Methods for determining an optimal surfactant structure for oil recovery

Patent metadata

Field	Value
Publication number	US-10995260-B2
Application number	US-201816170416-A
Country	US
Kind code	B2
Filing date	Oct 25, 2018
Priority date	May 9, 2017
Publication date	May 4, 2021
Grant date	May 4, 2021

Abstract

Methods for evaluating an optimal surfactant structure for oil recovery by systematically evaluating surfactants' phase behavior, cloud point, dynamic interfacial tension, dynamic contact angle, and spontaneous and forced imbibition. In one embodiment, a method for determining an optimal surfactant structure for oil recovery includes the steps of evaluating a surfactant's phase behavior, evaluating the surfactant's solubility, evaluating the surfactant's dynamic interfacial tension in a porous rock sample, evaluating the surfactant's static and dynamic contact angles in the porous rock sample, evaluating the surfactant's spontaneous imbibition in the porous rock sample, and evaluating the surfactant's forced imbibition in the porous rock sample. In one example, the surfactant comprises a polyoxyethylenated (POE) straight-chain alcohol.

First claim

We claim:

1. A method for determining an optimal surfactant structure for oil recovery, comprising the steps of:
(a) evaluating a surfactant's phase behavior;
(b) evaluating the surfactant's solubility;
(c) evaluating the surfactant's dynamic interfacial tension;
(d) evaluating the surfactant's static and dynamic contact angles in a porous rock sample;
(e) evaluating the surfactant's spontaneous imbibition in the porous rock sample; and
(f) evaluating the surfactant's forced imbibition in the porous rock sample via a core holder apparatus, wherein the evaluating the surfactant's forced imbibition comprises:
placing the porous rock sample in the core holder apparatus;
injecting a brine solution into the porous rock sample;
injecting oil into the porous rock sample; and
injecting a surfactant solution into the porous rock sample.

2. The method of claim 1 , wherein the method is carried out with a surfactant concentration above a critical micelle concentration.

3. The method of claim 1 , wherein the surfactant's phase behavior is evaluated by visualizing a microemulsion middle phase at ambient and high temperatures.

4. The method of claim 1 , wherein the surfactant's solubility is evaluated by determining the surfactant's cloud point temperature at ambient conditions and at reservoir conditions.

5. The method of claim 1 , wherein the surfactant's dynamic interfacial tension is evaluated at ambient conditions and at reservoir conditions.

6. The method of claim 1 , wherein the surfactant's dynamic interfacial tension is evaluated by (i) creating a bubble of crude oil inside a measurement cell; (ii) capturing oil bubble images; and (iii) fitting drop profiles to the Young-Laplace equation.

7. The method of claim 6 , wherein oil bubble images are captured at time intervals ranging from 1 second to 100 seconds.

8. The method of claim 1 , wherein the surfactant's static and dynamic contact angles are evaluated at ambient conditions and at reservoir conditions.

9. A method of claim 1 , wherein the surfactant's static contact angle is evaluated by (i) vacuum saturating a rock sample with crude oil; (ii) immersing the saturated rock sample in the brine solution (iii) capturing oil bubble images; and (iv) measuring an angle made by a tangent line on the oil bubble images through the brine solution.

10. The method of claim 1 , wherein the surfactant's dynamic contact angle is evaluated by (i) creating bubbles of crude oil inside a measurement cell; (ii) capturing oil bubble images as oil bubbles are injected or retracted beneath a surface of a rock sample; and (iii) measuring angles made by a tangent line on the oil bubble images through the brine solution using imaging software.

11. The method of claim 1 , wherein the surfactant's spontaneous imbibition is evaluated at ambient conditions.

12. The method of claim 11 , wherein the brine solution is a first brine solution; and wherein surfactant's spontaneous imbibition is further evaluated by (i) saturating a rock sample in crude oil; (ii) exposing the saturated rock sample to a second brine solution; and (iii) measuring oil production resulting from brine imbibition.

13. The method of claim 1 , further comprising the step of determining permeability to brine of the porous rock sample and average porosity of the rock sample after the injecting bring solution step.

14. The method of claim 1 , further comprising the step of determining initial water saturation after the injecting oil step.

15. The method of claim 1 , wherein the injecting a surfactant solution step comprises injecting the surfactant solution at a constant flow rate.

16. The method of claim 15 , wherein the flow rate of surfactant solution injection is in a range from 0.001 cc/min to 5 cc/min.

17. The method of claim 1 , further comprising the step of determining residual oil saturation after the injecting a surfactant solution step.

18. The method of claim 1 , comprising injecting oil into the porous rock sample after the injecting a surfactant solution step.

19. The method of claim 1 , wherein the surfactant comprises one or more polyoxyethylenated (POE) straight-chain alcohols.

20. The method as in claim 19 , wherein the POE straight-chain alcohol has the formula:
CH 3 (CH 2 ) x (OC 2 H 4 ) y OH
wherein x is 8-10 and y is 2.5, 6-6.5, 8, or 8.3; or
wherein x is 10 and y is 3, 5, 7, or 9; or
wherein x is 11-12 and y is 3; or
wherein x is 11-13 and y is 8.2; or
wherein x is 11-14 and y is 3, 7.25, 8.2, 8.3, 9, 15, or 18.

21. The method as in claim 19 , wherein the POE straight-chain alcohol has the formula:
CH 3 (CH 2 ) x (OC 2 H 4 ) y OH
wherein x is 8-10 and y is 2.5, 6, or 8; or
wherein x is 11-14 and y is 3, 7.25, 8.2, or 18.

22. The method as in claim 19 , wherein the POE straight-chain alcohol has the formula:
CH 3 (CH 2 ) 11-14 (OC 2 H 4 ) 18 OH.

Assignees

• Univ Wyoming

Inventors

• Piri Mohammad
• Goual Lamia
• Mirchi Vahideh
• Akbarabadi Morteza
• Saraji Soheil

Classifications

• C09K8/602

  containing surfactants · CPC title

• C09K8/584 Primary

  characterised by the use of specific surfactants · CPC title

• C09K8/592

  Compositions used in combination with generated heat, e.g. by steam injection · CPC title

• E21B43/16

  Enhanced recovery methods for obtaining hydrocarbons · CPC title

• C09K8/04

  Aqueous well-drilling compositions · CPC title