Synchronic dual packer with energized slip joint

• US 9,580,990 B2
• Filed: 05/21/2015
• Issued: 02/28/2017
• Est. Priority Date: 06/30/2014
• Status: Active Grant

• Current Assignee: Baker Hughes Holdings LLC (Baker Hughes Company)
• Original Assignee: Baker Hughes Incorporated (Baker Hughes Company)
• Inventors: Flores, Juan Carlos, McKitrick, Robert
• Primary Examiner(s): Andrews, David
• Assistant Examiner(s): RUNYAN, RONALD R
• Application Number:
  US14/718,693
• Publication Number:
  US 20150376975A1
• Time in Patent Office: 649 Days
• US Class Current: 1/1
• CPC Class Codes: E21B 23/006 "J-slot" systems, i.e. lug and slot indexing mechanisms
• CPC Class Codes: E21B 23/06 for setting packers
• CPC Class Codes: E21B 33/124 Units with longitudinally-spaced plugs for isolating the intermediate space
• CPC Class Codes: E21B 33/128 with a member expanded radially by axial pressure E21B33/122, E21B33/124 take precedence

Abstract

A downhole tool having a first packing element and a second packing element configured to synchronically set to selectively hydraulically isolate a portion of the wellbore. The lower packing element may be first set against the well with the upper packing element next being set against the well. A slip joint permits a change in distance between the packing elements during the setting of the packing elements. The slip joint may be energized to apply a force to the lower packing element to prevent the unsetting of the lower packing element during the setting of the upper packing element. A resilient member may be used to energize the slip joint or the slip joint could be hydraulically or pneumatically energized. Once both packing elements are set, the wellbore may then be treated by flowing fluid out of a ported sub positioned between the packing elements.

Claims

1. A dual packer comprising:

a first packing element movable between a set position and a running position;

a first sleeve having a first continuous j-slot track that extends completely around a perimeter of the first sleeve, wherein movement of a first pin along the first continuous j-slot track actuates the first packing element between the set position and the running position;

a second packing element movable between a set position and a running position;

a second sleeve having a second continuous j-slot track that extends completely around a perimeter of the second sleeve, wherein movement of a second pin along the second continuous j-slot track actuates the second packing element between the set position and the running position, wherein the second j-slot track is inverted with respect to the first j-slot track; and

a slip joint positioned between the first packing element and the second packing element, wherein the slip joint is configured to change a length between the first and second packing elements.

2. The dual packer of claim 1, wherein the slip joint is energized.

3. The dual packer of claim 2, wherein the slip joint is comprised of an upper portion and a lower portion, the upper and lower portions move relative to one another to change the length between the first and second packing element.

4. The dual packer of claim 3, wherein a resilient member positioned between a shoulder of the upper portion and a shoulder of the lower portion energizes the slip joint.

5. The dual packer of claim 2, wherein the energized slip joint applies a force on the second packing element when the second packing element is in the set position.

6. The dual packer of claim 5, wherein the slip joint is energized by a resilient member.

7. The dual packer of claim 5, the slip joint further comprising a chamber, wherein the chamber energizes the slip joint.

8. The dual packer of claim 7, wherein the chamber is hydraulically or pneumatically pressurized.

9. The dual packer of claim 7, wherein the slip joint is energized by a resilient member positioned within the chamber.

10. A system to isolate and treat a portion of a wellbore comprising:

an upper packer;

a first sleeve having a continuous j-slot track that extends completely around a perimeter of the first sleeve, wherein movement of a first pin along the continuous j-slot track of the first sleeve actuates the upper packer between a set position and a running position;

a lower packer;

a second sleeve having a continuous j-slot track that extends completely around a perimeter of the second sleeve wherein the j-slot track of the second sleeve is inverted with respect to the j-slot track of the first sleeve, wherein movement of a second pin along the continuous j-slot track of the second sleeve actuates the lower packer between a set position and a running position;

a ported sub being connected between the upper packer and the lower packer; and

a slip joint being connected between the upper packer and the lower packer, the slip joint is configured to change a length between the upper and lower packers.

11. The system of claim 10, wherein the slip joint is energized to provide a force on the lower packer when the lower packer is in the set position.

12. The system of claim 11, wherein the slip joint is energized hydraulically, pneumatically, or by a resilient member.

13. The system of claim 11, further comprising a work string connected to the upper packer, wherein fluid may be pumped down the work string and out the ported sub.

14. The system of claim 10, wherein the upper packer in a set position and the lower packer in a set position are connected together via the slip joint and the ported sub.

15. A method of isolating a portion of a wellbore comprising:

running a tool on a work string into a wellbore;

positioning the tool adjacent a portion of the wellbore;

picking up the work string to move a first pin along a continuous j-slot track of a first sleeve that extends completely around a perimeter of the first sleeve and to move a second pin along a continuous j-slot track of a second sleeve that extends completely around a perimeter of the second sleeve, wherein the j-slot track of the second sleeve is inverted with respect to the j-slot track of the first sleeve;

setting a lower packer of the tool;

applying a force to the set lower packer; and

setting an upper packer of the tool after setting the lower packer.

16. The method of claim 15, further comprising treating a formation of the wellbore through a port in a tubular.

17. The method of claim 16, wherein treating the formation of the wellbore further comprises at least one of fracturing, re-fracturing, stimulating, tracer injection, cleaning, acidizing, steam injection, water flooding, and cementing.

18. The method of claim 16, further comprising releasing the upper packer of the tool and releasing the lower packer of the tool after releasing the upper packer.

19. The method of claim 15, wherein an energized slip joint applied the force to the set lower packer.

20. The method of claim 19, wherein a resilient member energizes the slip joint.

21. The method of claim 20, wherein the resilient member is positioned between two shoulders of the slip joint.

22. The method of claim 19, wherein the slip joint is energized hydraulically or pneumatically.