Methods and compositions for stimulating the production of hydrocarbons from subterranean formations

• US 10,087,361 B2
• Filed: 11/06/2017
• Issued: 10/02/2018
• Est. Priority Date: 03/14/2013
• Status: Active Grant

• Current Assignee: Flotek Industries Incorporated
• Original Assignee: Flotek Industries Incorporated
• Inventors: Hill, Randal M., Champagne, Lakia M., Lett, Nathan L., Green, Maria Elizabeth, Saboowala, Hasnain
• Primary Examiner(s): Bates, Zakiya W
• Assistant Examiner(s): Miller, Crystal J
• Application Number:
  US15/804,114
• Publication Number:
  US 20180057733A1
• Time in Patent Office: 330 Days
• CPC Class Codes: C09K 8/584 characterised by the use of specific surfactants
• CPC Class Codes: C09K 8/602 containing surfactants
• CPC Class Codes: C09K 8/92 characterised by their form or by the form of their components, e.g. encapsulated material C09K8/70 takes precedence
• CPC Class Codes: E21B 43/16 Enhanced recovery methods for obtaining hydrocarbons
• CPC Class Codes: E21B 43/26 by forming crevices or fractures

Abstract

Methods and compositions for stimulating of the production of hydrocarbons (e.g., formation crude oil and/or formation gas) from subterranean formations, and methods of selecting a composition for treating an oil or gas well. In some embodiments, the compositions are emulsions or microemulsions, which may include water, a terpene, and a surfactant.

Claims

1. A method of treating a formation crude oil well having a wellbore comprising:

injecting an emulsion or a microemulsion into the wellbore of the formation crude oil well to stimulate displacement of residual aqueous treatment fluid by formation crude oil and increase production of formation crude oil by the well, wherein the emulsion or the microemulsion comprises water, a terpene, and a surfactant;

wherein the ratio of water to terpene is between about 3;

1 and about 1;

2; and

wherein the terpene has a phase inversion temperature greater than or equal to 43°

C.

2. The method of claim 1, wherein the terpene is selected from the group consisting of d-limonene, terpinolene, P-occimene, y-terpinene, a-pinene, and citronellene.

3. The method of claim 1, wherein the emulsion or the microemulsion comprising a first type of terpene and a second type of terpene.

4. The method of claim 1, wherein the emulsion or the microemulsion is diluted with an aqueous fluid prior to injection to the wellbore.

5. The method of claim 1, wherein the emulsion or the microemulsion further comprises a freezing point depression agent.

6. The method of claim 1, wherein the freezing point depression agent comprises an alkylene glycol, an alcohol, and/or a salt.

7. The method of claim 1, wherein the surfactant is selected from the group consisting of nonionic surfactants, anionic surfactants, cationic surfactants and zwitterionic surfactants.

8. A method of treating a formation gas well having a wellbore comprising:

injecting an emulsion or a microemulsion into the wellbore of the formation gas well to stimulate displacement of residual aqueous treatment fluid by formation gas and increase production of formation gas by the well, wherein the emulsion or the microemulsion comprises water, a terpene, and a surfactant;

wherein the ratio of water to terpene is between about 3;

1 and about 1;

2; and

wherein the terpene has a phase inversion temperature less than 43°

C.

9. The method of claim 8, wherein the terpene is selected from the group consisting of linalool, geraniol, nopol, a-terpineol, menthol, eucalyptol and menthone.

10. A method of treating a formation crude oil well having a wellbore comprising:

using an emulsion or a microemulsion to stimulate displacement of residual aqueous treatment fluid by formation crude oil by injecting the emulsion or the microemulsion into the wellbore of the formation crude oil well, and increase production of formation crude oil by the well, wherein the emulsion or the microemulsion comprises water, a terpene, and a surfactant;

wherein the ratio of water to terpene is between about 10;

1 and about 3;

1; and

wherein the terpene has a phase inversion temperature of greater than or equal to 43°

C.

11. The method of claim 10, wherein the terpene is selected from the group consisting of d-limonene, terpinolene, β

-occimene, γ

-terpinene, α

-pinene, and citronellene.

12. The method of claim 10, wherein the emulsion or the microemulsion comprising a first type of terpene and a second type of terpene.

13. The method of claim 10, wherein the emulsion or the microemulsion is diluted with an aqueous fluid prior to injection to the wellbore.

14. The method of claim 10, wherein the emulsion or the microemulsion further comprises a freezing point depression agent.

15. The method of claim 10, wherein the freezing point depression agent comprises an alkylene glycol, an alcohol, and/or a salt.

16. The method of claim 10, wherein the surfactant is selected from the group consisting of nonionic surfactants, anionic surfactants, cationic surfactants and zwitterionic surfactants.

17. A method of treating a formation gas well having a wellbore comprising:

using an emulsion or a microemulsion to stimulate displacement of residual aqueous treatment fluid by gas by injecting the emulsion or the microemulsion into the wellbore of the formation gas well, and increase production of formation gas by the well, wherein the emulsion or the microemulsion comprises water, a terpene, and a surfactant;

wherein the ratio of water to terpene is between about 10;

1 and about 3;

1; and

wherein the terpene has a phase inversion temperature of less than 43°

C.

18. The method of claim 17, wherein the terpene is selected from the group consisting of linalool, geraniol, nopol, α

-terpineol, menthol, eucalyptol and menthone.