Methods for foam stimulation

Patent metadata

Field	Value
Publication number	US-11905461-B2
Application number	US-202016922999-A
Country	US
Kind code	B2
Filing date	Jul 7, 2020
Priority date	Jul 7, 2019
Publication date	Feb 20, 2024
Grant date	Feb 20, 2024

Abstract

Disclosed are foam precursor compositions, foamed compositions, and methods of using these foamed compositions for the stimulation of unconventional reservoirs.

First claim

What is claimed is:

1. A method for stimulating an unconventional subterranean formation comprising:
(a) providing an existing wellbore in fluid communication with an unconventional subterranean formation, wherein the existing wellbore has a pressure that is less than original reservoir pressure;
(b) injecting a foamed composition through the existing wellbore into the unconventional subterranean formation, the foamed composition comprising a surfactant package comprising a primary foaming surfactant, wherein the foamed composition is injected at a pressure and flowrate effective to increase the existing wellbore pressure;
(c) contacting the foamed composition with a rock matrix of the unconventional subterranean formation for a period of time; and
(d) producing fluids from the unconventional subterranean formation through the wellbore;
wherein step (b) comprises:
combining a foam precursor solution with an expansion gas to form the foamed composition above ground, and injecting the foamed composition through the existing wellbore into the unconventional subterranean formation; or
combining a foam precursor solution with an expansion gas downhole to form the foamed composition in situ within the existing wellbore.

2. The method of claim 1 , wherein step (b) comprises injecting the foamed composition at a pressure and flowrate effective to:
increase the existing wellbore pressure by at least 30%;
increase the existing wellbore pressure to from greater than the original reservoir pressure to 150% of the original reservoir pressure;
increase the existing wellbore pressure without refracturing the existing wellbore; or
any combination thereof.

3. The method of claim 1 , wherein the period of time in step (c) comprises a period of time effective for the foamed composition to break.

4. The method of claim 1 , further comprising repeating steps (b)-(d) from 2 to 10 times.

5. The method of claim 1 , wherein the method further comprises ceasing introduction of the foamed composition through the existing wellbore into the unconventional subterranean formation before contacting step (c).

6. The method of claim 1 , wherein the existing wellbore has a pressure that is from 20% to 70% of the original reservoir pressure.

7. The method of claim 1 , wherein the injection of the foamed composition:
increases a relative permeability in a region of the unconventional subterranean formation proximate to the existing wellbore;
releases hydrocarbons from pores in a rock matrix in a region of the unconventional subterranean formation proximate to the existing wellbore; or
any combination thereof.

8. The method of claim 1 , wherein the fluids comprise a hydrocarbon and wherein injection of the foamed composition into the unconventional subterranean formation results in increased hydrocarbon recovery from the existing wellbore as compared to an expected level of hydrocarbon recovery projected from a decline curve fit to production history of the existing wellbore.

9. The method of claim 1 , wherein the method remediates near wellbore damage.

10. The method of claim 1 , wherein the period of time is from one day to six months.

11. The method of claim 1 , further comprising:
adding a tracer to the foamed composition prior to introducing the foamed composition through the wellbore into the unconventional subterranean formation;
recovering the tracer from the fluids produced from the unconventional subterranean formation through the wellbore, fluids recovered from a different wellbore in fluid communication with the unconventional subterranean formation, or any combination thereof; and
comparing a quantity of tracer recovered from the fluids produced to a quantity of tracer introduced to the foamed composition.

12. The method of claim 1 , wherein the foamed composition is foamed and further comprises from 30% to 98% expansion gas.

13. The method of claim 1 , wherein a region of an unconventional subterranean formation in fluid communication with the existing wellbore is naturally fractured, has been previously fractured one or more times, or a combination thereof.

Assignees

• Chevron Usa Inc

Inventors

• Dwarakanath Varadarajan
• Malik Taimur
• Zuo Lin
• Zhou Jimin Daniel
• Nizamidin Nabijan
• Winslow Gregory A
• Banki Reza
• Salman Mohamad

Classifications

• C09K8/602 Primary

  containing surfactants · CPC title

• C09K8/94 Primary

  Foams · CPC title

• E21B43/166

  Injecting a gaseous medium; Injecting a gaseous medium and a liquid medium (CO2 injection E21B43/164; steam injection E21B43/24) · CPC title