

or

adjust a weight of fluid in the tubing string.

17. A method of using a subsea assembly, the method comprising:

deploying a tubing string into a riser, thereby forming a riser annulus between the riser and the tubing string, the riser annulus having a volume of riser fluid therein, the riser being connected to a blow-out preventer (“

BOP”

) positioned at a sea floor above a well; and

selectively communicating the volume of riser fluid from the riser annulus and into the tubing string to thereby fill a tubing volume of a work string extending to a formation depth into the well below the sea floor.

18. A method as defined in claim 17, wherein selectively communicating the fluid comprises:

flowing the riser fluid to flow from the riser annulus and into the tubing string;

or

flowing fluid within the tubing string from the tubing string and into the riser annulus.

19. A method as defined in claim 17, wherein selectively communicating the fluid comprises:

killing the well using the riser fluid.

20. A method as defined in claim 17, further comprising:

closing a subsea test tree (“

SSTT”

) positioned along the tubing string;

flowing the riser fluid up the tubing string;

opening the SSTT; and

killing the well with the riser fluid.

21. A method as defined in claim 17, further comprising:

closing a subsea test tree (“

SSTT”

);

pumping fluid down the tubing string and out into the riser annulus via a port positioned along the tubing string;

closing the port; and

opening the SSTT to allow production of well fluids.

22. A method as defined in claim 17, further comprising:

preventing fluid flow up the tubing string;

killing the well using the riser fluid; and

closing a subsea test tree (“

SSTT”

).