Methods and compositions for use in oil and/or gas wells

• US 9,884,988 B2
• Filed: 03/14/2014
• Issued: 02/06/2018
• Est. Priority Date: 03/14/2013
• Status: Active Grant

• Current Assignee: Flotek Industries Incorporated
• Original Assignee: Flotek Industries Incorporated
• Inventors: Dismuke, Keith Ingram, Hill, Randal M., Zelenev, Andrei, Silas, James, Germack, David, Champagne, Lakia M., Hammond, Charles Earl, Pursley, John T., Penny, Glenn S., Bryan, Michael A., Green, Maria Elizabeth, Smith-Gonzalez, Monica, Soeung, Melinda, Saboowala, Hasnain, Fursdon-Welsh, Angus, Lett, Nathan L., Mast, Nicole, Hughes, Joby
• Primary Examiner(s): RUNYAN, SILVANA C
• Application Number:
  US14/212,763
• Publication Number:
  US 20140338911A1
• Time in Patent Office: 1,425 Days
• Field of Search: 166279, 1663051, 1663081, 166285
• CPC Class Codes: C09K 8/035 Organic additives
• 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

Abstract

Methods and compositions comprising an emulsion or a microemulsion for use in various aspects of the life cycle of an oil and/or gas well are provided. In some embodiments, the emulsion or the microemulsion comprises water, a solvent, and a surfactant, and optionally, one or more additives.

Claims

1. A method of treating an oil and/or gas well having a wellbore, comprising:

injecting a solution into the wellbore, wherein the solution comprises;

a stimulation fluid utilized in offshore wells, and

a microemulsion, wherein the microemulsion comprises a water continuous phase, and

wherein the microemulsion comprises;

between about 1 wt % and about 95 wt % water;

between about 1 wt % and about 30 wt % solvent, wherein the solvent comprises a terpene and an ester of fatty acid, wherein the ester of fatty acid has the formula R⁷O(C═

OR⁸), wherein R⁷ and R⁸ are the same or different and are cyclic or acyclic, branched or unbranched C1-16 alkyl, optionally substituted, wherein the ratio of the terpene to the ester of fatty acid by weight is between 1;

2 and 2;

1;

between about 0 wt % and about 50 wt % alcohol;

between about 1 wt % and about 90 wt % surfactant;

between about 0 wt % and about 70 wt % freezing point depression agent; and

between about 0 wt % and about 70 wt % other additives.

2. The method as in claim 1, wherein the water is present in an amount between about 1 wt % and about 90 wt % versus the total microemulsion composition.

3. The method as in claim 1, wherein the microemulsion is diluted and/or combined with a solution prior to and/or during injection.

4. The method as in claim 1, wherein the microemulsion is present in an amount between about 0.1 and about 100 gallons per thousand gallons.

5. The method as in claim 1, wherein the alcohol comprises isopropanol.

6. The method as in claim 1, wherein the alcohol is present in an amount between about 0.1 wt % and about 50 wt % versus the total microemulsion composition.

7. The method as in claim 1, wherein the freezing point depression agent is present in an amount between about 1 wt % and about 40 wt % versus the total microemulsion composition.

8. The method as in claim 1, wherein the other additives are selected from the group consisting of an alcohol, a freezing point depression agent, an acid, a salt, a proppant, a scale inhibitor, a friction reducer, a biocide, a corrosion inhibitor, a buffer, a viscosifier, a clay swelling inhibitor, an oxygen scavenger, and a clay stabilizer.

9. The method as in claim 1, wherein the other additives are present in an amount between about 0 wt % and about 30 wt % versus the total microemulsion composition.

10. The method as in claim 1, wherein the surfactant comprises a first type of surfactant and a second type of surfactant.

11. The method as in claim 1, wherein the surfactant is present in an amount between about 1 wt % and about 60 wt % versus the total microemulsion composition.

12. The method as in claim 1, wherein the solvent is present in an amount between about 2 wt % and about 90 wt % versus the total microemulsion composition.

13. The method as in claim 1, wherein the fluid is the stimulation fluid utilized in offshore wells and the microemulsion is present in the solution in an amount between about 2 and about 5 gallons per thousand gallons.

14. The method as in claim 1, wherein the microemulsion is injected into the wellbore via straight tubing or coiled tubing.