Coinjection of dimethyl ether and steam for bitumen and heavy oil recovery

Patent metadata

Field	Value
Publication number	US-10125591-B2
Application number	US-201715670973-A
Country	US
Kind code	B2
Filing date	Aug 7, 2017
Priority date	Aug 8, 2016
Publication date	Nov 13, 2018
Grant date	Nov 13, 2018

Abstract

Provided are oil recovery techniques, which may include enhanced oil recovery techniques in which a heated combination of water vapor (steam) and dimethyl ether (DME) vapor are injected into an oil reservoir, such as containing heavy oil and/or bitumen, to facilitate extraction of the oil from the reservoir.

First claim

What is claimed is:

1. A method for recovering heavy oil or bitumen from a reservoir, the method comprising:
generating a vapor mixture including vapor phase water and vapor phase dimethyl ether (DME);
injecting the vapor mixture into a horizontal injection well in a reservoir containing heavy oil or bitumen, wherein injecting the vapor mixture into the reservoir forms a chamber in the reservoir, and wherein injecting the vapor mixture includes using a variable vapor mixture composition as a function of time;
accumulating injected DME at a chamber-edge corresponding to an outer edge of the chamber;
extracting a liquid oil phase mixture including DME and heavy oil or bitumen and a liquid aqueous phase mixture including DME and water from a horizontal production well in the reservoir, wherein the horizontal production well is positioned vertically beneath the horizontal injection well, wherein the injecting and extracting correspond to a steam assisted gravity drainage oil recovery technique;
separating the DME and the heavy oil or bitumen from the extracted liquid oil phase mixture to recover the DME from the liquid oil mixture;
separating the DME and the water from the extracted liquid aqueous phase mixture to recover the DME from the liquid aqueous mixture;
determining a time period for injection of the vapor mixture by developing a model for the chamber and the reservoir, wherein the model uses partitioning of liquid DME into a liquid oil phase including DME and the heavy oil or bitumen and a liquid aqueous phase including DME and water, and wherein time period corresponds to a duration of injecting DME in the vapor mixture for the chamber in the model to reach a target size; and
reducing an amount of DME in the variable vapor mixture composition after expiration of the time period by decreasing the percentage of DME in the vapor mixture monotonically over time.

2. The method of claim 1 , wherein the chamber-edge has a chamber-edge temperature equal to a condensation temperature of the vapor mixture.

3. The method of claim 2 , wherein the chamber-edge has a temperature that is less than a comparable chamber-edge temperature when vapor phase water, but not vapor phase DME, is injected into the reservoir.

4. The method of claim 2 , wherein the chamber-edge has a temperature that is greater than a comparable chamber-edge temperature when vapor phase DME, but not vapor phase water, is injected into the reservoir.

5. The method of claim 1 , wherein a temperature within the chamber is greater than a condensation temperature of the vapor mixture.

6. The method of claim 1 , wherein a viscosity of the heavy oil or bitumen is reduced due to dilution of the heavy oil or bitumen by DME.

7. The method of claim 1 , wherein a heated region in the reservoir surrounding the chamber has a temperature less than a condensation temperature of the vapor mixture and greater than an ambient temperature of the reservoir surrounding the heated region.

8. The method of claim 1 , wherein the chamber contains a vapor phase including water and DME, a first liquid oil phase including DME and heavy oil or bitumen, and a first liquid aqueous phase including water and DME.

9. The method of claim 1 , wherein the time period further corresponds to a duration of injecting DME in the vapor mixture for an amount of injected DME to reach a target amount.

10. The method of claim 1 , further comprising reducing the variable vapor mixture composition to a zero fraction of DME in the vapor mixture after a target amount of DME is injected into the reservoir.

11. The method of claim 1 , wherein the extracting corresponds to extracting a quantity of heavy oil or bitumen from the reservoir at a particular rate, and, wherein an amount of energy used for generating the vapor mixture needed for extracting the quantity of heavy oil or bitumen from the reservoir at the particular rate is less than a reference amount of energy required for generating vapor phase water, but not vapor phase DME, or for generating vapor phase DME, but not vapor phase water, needed for extracting the quantity of heavy oil or bitumen from the reservoir at the particular rate.

12. The method of claim 1 , wherein the extracting and separating provide a 70%-100% recovery factor for injected DME.

13. The method of claim 1 , wherein the extracting corresponds to extracting a quantity of heavy oil or bitumen from the reservoir at a particular rate, and wherein an amount of water used for generating the vapor mixture needed for extracting the quantity of heavy oil or bitumen from the reservoir at the particular rate is less than a reference amount of water required for generating vapor phase water needed for extracting the quantity of heavy oil or bitumen from the reservoir at the particular rate by injecting vapor phase water, but not vapor phase DME, into the reservoir.

14. The method of claim 1 , wherein the vapor mixture has a composition of 90-99 mol % water and 1-10 mol % DME.

15. The method of claim 1 , wherein injecting the vapor mixture includes injecting the vapor mixture at a temperature selected from the range of 320-550 K or injecting the vapor mixture at a pressure selected from the range of 10-100 bar.

16. The method of claim 1 , wherein the variable vapor mixture composition as a function of time corresponds to the vapor mixture having a first non-zero percentage of DME for a first time duration, the vapor mixture having a second non-zero percentage of DME for a second time duration after the first time duration, and the vapor mixture having a third non-zero percentage of DME for a third time duration after the second time duration, wherein the second non-zero percentage of DME is less than the first non-zero percentage of DME, and wherein the third non-zero percentage of DME is less than the second non-zero percentage of DME.

17. The method of claim 1 , wherein the variable vapor mixture composition as a function of time corresponds to the vapor mixture having a percentage of DME that decreases monotonically in a step-wise fashion over time after expiration of the time period.

18. The method of claim 1 , wherein injecting the vapor mixture further includes using a variable injection pressure as a function of time or a variable injection temperature as a function of time.

19. The method of claim 1 , wherein the vapor mixture further includes one or more hydrocarbon solvents.

20. The method of claim 1 , further comprising injecting one or more non-condensable gases into the reservoir containing heavy oil or bitumen.

Assignees

• Univ Texas

Inventors

• Okuno Ryosuke

Classifications

• C09K8/594

  Compositions used in combination with injected gas {, e.g. CO2 orcarbonated gas}(C09K8/592 takes precedence) · CPC title

• E21B43/2408 Primary

  SAGD in combination with other methods · CPC title

• C09K8/592

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