Systems, methods, and compositions for reservoir stimulation treatment diversion using thermochemicals

Patent metadata

Field	Value
Publication number	US-11268017-B2
Application number	US-202016817305-A
Country	US
Kind code	B2
Filing date	Mar 12, 2020
Priority date	Mar 12, 2020
Publication date	Mar 8, 2022
Grant date	Mar 8, 2022

Abstract

Reservoir stimulation treatment diversion methods, systems, and compositions. One method includes identifying a reservoir requiring liquid stimulation treatment in a lesser-permeability portion of the reservoir. The method includes identifying a greater-permeability portion of the reservoir, the greater-permeability portion of the reservoir having a greater permeability than the lesser-permeability portion. The method also includes disposing a gas in the greater-permeability portion of the reservoir; injecting a liquid stimulation treatment into the reservoir, and allowing the gas in the greater-permeability portion of the reservoir to divert the liquid stimulation treatment into the lesser-permeability portion to stimulate fluid production from the lesser-permeability portion of the reservoir.

First claim

What is claimed is:

1. A reservoir stimulation treatment diversion method, the method comprising:
identifying a reservoir requiring liquid stimulation treatment in a lesser-permeability portion of the reservoir;
identifying a greater-permeability portion of the reservoir, the greater-permeability portion of the reservoir having a greater permeability than the lesser-permeability portion;
disposing a gas in the greater-permeability portion of the reservoir via in situ gas generation from an exothermic reaction of thermochemicals;
injecting a liquid stimulation treatment into the reservoir; and
allowing the gas in the greater-permeability portion of the reservoir to divert the liquid stimulation treatment into the lesser-permeability portion to stimulate fluid production from the lesser-permeability portion of the reservoir to control a temperature profile in the lesser-permeability portion of the reservoir.

2. The method according to claim 1 , where the permeability of the greater-permeability portion is greater than about 80 milliDarcy (mD) and where the permeability of the lesser-permeability portion is less than about 40 mD.

3. The method according to claim 1 , where disposing is carried out before injecting.

4. The method according to claim 1 , where disposing is carried out during injecting.

5. The method according to claim 1 , where disposing is carried out after injecting.

6. The method according to claim 1 , where disposing includes injecting a gas from the surface into the greater-permeability portion, the gas including at least one component selected from the group consisting of: carbon dioxide, methane, ethane, and nitrogen.

7. The method according to claim 1 , where the thermochemicals include ammonium ions and nitrite ions.

8. The method according to claim 1 , where injecting includes injecting an acid composition including at least one acid selected from the group consisting of: hydrochloric acid and hydrofluoric acid.

9. The method according to claim 1 , where injecting includes injecting a composition that reacts in situ to produce an acid and the gas, the acid selected from the group consisting of: hydrochloric acid, hydrofluoric acid, and combinations of the same.

10. The method according to claim 1 , further comprising the step of verifying stimulated fluid production from the lesser-permeability portion of the reservoir by calculating decreased skin damage for the lesser-permeability portion.

11. The method according to claim 1 , where the permeability of the lesser-permeability portion is increased by at least 100%.

12. The method according to claim 1 , where the thermochemicals comprise a component selected from the group consisting of: ammonium chloride, ammonium bromide, ammonium nitrate, ammonium sulfate, ammonium carbonate, ammonium hydroxide, and combinations thereof.

13. The method according to claim 1 , where the thermochemicals comprise a component selected from the group consisting of: sodium nitrite, potassium nitrite, and combinations thereof.

14. The method according to claim 1 , where the thermochemicals comprise NH 4 C 1 and NaNO 2 .

15. The method according to claim 14 , where concentrations of the NH 4 C 1 and NaNO 2 are about 1 molar and where the NH 4 C 1 and NaNO 2 are injected separately during injecting and combined in situ to exothermically react.

16. The method according to claim 14 , where the thermochemicals are triggered at a temperature in situ between about 50° C. and about 300° C.

17. The method according to claim 14 , further comprising activating the thermochemicals with at least one of microwaves, an acid, or combinations of the same.

18. The method according to claim 1 , where the reservoir comprises at least one component selected from the group consisting of: limestone and dolomite.

19. The method according to claim 1 , where injecting is selected from an injection type of continuous injection, cyclic injection, huff-n-puff injection, and combinations of the same.

20. The method according to claim 1 , where disposing and injecting are carried out separately so as not to create foam or foamed acid.

21. The method according to claim 1 , where disposing a gas in the greater-permeability portion of the reservoir does not cause fracturing.

22. The method according to claim 1 , where injecting a liquid stimulation treatment in the reservoir does not cause fracturing.

23. The method according to claim 1 , where the steps of disposing a gas in the greater-permeability portion of the reservoir and injecting a liquid stimulation treatment in the reservoir do not cause fracturing.

Assignees

• Saudi Arabian Oil Co
• Univ King Fahd Pet & Minerals

Inventors

• Al-Nakhli Ayman
• Mahmoud Mohamed Ahmed Nasr Eldin

Classifications

• E21B49/00

  Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells · CPC title

• C09K8/607

  specially adapted for clay formations · CPC title

• E21B43/164

  Injecting CO2 or carbonated water (in combination with organic material C09K8/594) · CPC title

• C09K8/72 Primary

  Eroding chemicals, e.g. acids · CPC title

• E21B43/168

  Injecting a gaseous medium · CPC title