Gas diverter for well and reservoir stimulation

• US 10,385,258 B2
• Filed: 01/12/2018
• Issued: 08/20/2019
• Est. Priority Date: 04/09/2015
• Status: Expired due to Fees

• Current Assignee: Diversion Technologies, LLC
• Original Assignee: Highlands Natural Resources, Plc
• Inventors: Mendell, Paul E., Miller, Stephen
• Primary Examiner(s): DiTrani Leff, Angela M
• Application Number:
  US15/870,713
• Publication Number:
  US 20180135397A1
• Time in Patent Office: 585 Days
• CPC Class Codes: C09K 8/594 Compositions used in combination with injected gas , e.g. CO2 orcarbonated gasC09K8/592 takes precedence
• CPC Class Codes: C09K 8/62 Compositions for forming crevices or fractures
• CPC Class Codes: C09K 8/703 Foams
• CPC Class Codes: C09K 8/94 Foams
• CPC Class Codes: E21B 43/2605 using gas or liquefied gas
• CPC Class Codes: E21B 43/261 Separate steps of (1) cementing, plugging or consolidating and (2) fracturing or attacking the formation

Abstract

The disclosure provides fracturing methods having advantage over current fracturing methods. The disclosed fracturing methods can change the fracture gradient of the downhole subterranean formation. For example, one or more of the fracture gradients of the low and high stress zones of the downhole subterranean formation can be changed. Furthermore, in relation to current practices, the methods can decrease the extent and/or degree of fracturing within low stress downhole formations and increase the degree of fracturing within high stress formations.

Claims

1. A method of influencing behavior of a subterranean formation, comprising:

(a) injecting a pressurized fluid comprising a gas into at least two injection wells to pressurize pre-existing fractures of the subterranean formation adjacent to the at least two injection wells, the at least two injection wells being spatially proximate to a target well of the subterranean formation, and increase a pressure of the at least two injection wells; and

(b) maintaining, for a suitable injected fluid dwell time, the pressurized fluid in the pressurized pre-existing fractures while a carrier liquid is introduced into the target well to induce hydraulic fracturing in the target well,

wherein the target well and the injection wells are not all collinear, and

wherein the pressurized fluid is maintained at an injection pressure below a fracture gradient of the subterranean formation during the duration of steps (a) and (b), and wherein the carrier liquid is injected into the target well at a sufficient pressure above the fracture gradient to fracture the subterranean formation.

2. The method of claim 1, wherein step (a) influences one or more of fracturing characteristics or patterns and hydrocarbon fluid production in the target well, and wherein the fluid is injected into the at least two injection wells at an injection pressure less than a fracture gradient of a selected formation along a wellbore of the at least two injection wells.

3. The method of claim 1, wherein a portion of the pressurized fluid occupies the pressurized pre-existing fractures in the at least two injection wells at a sufficient pressure to cause the carrier liquid to be diverted to fracture additional features of the subterranean formation to form additional fractures or pore volumes, wherein the pressurized fluid diverts the carrier liquid from fracturing a previously stimulated area comprising the pre-existing fractures and forces the carrier liquid to fracture a previously unstimulated area, wherein the pressurized fluid is injected into the at least two injection wells through a wellhead and a wellbore of the at least two injection wells, and wherein the pressurized fluid infiltrates and occupies pore volumes of the subterranean formation in a far afield area of the subterranean formation to a distance of between about 10 feet and about 3,000 feet from the wellbore.

4. The method of claim 3, wherein the pressurized fluid comprises no more than about 1% by volume solid particulates, wherein the carrier liquid comprises a proppant, wherein both the pressurized fluid and the carrier liquid are substantially incompressible, wherein at least a portion of the pressurized fluid occupies pressurized features in the at least two injection wells at a pressure sufficient to cause the carrier liquid to be diverted to fracture additional features of the subterranean formation to form additional fractures or pore volumes, wherein the pressurized fluid diverts the carrier liquid from fracturing a previously stimulated area and forces the carrier liquid to fracture a previously unstimulated area, and wherein pressurization of the features in the at least two injection wells by the pressurized fluid inhibits fracturing of the pressurized features by the carrier liquid in the target well.

5. The method of claim 1, wherein pressurization of the pre-existing fractures adjacent to the at least two injection wells by the pressurized fluid inhibits fracturing of the pressurized pre-existing fractures by the carrier liquid in the target well, wherein a dwell time of the pressurized fluid in the at least two injection wells is at least about 5 minutes, and wherein the pressurized fluid infiltrates and occupies pore volumes of the subterranean formation in a far afield area of the subterranean formation to a distance of between about 100 feet and about 5,000 feet from a wellbore of the at least two injection wells.

6. The method of claim 5, and wherein the dwell time is between about 5 minutes and about 24 hours.

7. The method of claim 1, wherein a portion of the pressurized fluid occupies the pressurized pre-existing fractures in the at least two injection wells at a sufficient pressure to cause the carrier liquid to be diverted to fracture additional features of the subterranean formation to form additional fractures or pore volumes, wherein the pressurized fluid diverts the carrier liquid from fracturing a previously stimulated area comprising the pre-existing fractures and forces the carrier liquid to fracture a previously unstimulated area, wherein the pressurized fluid migrates through a stimulation network of manmade and naturally occurring fractures and/or pore volumes to create a barrier, wherein the carrier liquid comprises a proppant, and wherein the pressurized fluid comprises at least one material selected from the group consisting of nitrogen, hydrogen, methane, ethane, propane, butane, carbon dioxide, and an inert gas.

8. The method of claim 1, wherein a portion of the pressurized fluid occupies the pressurized pre-existing fractures in the at least two injection wells at a sufficient pressure to cause the carrier liquid to be diverted to fracture additional features of the subterranean formation to form additional fractures or pore volumes, wherein the pressurized fluid diverts the carrier liquid from fracturing a previously stimulated area comprising the pre-existing fractures and forces the carrier liquid to fracture a previously unstimulated area, and wherein step (b) is started before completion of step (a).

9. The method of claim 1, wherein pressurization of the pre-existing fractures adjacent to the at least two injection wells by the pressurized fluid inhibits fracturing of the pressurized pre-existing fractures by the carrier liquid in the target well, and wherein step (b) is started after completion of step (a).

10. The method of claim 1, wherein the pressurized fluid is free of liquid.

11. The method of claim 1, wherein the pressurized fluid comprises no more than about 50 volume % liquid.

12. The method of claim 1, wherein the pressurized fluid is free of solid particulates.

13. The method of claim 1, wherein the pressurized fluid comprises no more than about 5 volume % solid particulates.

14. A method of influencing behavior of a subterranean formation, comprising:

(a) injecting a pressurized fluid comprising a gas into an injection well to pressurize pre-existing fractures of the subterranean formation adjacent to the injection well, the injection well being spatially proximate to a target well of the subterranean formation, and increase a pressure of the injection well; and

(b) maintaining, for a suitable injected fluid dwell time, the pressurized fluid in the pressurized pre-existing fractures while a carrier liquid is introduced into the target well to induce fracturing in the target well,

wherein the pressurized fluid is maintained at an injection pressure below a fracture gradient of the subterranean formation during the duration of steps (a) and (b), and wherein the carrier liquid is injected into the target well at a sufficient pressure above the fracture gradient to fracture the subterranean formation.

15. The method of claim 14, wherein a portion of the pressurized fluid occupies the pressurized pre-existing fractures in the injection well at a sufficient pressure to cause the carrier liquid to be diverted to fracture additional features of the subterranean formation to form additional fractures or pore volumes, wherein the pressurized fluid diverts the carrier liquid from fracturing a previously stimulated area comprising the pre-existing fractures and forces the carrier liquid to fracture a previously unstimulated area, wherein step (a) influences one or more of fracturing characteristics or patterns and hydrocarbon fluid production in the target well.

16. The method of claim 14, wherein pressurization of the pre-existing fractures adjacent to the injection well by the pressurized fluid inhibits fracturing of the pressurized pre-existing fractures by the carrier liquid in the target well, wherein the pressurized fluid is injected into the injection well through a wellhead and a wellbore of the injection well, and wherein the pressurized fluid infiltrates and occupies pore volumes of the subterranean formation in a far afield area of the subterranean formation to a distance of between about 10 feet and about 3,000 feet from the wellbore.

17. The method of claim 14, wherein a portion of the pressurized fluid occupies the pressurized pre-existing fractures in the injection well at a sufficient pressure to cause the carrier liquid to be diverted to fracture additional features of the subterranean formation to form additional fractures or pore volumes, wherein the pressurized fluid diverts the carrier liquid from fracturing a previously stimulated area comprising the pre-existing fractures and forces the carrier liquid to fracture a previously unstimulated area, wherein a dwell time of the pressurized fluid in the injection well is at least about 5 minutes, wherein the carrier liquid comprises a proppant, and wherein the pressurized fluid infiltrates and occupies pore volumes of the subterranean formation in a far afield area of the subterranean formation to a distance of between about 100 feet and about 5,000 feet from the wellbore.

18. The method of claim 17, wherein the pressurized fluid comprises no more than about 1% by volume solid particulates, and wherein the dwell time is between about 5 minutes and about 24 hours.

19. The method of claim 17, wherein the pressurized fluid comprises no more than about 1% by volume solid particulates, wherein the carrier liquid comprises a proppant, wherein both the pressurized fluid and the carrier liquid are substantially incompressible, wherein at least a portion of the pressurized fluid occupies pressurized features in the injection well at a pressure sufficient to cause the carrier liquid to be diverted to fracture additional features of the subterranean formation to form additional fractures or pore volumes, wherein the pressurized fluid diverts the carrier liquid from fracturing a previously stimulated area and forces the carrier liquid to fracture a previously unstimulated area, and wherein pressurization of the features in the injection well by the pressurized fluid inhibits fracturing of the pressurized features by the carrier liquid in the target well.

20. The method of claim 14, wherein the pressurized fluid comprises no more than about 1% by volume solid particulates, wherein the pressurized fluid migrates through a stimulation network of manmade and naturally occurring fractures and/or pore volumes to create a barrier, and wherein the pressurized fluid comprises at least one material selected from the group consisting of nitrogen, hydrogen, methane, ethane, propane, butane, carbon dioxide, and an inert gas.

21. The method of claim 14, wherein a portion of the pressurized fluid occupies the pressurized pre-existing fractures in the injection well at a sufficient pressure to cause the carrier liquid to be diverted to fracture additional features of the subterranean formation to form additional fractures or pore volumes, wherein the pressurized fluid diverts the carrier liquid from fracturing a previously stimulated area comprising the pre-existing fractures and forces the carrier liquid to fracture a previously unstimulated area, and wherein step (b) is started before completion of step (a).

22. The method of claim 14, wherein pressurization of the pre-existing fractures adjacent to the injection well by the pressurized fluid inhibits fracturing of the pressurized pre-existing fractures by the carrier liquid in the target well, and wherein step (b) is started after completion of step (a).

23. The method of claim 14, wherein the pressurized fluid is free of liquid.

24. The method of claim 14, wherein the pressurized fluid comprises no more than about 50 volume % liquid.

25. The method of claim 14, wherein the pressurized fluid is free of solid particulates.

26. The method of claim 14, wherein the pressurized fluid comprises no more than about 5 volume % solid particulates.

27. A method of influencing behavior of a subterranean formation, comprising:

(a) injecting a pressurized fluid comprising a gas into at least one injection well to pressurize pre-existing fractures of the subterranean formation adjacent to at least one injection well, the at least one injection well being spatially proximate to a target well of the subterranean formation, and increase a pressure of the at least one injection well; and

(b) after starting step (a), introducing a carrier liquid into the target well to induce fracturing in the target well,

wherein the pressurized fluid is maintained at an injection pressure below a fracture gradient of the subterranean formation during the duration of steps (a) and (b) to inhibit hydraulic fracturing of the pressurized pre-existing fractures adjacent to the at least one injection well by the carrier liquid in the target well,

wherein the carrier liquid is injected into the target well at a sufficient pressure above the fracture gradient to fracture the subterranean formation.

28. The method of claim 27, wherein the pressurized fluid comprises no more than about 50 volume % liquid.

29. The method of claim 27, wherein the pressurized fluid is free of solid particulates.

30. The method of claim 27, wherein the pressurized fluid comprises no more than about 5 volume % solid particulates.

31. The method of claim 27, wherein the pressurized fluid is free of liquid.

32. The method of claim 27, wherein pressurization of the pre-existing fractures adjacent to at least one injection well by the pressurized fluid inhibits fracturing of the pressurized pre-existing fractures by the carrier liquid in the target well.

33. The method of claim 27, wherein a portion of the pressurized fluid occupies the pressurized pre-existing fractures in the at least one injection well at a sufficient pressure to cause the carrier liquid to be diverted to fracture additional features of the subterranean formation to form additional fractures or pore volumes, wherein the pressurized fluid diverts the carrier liquid from fracturing a previously stimulated area comprising the pre-existing fractures and forces the carrier liquid to fracture a previously unstimulated area.