System and methodology using annulus access valve

• US 10,161,244 B2
• Filed: 06/08/2015
• Issued: 12/25/2018
• Est. Priority Date: 06/09/2014
• Status: Active Grant

• Current Assignee: Onesubsea IP UK Limited (Schlumberger NV)
• Original Assignee: Schlumberger Technology Corporation (Schlumberger NV)
• Inventors: Taylor, Nicholas, Daniel, Gregory, Martinez, Boris
• Primary Examiner(s): Sayre, James G
• Application Number:
  US15/316,416
• Publication Number:
  US 20170183956A1
• Time in Patent Office: 1,296 Days
• CPC Class Codes: E21B 33/035 specially adapted for underwater installations E21B33/043, E21B33/064, E21B33/076 take precedence
• CPC Class Codes: E21B 33/043 specially adapted for underwater well heads E21B33/0407, E21B33/047 take precedence
• CPC Class Codes: E21B 33/064 specially adapted for underwater well heads
• CPC Class Codes: E21B 34/04 in underwater well heads
• CPC Class Codes: E21B 47/117 Detecting leaks, e.g. from tubing, by pressure testing

Abstract

A technique facilitates pressure testing of seals along a tubing hanger, such as a tubing hanger used in a subsea application. In some applications, the tubing hanger is sealed along its exterior with an upper tubing hanger seal and a lower tubing hanger seal. A valve assembly is deployed along a fluid passageway which is routed to the tubing hanger seals. The valve assembly may be selectively actuated to a test position, e.g. a closed position, which enables pressure isolation and pressure testing of the tubing hanger seals. The valve assembly may also be selectively utilized to introduce fluids into the formation below the tubing hanger.

Claims

1. A method for seal testing in a well, the method comprising:

installing a tubing hanger in a subsea Christmas tree at the well;

externally sealing the tubing hangar at a wellhead defining the well with an upper tubing hanger seal between the hangar and the wellhead and a lower tubing hanger seal between the hangar and the wellhead;

routing an annulus line through a blowout preventer and the subsea Christmas tree to a location that is both between the seals and between the hangar and the wellhead to enable application of test pressure to both the upper tubing hanger seal and the lower tubing hanger seal simultaneously via a flow passage provided by the annulus line; and

using a valve located in an adapter hub and in fluid communication with the annulus line to selectively close off the annulus line during pressure testing of both the upper tubing hanger seal and the lower tubing hanger seal.

2. The method as recited in claim 1, further comprising applying test pressure to the annulus line via a pressure test port while the valve is in a closed position.

3. The method as recited in claim 2, further comprising shifting the valve to an open position via pressure applied in the annulus line on an opposite side of the valve relative to the upper tubing hanger seal.

4. The method as recited in claim 1, further comprising applying test pressure to the annulus line via a pressure test port while the valve is closed to simultaneously pressure test the upper tubing hanger seal and the lower tubing hanger seal by establishing a differential pressure across both the upper tubing hanger seal and the lower tubing hanger seal.

5. The method as recited in claim 1, further comprising forming the valve as a flapper valve.

6. The method as recited in claim 5, further comprising shifting the flapper valve to an open position via a piston.

7. The method as recited in claim 1, further comprising routing the annulus line to a region between the upper tubing hanger seal and the lower tubing hanger seal.

8. The method as recited in claim 1, further comprising locating the annulus line in a radially offset position relative to a primary flow passage through the Christmas tree.

9. The method as recited in claim 1, further comprising providing the valve with capability for full bore flow along the annulus line.

10. A system, comprising:

a subsea wellhead; and

a subsea Christmas tree mounted on the subsea wellhead, the subsea Christmas tree comprising;

a tubing hanger forming seals with the wellhead at an interface therewith via an upper tubing hanger seal and a lower tubing hanger seal between the hanger and the wellhead; and

a valve assembly located in an adapter hub and in fluid communication with a flow passage positioned externally of a primary flow passage through the Christmas tree, the flow passage providing communication between a pressure test port at the interface and between the upper and lower tubing hanger seals, the valve assembly having a valve selectively shiftable from an open flow position to a closed flow position such that a pressure differential may be established across both the upper and lower tubing hanger seals via the pressure test port when the valve is in the closed position.

11. The system as recited in claim 10, wherein the valve comprises a flapper valve.

12. The system as recited in claim 10, further comprising a blowout preventer mounted above the Christmas tree.

13. The system as recited in claim 12, wherein the flow passage extends to the blowout preventer and the valve assembly is selectively actuatable to isolate pressure in the flow passage between the blowout preventer and the upper and lower tubing hanger seals.

14. A method, comprising:

establishing a seal about a tubing hanger via an upper tubing hanger seal at an interface between the hanger and a wellhead and a lower tubing hanger seal at the interface;

selectively isolating a flow passage defined by an annulus line extending from a blowout preventer through a Christmas tree and into the tubing hanger to a location between the upper tubing hanger seal and the lower tubing hanger seal; and

testing seal integrity at the upper tubing hangar seal and the lower tubing hangar seal simultaneously by establishing a pressure differential across the upper tubing hangar seal and the lower tubing hangar seal via the flow passage while the flow passage is selectively isolated.

15. The method as recited in claim 14, wherein selectively isolating comprises selectively actuating a valve assembly disposed along the flow passage.

16. The method as recited in claim 15, further comprising positioning the tubing hanger by moving the tubing hanger through the subsea Christmas tree.

17. The method as recited in claim 16, further comprising routing the flow passage along an annular line located externally of a primary flow passage through the Christmas tree.

18. The method as recited in claim 15, wherein actuating the valve assembly comprises actuating a flapper valve.

19. The method as recited in claim 15, wherein testing comprises applying a test pressure via a pressure test port when the valve assembly is in a closed position.

20. The method as recited in claim 19, wherein testing comprises establishing the pressure differential at a specific level for a specific time period.