Micro-aggregates and microparticulates for use in subterranean formation operations

Patent metadata

Field	Value
Publication number	US-10988677-B2
Application number	US-201616304100-A
Country	US
Kind code	B2
Filing date	Jun 22, 2016
Priority date	Jun 22, 2016
Publication date	Apr 27, 2021
Grant date	Apr 27, 2021

Abstract

Methods and systems employing a flocculation polymer and microparticulates. The flocculation polymer flocculates the microparticulates to form micro-aggregates for use in forming complex fracture networks. Additionally, the flocculation causes the flocculation polymer to be removed from a treatment fluid due to its interaction with the microparticulates, thereby effectively cleaning the flocculation polymer from a subterranean formation. Individual microparticulates are synergistically used alone or in the presence of a de-aggregating agent to enhance complex fracture networks.

First claim

What is claimed is:

1. A method comprising:
(a) introducing a first treatment fluid into a subterranean formation at a pressure above a fracture gradient of the subterranean formation to create or enhance at least one dominate fracture, wherein the first treatment fluid comprises a first polar base fluid and a first flocculation polymer;
(b) introducing a second treatment fluid into the subterranean formation at a pressure above a fracture gradient to create or enhance at least one branch fracture extending from the at least one dominate fracture, wherein the second treatment fluid comprises a second polar base fluid, a second flocculation polymer, and first microparticulates;
(c) flocculating the first microparticulates with a flocculation polymer selected from the group consisting of the first flocculation polymer, the second flocculation polymer, and any combination thereof to form micro-aggregates;
(d) placing the micro-aggregates in the at least one branch fracture, thereby forming a partial monolayer therein;
(e) introducing a third treatment fluid into the subterranean formation at a pressure above the fracture gradient, wherein the third treatment fluid comprises a third polar base fluid, a third flocculation polymer, and a de-aggregating agent; and
(f) closing the facture, wherein during fracture closure a second microparticulates leaks off into the at least one branch fracture.

2. The method of claim 1 , further comprising between (a) and (b):
introducing a fourth treatment fluid into the subterranean formation at a rate and pressure above the fracture, the fourth treatment fluid comprising a fourth polar base fluid and third microparticulates, and
flocculating the third microparticulates with the first flocculation polymer, thereby removing at least a portion of the first flocculation polymer from contact with the subterranean formation.

3. The method of claim 1 , wherein the first flocculation polymer is a polyacrylamide-polyacrylate copolymer and the second flocculation polymer is a polyacrylamide-polyacrylate copolymer, and each comprise a ratio of about 5% to about 10% by molar % of polyacrylamide to polyacrylate.

4. The method of claim 1 , wherein the first flocculation polymer is present in the first treatment fluid in a concentration of about 0.01% to about 0.5% by volume of the first polar base fluid.

5. The method of claim 1 , wherein the second flocculation polymer is present in the second treatment fluid in a concentration of about 0.01% to about 0.5% by volume of the second polar base fluid.

6. The method of claim 1 , wherein the third flocculation polymer is present in the third treatment fluid in a concentration of about 0.01% to about 0.5% by volume of the third polar base fluid.

7. The method of claim 1 , wherein the first microparticulates, the second microparticulates, and any combination thereof have a unit mesh size in the range of about 0.1 micrometer to about 150 micrometer.

8. The method of claim 1 , wherein the first microparticulates are present in a concentration of about 10% to about 70% by weight of the second polar base fluid.

9. The method of claim 1 , wherein the second microparticulates are present in a concentration of about 10% to about 70% by weight of the third polar base fluid.

10. The method of claim 1 , further comprising a tubular extending into the subterranean formation through a wellhead, and a pump fluidly coupled to a tubular, wherein a treatment fluid selected from the group consisting of the first treatment fluid, the second treatment fluid, the third treatment fluid, and any combination thereof is introduced into the subterranean formation through the tubular.

11. A method comprising:
(a) introducing a first treatment fluid into a subterranean formation at a pressure above a fracture gradient of the subterranean formation to create or enhance at least one dominate fracture, wherein the first treatment fluid comprises a first polar base fluid and a first flocculation polymer;
(b) introducing a second treatment fluid into the subterranean formation at a pressure above a fracture gradient to create or enhance at least one branch fracture extending from the at least one dominate fracture, wherein the second treatment fluid comprises a second polar base fluid, a second flocculation polymer, and first microparticulates;
(c) flocculating the first microparticulates with a flocculation polymer selected from the group consisting of the first flocculation polymer, the second flocculation polymer, and any combination thereof to form micro-aggregates;
(d) placing the micro-aggregates in the at least one branch fracture, thereby forming a partial monolayer therein;
(e) introducing a third treatment fluid into the subterranean formation at a pressure above the fracture gradient, wherein the third treatment fluid comprises a third polar base fluid, a third flocculation polymer, second microparticulates, and a de-aggregating agent;
(f) placing the second microparticulates into the at least one branch fracture; and
(g) introducing a fourth treatment fluid into the subterranean formation at a pressure above the fracture gradient, wherein the fourth treatment fluid comprises a fourth polar base fluid and proppant particulates; and
(h) placing the proppant particulates into the at least one dominate fracture; and
(i) closing the facture, wherein during fracture closure the second microparticulates leaks off into the at least one branch fracture.

12. The method of claim 11 , further comprising between (a) and (b):
introducing a fifth treatment fluid into the subterranean formation at a rate and pressure above the fracture, wherein the fifth treatment fluid comprises a fifth polar base fluid and third microparticulates, and
flocculating the third microparticulates with the first flocculation polymer, thereby removing at least a portion of the first flocculation polymer from contact with the subterranean formation.

13. The method of claim 11 , wherein the first flocculation polymer is a polyacrylamide-polyacrylate copolymer, the second flocculation polymer is a polyacrylamide-polyacrylate copolymer, and the third flocculation polymer is a polyacrylamide-polyacrylate copolymer, and each comprise a ratio of about 5% to about 10% by molar % of polyacrylamide to polyacrylate.

14. The method of claim 11 , wherein the first flocculation polymer is present in the first treatment fluid in a concentration of about 0.01% to about 0.5% by volume of the first polar base fluid.

15. The method of claim 11 , wherein the second flocculation polymer is present in the second treatment fluid in a concentration of about 0.01% to about 0.5% by volume of the second polar base fluid.

16. The method of claim 11 , wherein the third flocculation polymer is present in the third treatment fluid in a concentration of about 0.01% to about 5% by volume of the third polar base fluid.

17. The method of claim 11 , wherein the first microparticulates, the second microparticulates, and any combination thereof have a unit mesh size in the range of about 0.1 micrometer to about 150 micrometer.

18. The method of claim 11 , wherein the de-aggregating agent is present in the third treatment fluid in a concentration of about 0.05% to about 5% by volume of the third flocculation polymer.

19. The method of claim 11 , further comprising metering the proppant particulates in the fourth treatment fluid as the fourth treatment fluid is introduced into the subterranean formation, and wherein the proppant particulates gradually increase

Assignees

• Halliburton Energy Services Inc

Inventors

• Montalvo Janette Cortez
• Nguyen Philip D
• Vo Loan K
• Larsen Travis Hope
• Singh Dipti
• Dusterhoft Ronald

Classifications

• C09K8/80 Primary

  Compositions for reinforcing fractures, e.g. compositions of proppants used to keep the fractures open · CPC title

• C09K8/88

  macromolecular compounds · CPC title

• C09K8/70 Primary

  characterised by their form or by the form of their components, e.g. foams · CPC title

• C09K8/68

  containing organic compounds · CPC title

• E21B43/267

  reinforcing fractures by propping · CPC title