Methods and compositions for reducing corrosivity of aqueous fluids

Patent metadata

Field	Value
Publication number	US-11414592-B2
Application number	US-202016782570-A
Country	US
Kind code	B2
Filing date	Feb 5, 2020
Priority date	May 3, 2019
Publication date	Aug 16, 2022
Grant date	Aug 16, 2022

Abstract

Methods and compositions for treating aqueous fluids that may be included in treatment fluids that are used for treating a subterranean formation. In some embodiments, the methods include: providing a treatment fluid including an aqueous fluid and a composition that includes an oxygen scavenger, a pH-adjusting agent, and a corrosion inhibitor, wherein the aqueous fluid is aerated; contacting a metal surface with the treatment fluid; and introducing the treatment fluid into a wellbore penetrating at least a portion of a subterranean formation.

First claim

What is claimed is:

1. A method comprising:
providing a treatment fluid comprising an aqueous fluid and a composition that comprises an oxygen scavenger, a pH-adjusting agent, and a corrosion inhibitor,
wherein the aqueous fluid is aerated by being exposed to any gas,
wherein the corrosion inhibitor is a film-forming surfactant,
wherein the aqueous fluid comprises an at least one salt selected from the group consisting of: NaBr, KBr, CaCl2, CaBr2, ZnBr2, KCl, NaCl, MgCl2, SrCl2, BaCl2, NaHCO3, NaSO4, a carbonate salt, a sulfide salt, a magnesium salt, a bromide salt, a formate salt, and an acetate salt, and
wherein the treatment fluid does not comprise a phosphate salt;

contacting a metal surface with the treatment fluid; and
introducing the treatment fluid into a wellbore penetrating at least a portion of a subterranean formation.

2. The method of claim 1 , wherein the aqueous fluid comprises a brine or produced water.

3. The method of claim 1 , wherein the metal surface comprises a low alloy carbon steel.

4. The method of claim 1 , wherein the metal surface is located on one or more of a pipe, a storage tank, a valve, a manifold, or a pump used to deliver the treatment fluid into the wellbore.

5. The method of claim 1 , wherein the step of providing the treatment fluid comprises continuously adding the composition to the aqueous fluid.

6. The method of claim 1 , wherein the treatment fluid further comprises one or more additional additives.

7. The method of claim 1 , further comprising adding one or more additional additives to the treatment fluid.

8. The method of claim 1 further comprising allowing the oxygen scavenger to reduce an amount of oxygen in the aqueous fluid by at least 95% within about 60 minutes.

9. The method of claim 1 further comprising allowing the pH-adjusting agent to increase the pH of the aqueous fluid to a level between about 7 and about 9.

10. The method of claim 1 , wherein the treatment fluid is introduced into the wellbore at or above a pressure sufficient to create or enhance one or more fractures within the subterranean formation.

11. A method comprising:
providing a fracturing fluid comprising an aqueous fluid, one or more additives, and a composition comprising an oxygen scavenger, a pH-adjusting agent, and a corrosion inhibitor,
wherein the aqueous fluid comprises dissolved oxygen gas in an amount of from about 4 ppm to about 14 ppm,
wherein the corrosion inhibitor is a film-forming surfactant,
wherein the aqueous fluid comprises an at least one salt selected from the group consisting of: NaBr, KBr, CaCl2, CaBr2, ZnBr2, KCl, NaCl, MgCl2, SrCl2, BaCl2, NaHCO3, NaSO4, a carbonate salt, a sulfide salt, a magnesium salt, a bromide salt, a formate salt, and an acetate salt, and
wherein the treatment fluid does not comprise a phosphate salt;

contacting a metal surface with the fracturing fluid; and
introducing the fracturing fluid into the wellbore at or above a pressure sufficient to create or enhance one or more fractures within the subterranean formation.

12. The method of claim 11 , wherein the composition is present in the aqueous fluid in an amount from about 50 ppm to about 5,000 ppm by volume of the aqueous fluid.

13. The method of claim 11 , wherein the metal surface comprises a low alloy carbon steel and is located on a pipe, a storage tank, a valve, a manifold, or a pump used to deliver the treatment fluid into the wellbore.

14. The method of claim 11 further comprising allowing the pH-adjusting agent to increase the pH of the aqueous fluid to a range from about 7 to about 9.

15. The method of claim 11 further comprising allowing the oxygen scavenger to reduce the amount of oxygen gas in the aqueous fluid by at least 95% within about 60 minutes.

16. The method of claim 11 , wherein the composition is added to the aqueous fluid to form the fracturing fluid, and wherein the composition is stored for up to 12 months before is it added to the aqueous fluid.

Assignees

• Halliburton Energy Services Inc

Inventors

• Davis Nathan Darrell
• Prince Philippe

Classifications

• C09K8/94

  Foams · CPC title

• C09K8/68 Primary

  containing organic compounds · CPC title

• C09K2208/34

  Lubricant additives · CPC title

• C09K8/80

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

• E21B21/062

  by mixing components · CPC title