초록 ▼

Methods for drilling, running casing in, and/or cementing a borehole in a subterranean formation without significant loss of drilling fluid are disclosed, as well as compositions for use in such methods. The methods employ drilling fluids comprising fragile gels or having fragile gel behavior and pr

Methods for drilling, running casing in, and/or cementing a borehole in a subterranean formation without significant loss of drilling fluid are disclosed, as well as compositions for use in such methods. The methods employ drilling fluids comprising fragile gels or having fragile gel behavior and providing superior oil mud rheology and overall performance. The fluids are especially advantageous for use in offshore wells because the fluids exhibit minimal differences between downhole equivalent circulating densities and surface densities notwithstanding differences in drilling or penetration rates. When an ester and isomerized olefin blend is used for the base of the fluids, the fluids make environmentally acceptable and regulatory compliant invert emulsion drilling fluids.

대표청구항 ▼

What is claimed is: 1. A method for drilling in a subterranean formation, comprising: providing an invert emulsion drilling fluid having substantially equal dial readings at 40° F. and at 120° F. when measured at 3 rpm or 6 rpm using a FANN viscometer at atmospheric pressure; and drilling in the

What is claimed is: 1. A method for drilling in a subterranean formation, comprising: providing an invert emulsion drilling fluid having substantially equal dial readings at 40° F. and at 120° F. when measured at 3 rpm or 6 rpm using a FANN viscometer at atmospheric pressure; and drilling in the subterranean formation with the drilling fluid while substantially maintaining an average ECD of less than 0.5 over a drilling interval of at least about 200 feet. 2. The method of claim 1 wherein the substantially equal dial readings at 40° F. and at 120° are measured at 3 rpm. 3. The method of claim 1 wherein the substantially equal dial readings at 40° F. and at 120° are measured at 6 rpm. 4. The method of claim 1 wherein the substantially equal dial readings at 40° F. and at 120° are measured at 3 rpm and 6 rpm. 5. The method of claim 1 wherein the drilling fluid comprises an invert emulsion base selected from the group consisting of: esters, olefins, paraffin hydrocarbons, mineral oil, glyceride trimesters, naphthenic hydrocarbons, and combinations thereof. 6. The method of claim 1 wherein the drilling fluid comprises an internal olefin. 7. The method of claim 1 wherein the drilling fluid comprises an ester. 8. The method of claim 1 wherein the drilling fluid comprises paraffin hydrocarbon. 9. The method of claim 1 wherein the drilling fluid is substantially free of an organophilic filtration control agent. 10. The method of claim 1 wherein the drilling fluid is substantially free of lignite. 11. The method of claim 1 wherein the drilling fluid comprises a modified fatty acid rheology modifier. 12. The method of claim 1 wherein the drilling fluid comprises a copolymer filtration control agent. 13. The method of claim 1 wherein the drilling fluid comprises a rheology modifier comprising dimeric and trimeric fatty acids. 14. The method of claim 1 wherein the drilling fluid comprises a methylstyrene/acrylate filtration control agent. 15. The method of claim 1 wherein the drilling fluid comprises a thinner. 16. The method of claim 1 wherein the drilling fluid comprises a thinner that reduces the viscosity of the drilling fluid at about 40° F. to a greater extent than it reduces the viscosity of the drilling fluid at about 120° F. 17. The method of claim 1 wherein the drilling fluid comprises organophilic clay present in an amount from about 0 to about 3 pounds per barrel. 18. The method of claim 1 wherein the drilling fluid has a lower yield point at about 40° F. than at about 120° F. 19. The method of claim 1 wherein the drilling is offshore. 20. The method of claim 1 wherein the drilling fluid has a G'10/G'200 elastic modulus ratio greater than about 2. 21. The method of claim 1 wherein the drilling fluid has a yield point less than about 3 Pa at a shear rate of 3.0 s-1 or less. 22. The method of claim 1 wherein the drilling fluid has a Stress Build Function greater than about 3.0. 23. The method of claim 1 further comprising running casing and/or cementing a wellbore in the subterranean formation. 24. The method of claim 1 further comprising stopping the drilling with substantially no sag in the drilling fluid. 25. A method for drilling in a subterranean formation, comprising: providing and/or using an invert emulsion drilling fluid having substantially equal dial readings at 40° F. and at 120° F. when measured at 3 rpm or 6 rpm using a FANN viscometer at atmospheric pressure. 26. The method of claim 25 wherein the substantially equal dial readings at 40° F. and at 120° are measured at 3 rpm. 27. The method of claim 25 wherein the substantially equal dial readings at 40° F. and at 120° are measured at 6 rpm. 28. The method of claim 25 wherein the substantially equal dial readings at 40° F. and at 120° are measured at 3 rpm and 6 rpm. 29. The method of claim 25 wherein the drilling fluid comprises an invert emulsion base selected from the group consisting of: esters, olefins, paraffin hydrocarbons, mineral oil, glyceride trimesters, naphthenic hydrocarbons, and combinations thereof. 30. The method of claim 25 wherein the drilling fluid comprises an internal olefin. 31. The method of claim 25 wherein the drilling fluid comprises an ester. 32. The method of claim 25 wherein the drilling fluid comprises paraffin hydrocarbon. 33. The method of claim 25 wherein the drilling fluid is substantially free of an organophilic filtration control agent. 34. The method of claim 25 wherein the drilling fluid is substantially free of lignite. 35. The method of claim 25 wherein the drilling fluid comprises a modified fatty acid rheology modifier. 36. The method of claim 25 wherein the drilling fluid comprises a copolymer filtration control agent. 37. The method of claim 25 wherein the drilling fluid comprises a rheology modifier comprising dimeric and trimeric fatty acids. 38. The method of claim 25 wherein the drilling fluid comprises a methylstyrene/acrylate filtration control agent. 39. The method of claim 25 wherein the drilling fluid comprises a thinner. 40. The method of claim 25 wherein the drilling fluid comprises a thinner that reduces the viscosity of the drilling fluid at about 40° F. to a greater extent than it reduces the viscosity of the drilling fluid at about 120° F. 41. The method of claim 25 wherein the drilling fluid comprises organophilic clay present in an amount from about 0 to about 3 pounds per barrel. 42. The method of claim 25 wherein the drilling fluid has a lower yield point at about 40° F. than at about 120° F. 43. The method of claim 25 wherein the drilling fluid is used offshore. 44. The method of claim 25 wherein the drilling fluid has a G'10/G'200 elastic modulus ratio greater than about 2. 45. The method of claim 25 wherein the drilling fluid has a yield point less than about 3 Pa at a shear rate of 3.0 s-1 or less. 46. The method of claim 25 wherein the drilling fluid has a Stress Build Function greater than about 3.0. 47. The method of claim 25 wherein using the drilling fluid comprises drilling, running casing and/or cementing in the subterranean formation. 48. The method of claim 25 wherein using the drilling fluid comprises drilling in the subterranean formation. 49. A method for drilling in a subterranean formation, comprising: drilling in the subterranean formation with an invert emulsion drilling fluid having a yield point less than about 3 Pa at a shear rate of 3.0 s-1 or less while substantially maintaining an average ECD of less than 0.5 over a drilling interval of at least about 200 feet. 50. The method of claim 49 wherein the drilling fluid comprises an invert emulsion base selected from the group consisting of: esters, olefins, paraffin hydrocarbons, mineral oil, glyceride trimesters, naphthenic hydrocarbons, and combinations thereof. 51. The method of claim 49 wherein the drilling fluid comprises an internal olefin. 52. The method of claim 49 wherein the drilling fluid comprises an ester. 53. The method of claim 49 wherein the drilling fluid comprises paraffin hydrocarbon. 54. The method of claim 49 wherein the drilling fluid is substantially free of an organophilic filtration control agent. 55. The method of claim 49 wherein the drilling fluid is substantially free of lignite. 56. The method of claim 49 wherein the drilling fluid comprises a modified fatty acid rheology modifier. 57. The method of claim 49 wherein the drilling fluid comprises a copolymer filtration control agent. 58. The method of claim 49 wherein the drilling fluid comprises a rheology modifier comprising dimeric and trimeric fatty acids. 59. The method of claim 49 wherein the drilling fluid comprises a methylstyrene/acrylate filtration control agent. 60. The method of claim 49 wherein the drilling fluid comprises a thinner. 61. The method of claim 49 wherein the drilling fluid comprises a thinner that reduces the viscosity of the drilling fluid at about 40° F. to a greater extent than it reduces the viscosity of the drilling fluid at about 120° F. 62. The method of claim 49 wherein the drilling fluid comprises organophilic clay present in an amount from about 0 to about 3 pounds per barrel. 63. The method of claim 49 wherein the drilling fluid has a lower yield point at about 40° F. than at about 120° F. 64. The method of claim 49 wherein the drilling is offshore. 65. The method of claim 49 wherein the drilling fluid has a G'10/G'200 elastic modulus ratio greater than about 2. 66. The method of claim 49 wherein the drilling fluid has a Stress Build Function greater than about 3.0. 67. The method of claim 49 further comprising running casing and/or cementing a wellbore in the subterranean formation.