Method to delay swelling of a packer by incorporating dissolvable metal shroud

• US 10,655,423 B2
• Filed: 03/01/2016
• Issued: 05/19/2020
• Est. Priority Date: 03/01/2016
• Status: Active Grant

• Current Assignee: Halliburton Energy Services Incorporated (Halliburton Company)
• Original Assignee: Halliburton Energy Services Incorporated (Halliburton Company)
• Inventors: Stein, Taylor Justin, Adkins, Darrell
• Primary Examiner(s): Buck, Matthew R
• Assistant Examiner(s): Lembo, Aaron L
• Application Number:
  US16/069,849
• Publication Number:
  US 20190048680A1
• Time in Patent Office: 1,540 Days
• CPC Class Codes: E21B 33/12 Packers; Plugs used for cementing E21B33/134, E21B33/16
• CPC Class Codes: E21B 33/1208 characterised by the construction of the sealing or packing means E21B33/1277 takes precedence
• CPC Class Codes: E21B 43/16 Enhanced recovery methods for obtaining hydrocarbons

Abstract

Swellable packer assemblies, and associated systems and methods are described for operation in connection with a subterranean wellbore. The swellable packer assemblies may include a shroud for maintaining a sealing element in a fully inactivated configuration until the packer assemblies reach a predetermined location in the wellbore. The shroud may be formed of a dissolvable metal material such that fluids in the wellbore may remove the shroud, and thereafter the sealing element may be rapidly expanded by exposure to fluids in the wellbore or by exposure to a trigger fluid pumped from the a surface location. The expanded sealing element may establish a seal with an outer tubular structure to isolate adjacent portions of the wellbore.

Claims

1. A swellable packer assembly for positioning in a wellbore, the swellable packer assembly comprising:

a mandrel;

a swellable sealing element disposed radially about the mandrel, the sealing element formed of a material responsive to exposure to a trigger fluid to radially expand from the mandrel;

at least one retaining element fixedly coupled to the mandrel adjacent the sealing element such that the at least one retaining element limits longitudinal movement of the sealing element along the mandrel; and

a shroud sealingly coupled to the at least one retaining element to fluidly isolate the sealing element from an exterior of the shroud and to define an annular cavity disposed radially between the sealing element and the shroud, the shroud selectively removable from the mandrel downhole so as to expose the sealing element to the trigger fluid in the wellbore.

2. The swellable packer assembly of claim 1, wherein the shroud is constructed of a dissolvable metal material.

3. The swellable packer assembly of claim 2, wherein the dissolvable metal material comprises at least one of a magnesium alloy, an aluminum alloy, nickel, copper, and tin.

4. The swellable packer assembly of claim 2, wherein the dissolvable metal material exhibits a thickness of at least about 0.0179 inches or at least about 18 mils.

5. The swellable packer assembly of claim 1, wherein the annular cavity is filled with a substantially non-compressible fluid.

6. The swellable packer assembly of claim 1, wherein the mandrel defines a longitudinal passageway therethrough.

7. A method of using a swellable packer assembly comprising:

running the swellable packer assembly into a wellbore on a conveyance to position the swellable packer assembly at a predetermined downhole location with a swellable sealing element of the swellable packer assembly in an inactivated configuration wherein a shroud is sealingly coupled to retaining elements disposed on each longitudinal side of the sealing element to define an annular cavity radially between the sealing element and the shroud;

removing the shroud from the retaining elements, subsequent to running the swellable packer assembly into the wellbore;

flooding the annular cavity with a wellbore fluid disposed at the predetermined downhole location in response to removing the shroud; and

exposing the sealing element to a trigger fluid in the wellbore at the predetermined location to thereby activate to sealing element to induce swelling of the sealing element.

8. The method of claim 7, wherein removing the shroud further comprises dissolving a dissolvable material of the shroud with wellbore fluid disposed at the predetermined downhole location.

9. The method of claim 8, wherein exposing the sealing element to the trigger fluid further comprises pumping the trigger fluid into the wellbore from a surface location subsequent to running the swellable packer assembly into the wellbore.

10. The method of claim 7, further comprising fluidly isolating at least two adjacent portions of the wellbore with the sealing element subsequent to exposing the sealing element to the trigger fluid.

11. The method of claim 10, further comprising producing a wellbore fluid from or injecting an injection fluid into an individual one of the adjacent portions of the wellbore.

12. A downhole swellable packer system comprising:

a conveyance;

a mandrel coupled within the conveyance;

a swellable sealing element disposed about the one mandrel, the sealing element formed of a material responsive to exposure to a trigger fluid to radially expand from the mandrel;

at least one retaining element coupled to the mandrel adjacent the sealing element such that the at least one retaining element limits longitudinal movement of the sealing element along the mandrel; and

a shroud coupled to the at least one retaining element to fluidly isolate the sealing element from an exterior of the shroud and to define an annular cavity disposed radially between the sealing element and the shroud, the shroud constructed of a dissolvable material and substantially spaced in a radial direction from an outer surface of the sealing element.

13. The downhole swellable packer system of claim 12, further comprising a downhole tool coupled within the conveyance, wherein the downhole tool is longitudinally spaced from the sealing element such that the sealing element may fluidly isolate the downhole tool in an individual portion of the wellbore.

14. The downhole swellable packer system of claim 13, wherein the conveyance is a tubing string and the downhole tool is an inflow control valve operable to selectively permit fluid communication between the wellbore and the tubing string.

15. The downhole swellable packer system of claim 12, further comprising a first source of trigger fluid selectively deliverable to the sealing element.

16. The downhole swellable packer system of claim 15, further comprising a second sealing element and a source of a second distinct trigger fluid, wherein the second sealing element is formed of a material responsive to exposure to the second distinct trigger fluid to radially expand.