Shifting tool assembly that facilitates controlled pressure equalization

• US 10,041,331 B2
• Filed: 02/18/2015
• Issued: 08/07/2018
• Est. Priority Date: 02/18/2015
• Status: Active Grant

• Current Assignee: Halliburton Energy Services Incorporated (Halliburton Company)
• Original Assignee: Halliburton Energy Services Incorporated (Halliburton Company)
• Inventors: Ross, Colby Munro, Garrison, Gregory William
• Primary Examiner(s): Andrish, Sean D
• Application Number:
  US14/782,849
• Publication Number:
  US 20160362960A1
• Time in Patent Office: 1,266 Days
• CPC Class Codes: E21B 2200/04 Ball valves
• CPC Class Codes: E21B 2200/06 Sleeve valves
• CPC Class Codes: E21B 33/12 Packers; Plugs used for cementing E21B33/134, E21B33/16
• CPC Class Codes: E21B 34/10 operated by control fluid supplied from outside the borehole
• CPC Class Codes: E21B 34/14 operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools E21B34/066 takes precedence
• CPC Class Codes: E21B 47/06 Measuring temperature or pressure

Abstract

An exemplary downhole system includes a completion string positioned within a wellbore and providing at least an upper seal bore and a downhole device that includes a sliding sleeve. A service tool is extendable within the completion string and includes a shifting tool assembly and provides a mandrel, a shifting tool coupled to the mandrel, and upper equalization seals arranged on the mandrel and sealingly engageable with the upper seal bore. The shifting tool is engageable with the sliding sleeve to move the downhole device at least partially between a closed position, where a pressure differential between a subterranean formation and an interior of the completion string is assumed by primary sealing elements of the downhole device, and an open position, where the pressure differential is assumed by at least the upper equalization seals.

Claims

1. A downhole system, comprising:

a completion string positionable within a wellbore and providing at least an upper seal bore, a lower seal bore axially offset from the upper seal bore, and a downhole device arranged downhole from the upper seal bore, wherein the downhole device provides a sliding sleeve;

a service tool extendable within the completion string; and

a shifting tool assembly coupled to the service tool and including a mandrel, a shifting tool coupled to the mandrel, one or more upper equalization seals arranged on the mandrel and configured to be sealably disposed within the upper seal bore, and one or more lower equalization seals arranged on the mandrel and configured to be sealably disposed within the lower seal bore,

wherein the shifting tool is engageable with the sliding sleeve to move the downhole device at least partially between a closed position, where a pressure differential between a subterranean formation and an interior of the completion string is borne by primary sealing elements of the downhole device, and an open position, where the pressure differential is borne by at least the one or more upper equalization seals,

wherein the pressure differential is borne by at least the one or more upper equalization seals while the downhole device is moved between the closed and open positions, and

wherein a differentially isolated chamber is defined between the completion string and the service tool when the upper and lower equalization seals are sealingly disposed in the upper and lower seal bores.

2. The downhole system of claim 1, wherein the downhole device is the sliding sleeve and the downhole system further comprises:

one or more flow ports defined in the completion string at the sliding sleeve to place the subterranean formation in fluid communication with the interior, wherein the sliding sleeve occludes the one or more flow ports when in the closed position, wherein the lower seal bore is provided by the completion string, and the sliding sleeve is axially positioned between the upper and lower seal bores.

3. The downhole system of claim 2, wherein the one or more upper equalization seals are axially spaced from the one or more lower equalization seals such that each of the one or more upper equalization seals and each of the one or more lower equalization seals is able to simultaneously seal against the upper and lower seal bores, respectively, while the shifting tool moves the sliding sleeve between the open and closed positions.

4. The downhole system of claim 3, wherein the sliding sleeve is arranged in the differentially isolated chamber.

5. The downhole system of claim 4, wherein the shifting tool assembly further includes a choke defined through the mandrel and arranged axially between the upper and lower equalization seals, the choke being in fluid communication with the differentially isolated chamber and configured to dissipate the pressure differential by allowing a metered amount of fluid out of the differentially isolated chamber.

6. The downhole system of claim 4, wherein the one or more lower equalization seals comprise a first set of lower equalization seals and a second set of equalization seals axially spaced from the first set of lower equalization seals on the mandrel, and wherein the shifting tool assembly further includes a choke defined through the mandrel and arranged axially between the first and second sets of lower equalization seals, the choke being configured to dissipate the pressure differential by allowing a metered amount of the fluid out of the differentially isolated chamber when the first set of lower equalization seals moves out of sealed engagement with the lower seal bore.

7. The downhole system of claim 2, wherein the upper and lower equalization seals are axially spaced from each other such that, while moving the shifting tool assembly with respect to the completion string, the one or more lower equalization seals sealingly engage the lower seal bore prior to the one or more upper equalization seals sealingly engaging the upper seal bore.

8. The downhole system of claim 7, wherein a differentially isolated chamber is defined by the service tool and the completion string when the one or more lower equalization seals sealingly engage the lower seal bore, and wherein the differentially isolated chamber is at least partially filled with a fluid to minimize a volume required to be equalized across the sliding sleeve as the sliding sleeve moves between the closed and open positions.

9. The downhole system of claim 2, wherein each of the one or more upper and lower equalization seals comprises a seal selected from the group consisting of a baffle seal, a seal ring, and a one-way seal.

10. The downhole system of claim 1, wherein the downhole device is a ball valve and the sliding sleeve is operatively coupled to the ball valve such that movement of the sliding sleeve within the completion string correspondingly moves the ball valve between the open and closed positions.

11. The downhole system of claim 10, wherein the shifting tool assembly further includes a bull plug positioned within the mandrel and a weep tube that extends through the bull plug to provide fluid communication through the bull plug, and wherein the weep tube dissipates the pressure differential by allowing a metered amount of the fluid to bypass the bull plug when the one or more upper equalization seals sealingly engage the upper seal bore.

12. The downhole system of claim 10, wherein the one or more upper equalization seals comprise a seal selected from the group consisting of a baffle seal, a seal ring, and a one-way seal.

13. A method, comprising:

introducing a service tool into a wellbore, the wellbore having a completion string positioned therein that provides at least an upper seal bore, a lower seal bore axially offset from the upper seal bore, and a downhole device, wherein the downhole device is arranged downhole from the upper seal bore and includes a sliding sleeve;

extending the service tool at least partially into the completion string, the service tool providing a shifting tool assembly that includes a mandrel, a shifting tool coupled to the mandrel, one or more upper equalization seals arranged on the mandrel uphole from the shifting tool, and one or more lower equalization seals arranged on the mandrel and configured to be sealably disposed within the lower seal bore;

sealingly disposing the one or more upper equalization seals and the one or more lower equalization seals on the respective upper seal bore and lower seal bore, wherein a differentially isolated chamber is defined between the completion string and the service tool upon sealingly disposing the upper and lower equalization seals within the upper and lower seal bores, respectively;

engaging the shifting tool on the sliding sleeve to move the downhole device at least partially between a closed position, where a pressure differential between a subterranean formation and an interior of the completion string is borne by primary sealing elements of the downhole device, and an open position, where the pressure differential is borne by at least the one or more upper equalization seals; and

bearing the pressure differential by at least the one or more upper equalization seals while the downhole device is moving between the closed and open positions.

14. The method of claim 13, wherein the downhole device is the sliding sleeve and the lower seal bore is provided by the completion string, the sliding sleeve being positioned between the upper and lower seal bores, the method further comprising:

occluding one or more flow ports defined in the completion string with the sliding sleeve upon placing the sliding sleeve to the closed position, the one or more flow ports placing the subterranean formation in fluid communication with the interior upon placing the sliding sleeve in the open position.

15. The method of claim 14, wherein the upper and lower equalization seals are axially spaced from each other on the mandrel, the method further comprising:

moving the sliding sleeve between the open and closed positions with the shifting tool; and

simultaneously sealing against the upper and lower seal bores with the upper and lower equalization seals, respectively, as the sliding sleeve is moved between the open and closed positions.

16. The method of claim 15, further comprising:

ceasing fluid flow through the one or more flow ports upon sealingly disposing the upper and lower seal bores within the upper and lower equalization seals, respectively; and

bearing the pressure differential with the upper and lower equalization seals while the sliding sleeve is moved between the closed and open positions.

17. The method of claim 16, wherein the shifting tool assembly further includes a choke defined in the mandrel and arranged axially between the upper and lower equalization seals and in fluid communication with the differentially isolated chamber, the method further comprising:

allowing a metered amount of the fluid out of the differentially isolated chamber via the choke; and

dissipating the pressure differential with the choke.

18. The method of claim 17, further comprising monitoring a pressure differential between the differentially isolated chamber and the interior with a pressure monitoring device.

19. The method of claim 16, wherein the upper and lower equalization seals comprise one-way seals, the method further comprising:

injecting a fluid into the differentially isolated chamber across the one of the upper and lower equalization seals in a first direction;

preventing the fluid from migrating across the one of the upper and lower equalization seals in a second direction opposite the first direction; and

filling the differentially isolated chamber at least partially with the fluid and thereby minimizing a volume required to be equalized across the sliding sleeve as the sliding sleeve moves between the closed and open positions.

20. The method of claim 16, wherein the one or more lower equalization seals comprise a first set of lower equalization seals and a second set of lower equalization seals axially spaced from the first set of lower equalization seals, the method further comprising:

moving the first set of lower equalization seals out of sealed engagement with the lower seal bore;

allowing a metered amount of the fluid out of the differentially isolated chamber via a choke defined in the mandrel and arranged axially between the first and second sets of lower equalization seals; and

dissipating the pressure differential with the choke.

21. The method of claim 14, wherein sealingly disposing the one or more upper equalization seals on the upper seal bore is preceded by:

moving the shifting tool assembly with respect to the completion string; and

sealingly disposing the lower seal bore with the one or more lower equalization seals; and

filling the differentially isolated chamber at least partially with a fluid and thereby minimizing a volume required to be equalized across the sliding sleeve as the sliding sleeve moves between the closed and open positions.

22. The method of claim 14, further comprising:

retrieving the service tool to a surface location; and

redressing, rehabilitating, or replacing the one or more upper and lower equalization seals upon returning the service tool to the surface location.

23. The method of claim 13, wherein the downhole device is a ball valve and the sliding sleeve is operatively coupled to the ball valve, and the shifting tool assembly further includes a bull plug positioned within the mandrel and a weep tube that extends through the bull plug to facilitate fluid communication through the bull plug, the method further comprising:

moving the sliding sleeve within the completion string with the shifting tool and thereby correspondingly moving the ball valve between the open and closed positions;

allowing a metered amount of the fluid to bypass the bull plug via the weep tube; and

dissipating the pressure differential with the weep tube.

24. The method of claim 23, further comprising:

retrieving the service tool to a surface location; and

redressing, rehabilitating, or replacing the one or more upper equalization seals upon returning the service tool to the surface location.