Initiation of injection planes in a well. A method of forming at least one generally planar inclusion in a subterranean formation includes the steps of: expanding a wellbore in the formation by injecting a material into an annulus positioned between the wellbore and a casing lining the wellbore; inc
Initiation of injection planes in a well. A method of forming at least one generally planar inclusion in a subterranean formation includes the steps of: expanding a wellbore in the formation by injecting a material into an annulus positioned between the wellbore and a casing lining the wellbore; increasing compressive stress in the formation as a result of the expanding step; and then injecting a fluid into the formation, thereby forming the inclusion in a direction of the increased compressive stress. Another method includes the steps of: expanding a wellbore in the formation by injecting a material into an annulus positioned between the wellbore and a casing lining the wellbore; reducing stress in the formation in a tangential direction relative to the wellbore; and then injecting a fluid into the formation, thereby forming the inclusion in a direction normal to the reduced tangential stress.
대표청구항▼
What is claimed is: 1. A method of forming at least one generally planar inclusion in a subterranean formation, the method comprising the steps of: expanding a wellbore in the formation by injecting a material into an annulus positioned between the wellbore and a casing lining the wellbore; increas
What is claimed is: 1. A method of forming at least one generally planar inclusion in a subterranean formation, the method comprising the steps of: expanding a wellbore in the formation by injecting a material into an annulus positioned between the wellbore and a casing lining the wellbore; increasing compressive stress in the formation as a result of the expanding step; and then injecting a fluid into the formation, thereby forming the inclusion in a direction of the increased compressive stress. 2. The method of claim 1, wherein the direction of the increased compressive stress is a radial direction relative to the wellbore. 3. The method of claim 1, further comprising the step of reducing stress in the formation in a tangential direction relative to the wellbore. 4. The method of claim 3, wherein the reducing stress step further comprises forming at least one perforation extending into the formation. 5. The method of claim 1, wherein the material in the expanding step comprises a hardenable material. 6. The method of claim 1, wherein the material in the expanding step includes a swellable material. 7. The method of claim 1, wherein the annulus in the expanding step is positioned between the wellbore and a sealing material surrounding the casing. 8. The method of claim 1, wherein the formation comprises weakly cemented sediment. 9. The method of claim 1, wherein the formation has a bulk modulus of less than approximately 750,000 psi. 10. The method of claim 1, wherein the fluid injecting step further comprises reducing a pore pressure in the formation at a tip of the inclusion. 11. The method of claim 1, wherein the fluid injecting step further comprises increasing a pore pressure gradient in the formation at a tip of the inclusion. 12. The method of claim 1, wherein the fluid injecting step further comprises fluidizing the formation at a tip of the inclusion. 13. The method of claim 1, wherein a viscosity of the fluid in the fluid injecting step is greater than approximately 100 centipoise. 14. The method of claim 1, wherein the formation has a cohesive strength of less than 400 pounds per square inch plus 0.4 times a mean effective stress in the formation at a depth of the inclusion. 15. The method of claim 1, wherein the formation has a Skempton B parameter greater than 0.95exp(−0.04 p′)+0.008 p′, where p′ is a mean effective stress at a depth of the inclusion. 16. The method of claim 1, wherein the fluid injecting step further comprises simultaneously forming multiple inclusions in the formation. 17. The method of claim 1, wherein the fluid injecting step further comprises forming four inclusions approximately aligned with orthogonal planes in the formation. 18. The method of claim 1, wherein the wellbore has been used for at least one of production from and injection into the formation for hydrocarbon production operations prior to the expanding step. 19. A method of forming at least one generally planar inclusion in a subterranean formation, the method comprising the steps of: expanding a wellbore in the formation by injecting a material into an annulus positioned between the wellbore and a casing lining the wellbore; reducing stress in the formation in a tangential direction relative to the wellbore; and then injecting a fluid into the formation, thereby forming the inclusion in a direction normal to the reduced tangential stress. 20. The method of claim 19, wherein the reducing stress step further comprises forming at least one perforation extending into the formation. 21. The method of claim 19, further comprising the step of increasing compressive stress in the formation as a result of the expanding step. 22. The method of claim 21, wherein a direction of the increased compressive stress is a radial direction relative to the wellbore. 23. The method of claim 19, wherein the material in the expanding step comprises a hardenable material. 24. The method of claim 19, wherein the material in the expanding step includes a swellable material. 25. The method of claim 19, wherein the annulus in the expanding step is positioned between the wellbore and a sealing material surrounding the casing. 26. The method of claim 19, wherein the formation comprises weakly cemented sediment. 27. The method of claim 19, wherein the formation has a drained bulk modulus of less than approximately 750,000 psi. 28. The method of claim 19, wherein the fluid injecting step further comprises reducing a pore pressure in the formation at a tip of the inclusion. 29. The method of claim 19, wherein the fluid injecting step further comprises increasing a pore pressure gradient in the formation at a tip of the inclusion. 30. The method of claim 19, wherein the fluid injecting step further comprises fluidizing the formation at a tip of the inclusion. 31. The method of claim 19, wherein a viscosity of the fluid in the fluid injecting step is greater than approximately 100 centipoise. 32. The method of claim 19, wherein the formation has a cohesive strength of less than 400 pounds per square inch plus 0.4 times a mean effective stress in the formation at a depth of the inclusion. 33. The method of claim 19, wherein the formation has a Skempton B parameter greater than 0.95exp(−0.04 p′)+0.008 p′, where p′ is a mean effective stress at a depth of the inclusion. 34. The method of claim 19, wherein the fluid injecting step further comprises simultaneously forming multiple inclusions in the formation. 35. A method of forming at least one generally planar inclusion in a subterranean formation, the method comprising the steps of: installing a sleeve in a pre-existing casing lining a wellbore; increasing compressive stress in the formation by injecting a material into an annulus positioned between the formation and the sleeve; and then injecting a fluid into the formation, thereby forming the inclusion in a direction of the increased compressive stress. 36. The method of claim 35, wherein the direction of the increased compressive stress is a radial direction relative to the wellbore. 37. The method of claim 35, further comprising the step of reducing stress in the formation in a tangential direction relative to the wellbore. 38. The method of claim 35, wherein the material comprises a hardenable material. 39. The method of claim 35, wherein the material includes a swellable material. 40. The method of claim 35, wherein the formation comprises weakly cemented sediment. 41. The method of claim 35, wherein the formation has a bulk modulus of less than approximately 750,000 psi. 42. The method of claim 35, wherein the fluid injecting step further comprises reducing a pore pressure in the formation at a tip of the inclusion. 43. The method of claim 35, wherein the fluid injecting step further comprises increasing a pore pressure gradient in the formation at a tip of the inclusion. 44. The method of claim 35, wherein the fluid injecting step further comprises fluidizing the formation at a tip of the inclusion. 45. The method of claim 35, wherein a viscosity of the fluid in the fluid injecting step is greater than approximately 100 centipoise. 46. The method of claim 35, wherein the formation has a cohesive strength of less than 400 pounds per square inch plus 0.4 times a mean effective stress in the formation at a depth of the inclusion. 47. The method of claim 35, wherein the formation has a Skempton B parameter greater than 0.95exp(−0.04 p′)+0.008 p′, where p′ is a mean effective stress at a depth of the inclusion. 48. The method of claim 35, wherein the fluid injecting step further comprises simultaneously forming multiple inclusions in the formation.
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