최소 단어 이상 선택하여야 합니다.
최대 10 단어까지만 선택 가능합니다.
다음과 같은 기능을 한번의 로그인으로 사용 할 수 있습니다.
NTIS 바로가기다음과 같은 기능을 한번의 로그인으로 사용 할 수 있습니다.
DataON 바로가기다음과 같은 기능을 한번의 로그인으로 사용 할 수 있습니다.
Edison 바로가기다음과 같은 기능을 한번의 로그인으로 사용 할 수 있습니다.
Kafe 바로가기국가/구분 | United States(US) Patent 등록 |
---|---|
국제특허분류(IPC7판) |
|
출원번호 | US-0292124 (2002-11-12) |
등록번호 | US-7456135 (2008-11-25) |
발명자 / 주소 |
|
출원인 / 주소 |
|
대리인 / 주소 |
|
인용정보 | 피인용 횟수 : 13 인용 특허 : 117 |
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.
What is claimed is: 1. A method of drilling in a subterranean formation comprising the steps of: providing an invert emulsion drilling fluid, comprising: a continuous phase, an internal phase, an emulsifier, and a weighting agent, wherein the drilling fluid has substantially equal dial readings at
What is claimed is: 1. A method of drilling in a subterranean formation comprising the steps of: providing an invert emulsion drilling fluid, comprising: a continuous phase, an internal phase, an emulsifier, and a weighting agent, wherein the drilling fluid has substantially equal dial readings at 40�� F. and at 120�� F. when measured at 6 rpm using a FANN viscometer at atmospheric pressure; drilling in the subterranean formation with the drilling fluid; stopping the drilling while suspending the weighting agent in the drilling fluid; measuring pressure with pressure-while-drilling equipment or instruments; and resuming the drilling with substantially no pressure spike as detected by the pressure-while-drilling equipment or instruments. 2. The method of claim 1 wherein the drilling comprises maintaining an average ECD of less than 0.5 over an interval of at least about 200 feet. 3. The method of claim 2 wherein the interval is at a depth in the range of 11,000 ft to 12,000 ft. 4. The method of claim 1 wherein the continuous phase of the drilling fluid comprises an olefin. 5. The method of claim 1 wherein the continuous phase of the drilling fluid comprises an internal olefin. 6. The method of claim 1 wherein the continuous phase of the drilling fluid comprises an ester. 7. The method of claim 1 wherein the continuous phase of the drilling fluid comprises a paraffin hydrocarbon. 8. The method of claim 1 wherein the continuous phase of the drilling fluid comprises a mineral oil hydrocarbon. 9. The method of claim 1 wherein the continuous phase of the drilling fluid comprises a glyceride triester. 10. The method of claim 1 wherein the continuous phase of the drilling fluid comprises a naphthenic hydrocarbon. 11. The method of claim 1 wherein the continuous phase of the drilling fluid comprises a combination of components selected from the group consisting of: an ester, an olefin, a paraffin hydrocarbon, a mineral oil hydrocarbon, a glyceride triester, and a naphthenic hydrocarbon. 12. The method of claim 1 wherein the internal phase of the drilling fluid comprises water. 13. The method of claim 1 wherein the drilling fluid is substantially free of an organophilic filtration control agent. 14. The method of claim 1 wherein the drilling fluid is substantially free of lignite. 15. The method of claim 1 wherein the drilling fluid comprises substantially no organophilic clay and lignite. 16. The method of claim 1 wherein the drilling fluid comprises 0 to about 3 pounds per barrel of organophilic clay. 17. The method of claim 1 wherein the drilling fluid further comprises about 0 to about 1 pound per barrel of organophilic clay. 18. The method of claim 1 wherein the drilling fluid comprises 0 to about 2 pounds per barrel of organophilic clay. 19. The method of claim 1 wherein the drilling fluid further comprises about 0 to about 3 pounds per barrel of organophilic clay. 20. The method of claim 1 wherein the drilling fluid further comprises about 1 to about 3 pounds per barrel of organophilic clay. 21. The method of claim 1 wherein the drilling fluid further comprises a rheology modifier. 22. The method of claim 1 wherein the drilling fluid further comprises a rheology modifier comprising dimeric and trimeric fatty acids. 23. The method of claim 1 wherein the drilling fluid further comprises a filtration control agent. 24. The method of claim 1 wherein the drilling fluid further comprises a copolymer filtration control agent. 25. The method of claim 1 wherein the drilling fluid further comprises a methyistyrene/acrylate copolymer filtration control agent. 26. The method of claim 1 wherein the drilling fluid further comprises a thinner. 27. The method of claim 1 wherein the drilling fluid further 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. 28. The method of claim 1 wherein the drilling fluid further comprises one or more additives selected from the group consisting of: an emulsion stabilizer, a viscosifier, an HTHP additive, and a water activity lowering material. 29. The method of claim 1 wherein the drilling fluid meets or exceeds the minimum requirements for year 2002 environmental compatibility as tested in a 10-day Liptocheirus test and year 2002 biodegradability requirements of the United States Environmental Protection Agency. 30. The method of claim 1 wherein the drilling fluid has a lower yield point at a temperature of about 40�� F. than at a temperature of about 120�� F. when measured at a shear rate of about 0.03 s-1. 31. The method of claim 1 wherein the drilling fluid has a G'10/G'200 elastic modulus ratio greater than about 2. 32. The method of claim 1 wherein the drilling fluid has a yield point in the range of from about 1.6 Pa to about 2.9 Pa at a shear rate in the range of from 0.03 s-1 to 3.0 s-1. 33. The method of claim 1 wherein the drilling fluid has a Stress Build Function greater than about 3.8. 34. The method of claim 1 wherein the drilling is offshore. 35. The method of claim 1 wherein the drilling is conducted without a substantial loss of drilling fluid. 36. The method of claim 1 wherein the drilling fluid is viscoelastic. 37. The method of claim 1 wherein the drilling fluid is used in running casing and cementing with loss of the drilling fluid being less than about 100 barrels of total drilling fluid. 38. The method of claim 1 wherein the drilling fluid is used in drilling, running casing and cementing with loss of the drilling fluid being less than about 500 barrels of total drilling fluid. 39. The method of claim 1 wherein the drilling fluid is used in running casing and/or cementing a wellbore in the subterranean formation. 40. A method of drilling in a subterranean formation comprising the steps of: providing an invert emulsion drilling fluid, comprising: a continuous phase, an internal phase, an emulsifier, and a weighting agent, wherein the drilling fluid has substantially equal dial readings at 40�� F. and at 120�� F. when measured at 6 rpm using a FANN viscometer at atmospheric pressure; drilling in the subterranean formation with the drilling fluid while maintaining an average ECD of less than 0.5 over an interval of at least about 200 feet; and stopping the drilling while suspending the weighting agent in the drilling fluid. 41. The method of claim 40 wherein the continuous phase of the drilling fluid comprises an olefin. 42. The method of claim 40 wherein the continuous phase of the drilling fluid comprises an internal olefin. 43. The method of claim 40 wherein the continuous phase of the drilling fluid comprises an ester. 44. The method of claim 40 wherein the continuous phase of the drilling fluid comprises a paraffin hydrocarbon. 45. The method of claim 40 wherein the continuous phase of the drilling fluid comprises a mineral oil hydrocarbon. 46. The method of claim 40 wherein the continuous phase of the drilling fluid comprises a glyceride triester. 47. The method of claim 40 wherein the continuous phase of the drilling fluid comprises a naphthenic hydrocarbon. 48. The method of claim 40 wherein the continuous phase of the drilling fluid comprises a combination of components selected from the group consisting of: an ester, an olefin, a paraffin hydrocarbon, a mineral oil hydrocarbon, a glyceride triester, and a naphthenic hydrocarbon. 49. The method of claim 40 wherein the internal phase of the drilling fluid comprises water. 50. The method of claim 40 wherein the drilling fluid is substantially free of an organophilic filtration control agent. 51. The method of claim 40 wherein the drilling fluid is substantially free of lignite. 52. The method of claim 40 wherein the drilling fluid comprises substantially no organophilic clay and lignite. 53. The method of claim 40 wherein the drilling fluid comprises 0 to about 3 pounds per barrel of organophilic clay. 54. The method of claim 40 wherein the drilling fluid further comprises about 0 to about 1 pound per barrel of organophilic clay. 55. The method of claim 40 wherein the drilling fluid comprises 0 to about 2 pounds per barrel of organophilic clay. 56. The method of claim 40 wherein the drilling fluid further comprises about 0 to about 3 pounds per barrel of organophilic clay. 57. The method of claim 40 wherein the drilling fluid further comprises about 1 to about 3 pounds per barrel of organophilic clay. 58. The method of claim 40 wherein the drilling fluid further comprises a rheology modifier. 59. The method of claim 40 wherein the drilling fluid further comprises a rheology modifier comprising dimeric and trimeric fatty acids. 60. The method of claim 40 wherein the drilling fluid further comprises a filtration control agent. 61. The method of claim 40 wherein the drilling fluid further comprises a copolymer filtration control agent. 62. The method of claim 40 wherein the drilling fluid further comprises a methylstyrene/acrylate copolymer filtration control agent. 63. The method of claim 40 wherein the drilling fluid further comprises a thinner. 64. The method of claim 40 wherein the drilling fluid further 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. 65. The method of claim 40 wherein the drilling fluid further comprises one or more additives selected from the group consisting of: an emulsion stabilizer, a viscosifier, an HTHP additive, and a water activity lowering material. 66. The method of claim 40 wherein the drilling fluid meets or exceeds the minimum requirements for year 2002 environmental compatibility as tested in a 10-day Liptocheirus test and year 2002 biogradability requirements of the United States Environmental Protection Agency. 67. The method of claim 40 wherein the drilling fluid has a lower yield point at a temperature of about 40�� F. than at a temperature of about 120�� F. when measured at a shear rate of about 0.03 s-1. 68. The method of claim 40 wherein the drilling fluid has a G'10/G'200 elastic modulus ratio greater than about 2. 69. The method of claim 40 wherein the drilling fluid has a yield point less in the range of from about 1.6 Pa to about 2.9 Pa at a shear rate in the range of from 0.03 s-1 to 3.0 s-1. 70. The method of claim 40 wherein the drilling fluid has a Stress Build Function greater than about 3.8. 71. The method of claim 40 wherein the drilling is offshore. 72. The method of claim 40 wherein the drilling is conducted without a substantial loss of drilling fluid. 73. The method of claim 40 wherein the drilling fluid is viscoelastic. 74. The method of claim 40 wherein the drilling fluid is used in running casing and cementing with loss of the drilling fluid being less than about 100 barrels of total drilling fluid. 75. The method of claim 40 wherein the drilling fluid is used in drilling, running casing and cementing with loss of the drilling fluid being less than about 500 barrels of total drilling fluid. 76. The method of claim 40 wherein the drilling fluid is used in running casing and/or cementing a wellbore in the subterranean formation. 77. The method of claim 40 wherein the interval is at a depth in the range of 11,000 feet to 12,000 feet. 78. The method of claim 40 wherein the drilling is at a water depth of at least about 1500 feet. 79. The method of claim 40 wherein the average ECD of less than 0.5 is maintained over an interval of at least about 300 feet. 80. The method of claim 40 wherein the average ECD of less than 0.5 is maintained over an interval of at least about 500 feet. 81. The method of claim 40 wherein the average ECD of less than 0.5 is maintained over an interval of at least about 1000 feet. 82. A method of drilling in a subterranean formation comprising the steps of: providing an invert emulsion drilling fluid, comprising: a continuous phase, an internal phase, an emulsifier, and a weighting agent, wherein the drilling fluid has substantially equal dial readings at 40�� F. and at 120�� F. when measured at 6 rpm using a FANN viscometer at atmospheric pressure; drilling in the subterranean formation with the drilling fluid; stopping the drilling with substantially no sag in the drilling fluid; measuring pressure with pressure-while-drilling equipment or instruments; and resuming the drilling with substantially no pressure spike as detected by the pressure-while-drilling equipment or instruments. 83. The method of claim 82 wherein the continuous phase of the drilling fluid comprises an olefin. 84. The method of claim 82 wherein the continuous phase of the drilling fluid comprises an internal olefin. 85. The method of claim 82 wherein the continuous phase of the drilling fluid comprises an ester. 86. The method of claim 82 wherein the continuous phase of the drilling fluid comprises a paraffin hydrocarbon. 87. The method of claim 82 wherein the continuous phase of the drilling fluid comprises a mineral oil hydrocarbon. 88. The method of claim 82 wherein the continuous phase of the drilling fluid comprises a glyceride triester. 89. The method of claim 82 wherein the continuous phase of the drilling fluid comprises a naphthenic hydrocarbon. 90. The method of claim 82 wherein the continuous phase of the drilling fluid comprises a combination of components selected from the group consisting of: an ester, an olefin, a paraffin hydrocarbon, a mineral oil hydrocarbon, a glyceride triester, and a naphthenic hydrocarbon. 91. The method of claim 82 wherein the internal phase of the drilling fluid comprises water. 92. The method of claim 82 wherein the drilling fluid is substantially free of an organophilic filtration control agent. 93. The method of claim 82 wherein the drilling fluid is substantially free of lignite. 94. The method of claim 82 wherein the drilling fluid comprises substantially no organophilic clay and lignite. 95. The method of claim 82 wherein the drilling fluid comprises 0 to about 3 pounds per barrel of organophilic clay. 96. The method of claim 82 wherein the drilling fluid further comprises about 0 to about 1 pound per barrel of organophilic clay. 97. The method of claim 82 wherein the drilling fluid comprises 0 to about 2 pounds per barrel of organophilic clay. 98. The method of claim 82 wherein the drilling fluid further comprises about 0 to about 3 pounds per barrel of organophilic clay. 99. The method of claim 82 wherein the drilling fluid further comprises about 1 to about 3 pounds per barrel of organophilic clay. 100. The method of claim 82 wherein the drilling fluid further comprises a rheology modifier. 101. The method of claim 82 wherein the drilling fluid further comprises a rheology modifier comprising dimeric and trimeric fatty acids. 102. The method of claim 82 wherein the drilling fluid further comprises a filtration control agent. 103. The method of claim 82 wherein the drilling fluid further comprises a copolymer filtration control agent. 104. The method of claim 82 wherein the drilling fluid further comprises a methylstyrene/acrylate copolymer filtration control agent. 105. The method of claim 82 wherein the drilling fluid further comprises a thinner. 106. The method of claim 82 wherein the drilling fluid further 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. 107. The method of claim 82 wherein the drilling fluid further comprises one or more additives selected from the group consisting of: an emulsion stabilizer, a viscosifier, an HTHP additive, and a water activity lowering material. 108. The method of claim 82 wherein the drilling fluid meets or exceeds the minimum requirements for year 2002 environmental compatibility as tested in a 10-day Liptocheirus test and year 2002 biodegradability requirements of the United States Environmental Protection Agency. 109. The method of claim 82 wherein the drilling fluid has a lower yield point at a temperature of about 40�� F. than at a temperature of about 120�� F. when measured at a shear rate of about 0.03 s-1. 110. The method of claim 82 wherein the drilling fluid has a G'10/G'200 elastic modulus ratio greater than about 2. 111. The method of claim 82 wherein the drilling fluid has a yield point less than about 3 Pa at a shear rate of 3.0 s-1 or less. 112. The method of claim 82 wherein the drilling fluid has a Stress Build Function greater than about 3.8. 113. The method of claim 82 wherein the drilling is offshore. 114. The method of claim 82 wherein the drilling is conducted without a substantial loss of drilling fluid. 115. The method of claim 82 wherein the drilling fluid is viscoelastic. 116. The method of claim 82 wherein the drilling fluid is used in running casing and cementing with loss of the drilling fluid being less than about 100 barrels of total drilling fluid. 117. The method of claim 82 wherein the drilling fluid is used in drilling, running casing and cementing with loss of the drilling fluid being less than about 500 barrels of total drilling fluid. 118. The method of claim 82 wherein the drilling fluid is used in running casing and/or cementing a wellbore in the subterranean formation. 119. The method of claim 82 wherein the drilling comprises maintaining an average ECD of less than 0.5 over an interval of at least about 200 feet. 120. The method of claim 82 wherein the drilling is at a water depth of at least about 1,500 ft. 121. A method of drilling in a subterranean formation comprising the steps of: providing an invert emulsion drilling fluid comprising: a continuous phase, an internal phase, an emulsifier, and a weighting agent, wherein the drilling fluid has substantially equal dial readings at 40�� F. and at 120�� F. when measured at 6 rpm using a FANN viscometer at atmospheric pressure; drilling in the subterranean formation with the drilling fluid while maintaining an average ECD of less than 0.5 over an interval of at least about 200 feet; and stopping the drilling with substantially no sag in the drilling fluid. 122. The method of claim 121 wherein the continuous phase of the drilling fluid comprises an olefin. 123. The method of claim 121 wherein the continuous phase of the drilling fluid comprises an internal olefin. 124. The method of claim 121 wherein the continuous phase of the drilling fluid comprises an ester. 125. The method of claim 121 wherein the continuous phase of the drilling fluid comprises a paraffin hydrocarbon. 126. The method of claim 121 wherein the continuous phase of the drilling fluid comprises a mineral oil hydrocarbon. 127. The method of claim 121 wherein the continuous phase of the drilling fluid comprises a glyceride triester. 128. The method of claim 121 wherein the continuous phase of the drilling fluid comprises a naphthenic hydrocarbon. 129. The method of claim 121 wherein the continuous phase of the drilling fluid comprises a combination of components selected from the group consisting of: an ester, an olefin, a paraffin hydrocarbon, a mineral oil hydrocarbon, a glyceride triester, and a naphthenic hydrocarbon. 130. The method of claim 121 wherein the internal phase of the drilling fluid comprises water. 131. The method of claim 121 wherein the drilling fluid is substantially free of an organophilic filtration control agent. 132. The method of claim 121 wherein the drilling fluid is substantially free of lignite. 133. The method of claim 121 wherein the drilling fluid comprises substantially no organophilic clay and lignite. 134. The method of claim 121 wherein the drilling fluid comprises 0 to about 3 pounds per barrel of organophilic clay. 135. The method of claim 121 wherein the drilling fluid further comprises about 0 to about 1 pound per barrel of organophilic clay. 136. The method of claim 121 wherein the drilling fluid comprises 0 to about 2 pounds per barrel of organophilic clay. 137. The method of claim 121 wherein the drilling fluid further comprises about 0 to about 3 pounds per barrel of organophilic clay. 138. The method of claim 121 wherein the drilling fluid further comprises about 1 to about 3 pounds per barrel of organophilic clay. 139. The method of claim 121 wherein the drilling fluid further comprises a rheology modifier. 140. The method of claim 121 wherein the drilling fluid further comprises a rheology modifier comprising dimeric and trimeric fatty acids. 141. The method of claim 121 wherein the drilling fluid further comprises a filtration control agent. 142. The method of claim 121 wherein the drilling fluid further comprises a copolymer filtration control agent. 143. The method of claim 121 wherein the drilling fluid further comprises a methylstyrene/acrylate copolymer filtration control agent. 144. The method of claim 121 wherein the drilling fluid further comprises a thinner. 145. The method of claim 121 wherein the drilling fluid further 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. 146. The method of claim 121 wherein the drilling fluid further comprises one or more additives selected from the group consisting of: an emulsion stabilizer, a viscosifier, an HTHP additive, and a water activity lowering material. 147. The method of claim 121 wherein the drilling fluid meets or exceeds the minimum requirements for year 2002 environmental compatibility as tested in a 10-day Liptocheirus test and year 2002 biodegradability requirements of the United States Environmental Protection Agency. 148. The method of claim 121 wherein the drilling fluid has a lower yield point at a temperature of about 40�� F. than at a temperature of about 120�� F. when measured at a shear rate of about 0.03 s-1. 149. The method of claim 121 wherein the drilling fluid has a G'10/G'200 elastic modulus ratio greater than about 2. 150. The method of claim 121 wherein the drilling fluid has a yield point in the range of from about 1.6 Pa to about 2.9 Pa at a shear rate in the range of from 0.03 s-1 to 3.0 s-1. 151. The method of claim 121 wherein the drilling fluid has a Stress Build Function greater than about 3.8. 152. The method of claim 121 wherein the drilling is offshore. 153. The method of claim 121 wherein the drilling is conducted without a substantial loss of drilling fluid. 154. The method of claim 121 wherein the drilling fluid is viscoelastic. 155. The method of claim 121 wherein the drilling fluid is used in running casing and cementing with loss of the drilling fluid being less than about 100 barrels of total drilling fluid. 156. The method of claim 121 wherein the drilling fluid is used in drilling, running casing and cementing with loss of the drilling fluid being less than about 500 barrels of total drilling fluid. 157. The method of claim 121 wherein the drilling fluid is used in running casing and/or cementing a wellbore in the subterranean formation. 158. The method of claim 121 wherein the interval is at a depth in the range of 11,000 feet to 12,000 feet. 159. The method of claim 121 wherein the drilling is at a water depth of at least about 1,500 ft. 160. The method of claim 121 wherein the average ECD of less than 0.5 is maintained over an interval of at least about 300 feet. 161. The method of claim 121 wherein the average ECD of less than 0.5 is maintained over an interval of at least about 500 feet. 162. The method of claim 121 wherein the average ECD of less than 0.5 is maintained over an interval of at least about 1000 feet. 163. A method of drilling in a subterranean formation comprising the steps of: providing an invert emulsion drilling fluid, comprising: a continuous phase, an internal phase, an emulsifier, and a weighting agent, wherein the drilling fluid has substantially equal dial readings at 40�� F. and at 120�� F. when measured at 3 rpm using a FANN viscometer at atmospheric pressure; drilling in the subterranean formation with the drilling fluid; stopping the drilling while suspending the weighting agent in the drilling fluid; measuring pressure with pressure-while-drilling equipment or instruments; and resuming the drilling with substantially no pressure spike as detected by the pressure-while-drilling equipment or instruments. 164. The method of claim 163 wherein the continuous phase of the drilling fluid comprises an olefin. 165. The method of claim 163 wherein the continuous phase of the drilling fluid comprises an internal olefin. 166. The method of claim 163 wherein the continuous phase of the drilling fluid comprises an ester. 167. The method of claim 163 wherein the continuous phase of the drilling fluid comprises a paraffin hydrocarbon. 168. The method of claim 163 wherein the continuous phase of the drilling fluid comprises a mineral oil hydrocarbon. 169. The method of claim 163 wherein the continuous phase of the drilling fluid comprises a glyceride triester. 170. The method of claim 163 wherein the continuous phase of the drilling fluid comprises a naphthenic hydrocarbon. 171. The method of claim 163 wherein the continuous phase of the drilling fluid comprises a combination of components selected from the group consisting of: an ester, an olefin, a paraffin hydrocarbon, a mineral oil hydrocarbon, a glyceride triester, and a naphthenic hydrocarbon. 172. The method of claim 163 wherein the internal phase of the drilling fluid comprises water. 173. The method of claim 163 wherein the drilling fluid is substantially free of an organophilic filtration control agent. 174. The method of claim 163 wherein the drilling fluid is substantially free of lignite. 175. The method of claim 163 wherein the drilling fluid comprises substantially no organophilic clay and lignite. 176. The method of claim 163 wherein the drilling fluid comprises 0 to about 3 pounds per barrel of organophilic clay. 177. The method of claim 163 wherein the drilling fluid further comprises about 0 to about 1 pound per barrel of organophilic clay. 178. The method of claim 163 wherein the drilling fluid comprises 0 to about 2 pounds per barrel of organophilic clay. 179. The method of claim 163 wherein the drilling fluid further comprises about 0 to about 3 pounds per barrel of organophilic clay. 180. The method of claim 163 wherein the drilling fluid further comprises about 1 to about 3 pounds per barrel of organophilic clay. 181. The method of claim 163 wherein the drilling fluid further comprises a rheology modifier. 182. The method of claim 163 wherein the drilling fluid further comprises a rheology modifier comprising dimeric and trimeric fatty acids. 183. The method of claim 163 wherein the drilling fluid further comprises a filtration control agent. 184. The method of claim 163 wherein the drilling fluid further comprises a copolymer filtration control agent. 185. The method of claim 163 wherein the drilling fluid further comprises a methylstyrene/acrylate copolymer filtration control agent. 186. The method of claim 163 wherein the drilling fluid further comprises a thinner. 187. The method of claim 163 wherein the drilling fluid further 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. 188. The method of claim 163 wherein the drilling fluid further comprises one or more additives selected from the group consisting of: an emulsion stabilizer, a viscosifier, an HTHP additive, and a water activity lowering material. 189. The method of claim 163 wherein the drilling fluid meets or exceeds the minimum requirements for year 2002 environmental compatibility as tested in a 10-day Liptocheirus test and year 2002 biodegradability requirements of the United States Environmental Protection Agency. 190. The method of claim 163 wherein the drilling fluid has a lower yield point at a temperature of about 40�� F. than at a temperature of about 120�� F. when measured at a shear rate of about. 0.03 s-1. 191. The method of claim 163 wherein the drilling fluid has a G'10/G'200 elastic modulus ratio greater than about 2. 192. The method of claim 163 wherein the drilling fluid has a yield point in the range of from about 1.6 Pa to about 2.9 Pa at a shear rate in the range of from 0.03 s-1 to 3.0 s-1. 193. The method of claim 163 wherein the drilling fluid has a Stress Build Function greater than about 3.8. 194. The method of claim 163 wherein the drilling is offshore. 195. The method of claim 163 wherein the drilling is conducted without a substantial loss of drilling fluid. 196. The method of claim 163 wherein the drilling fluid is viscoelastic. 197. The method of claim 163 wherein the drilling fluid is used in running casing and cementing with loss of the drilling fluid being less than about 100 barrels of total drilling fluid. 198. The method of claim 163 wherein the drilling fluid is used in drilling, running casing and cementing with loss of the drilling fluid being less than about 500 barrels of total drilling fluid. 199. The method of claim 163 wherein the drilling fluid is used in running casing and/or cementing a wellbore in the subterranean formation. 200. The method of claim 163 wherein the drilling comprises maintaining an average ECD of less than 0.5 over an interval of at least about 200 feet. 201. The method of claim 163 wherein the interval is at a depth in the range of 11,000 ft to 12,000 ft. 202. A method of drilling in a subterranean formation comprising the steps of: providing an invert emulsion drilling fluid, comprising: a continuous phase, an internal phase, an emulsifier, and a weighting agent, wherein the drilling fluid has substantially equal dial readings at 40�� F. and at 120�� F. when measured at 3 rpm using a FANN viscometer at atmospheric pressure; drilling in the subterranean formation with the drilling fluid while maintaining an average ECD of less than 0.5 over an interval of at least about 200 feet; and stopping the drilling while suspending the weighting agent with the drilling fluid. 203. The method of claim 202 wherein the continuous phase of the drilling fluid comprises an olefin. 204. The method of claim 202 wherein the continuous phase of the drilling fluid comprises an internal olefin. 205. The method of claim 202 wherein the continuous phase of the drilling fluid comprises an ester. 206. The method of claim 202 wherein the continuous phase of the drilling fluid comprises a paraffin hydrocarbon. 207. The method of claim 202 wherein the continuous phase of the drilling fluid comprises a mineral oil hydrocarbon. 208. The method of claim 202 wherein the continuous phase of the drilling fluid comprises a glyceride triester. 209. The method of claim 202 wherein the continuous phase of the drilling fluid comprises a naphthenic hydrocarbon. 210. The method of claim 202 wherein the continuous phase of the drilling fluid comprises a combination of components selected from the group consisting of: an ester, an olefin, a paraffin hydrocarbon, a mineral oil hydrocarbon, a glyceride triester, and a naphthenic hydrocarbon. 211. The method of claim 202 wherein the internal phase of the drilling fluid comprises water. 212. The method of claim 202 wherein the drilling fluid is substantially free of an organophilic filtration control agent. 213. The method of claim 202 wherein the drilling fluid is substantially free of lignite. 214. The method of claim 202 wherein the drilling fluid comprises substantially no organophilic clay and lignite. 215. The method of claim 202 wherein the drilling fluid comprises 0 to about 3 pounds per barrel of organophilic clay. 216. The method of claim 202 wherein the drilling fluid further comprises about 0 to about 1 pound per barrel of organophilic clay. 217. The method of claim 202 wherein the drilling fluid comprises 0 to about 2 pounds per barrel of organophilic clay. 218. The method of claim 202 wherein the drilling fluid further comprises about 0 to about 3 pounds per barrel of organophilic clay. 219. The method of claim 202 wherein the drilling fluid further comprises about 1 to about 3 pounds per barrel of organophilic clay. 220. The method of claim 202 wherein the drilling fluid further comprises a rheology modifier. 221. The method of claim 202 wherein the drilling fluid further comprises a rheology modifier comprising dimeric and trimeric fatty acids. 222. The method of claim 202 wherein the drilling fluid further comprises a filtration control agent. 223. The method of claim 202 wherein the drilling fluid further comprises a copolymer filtration control agent. 224. The method of claim 202 wherein the drilling fluid further comprises a methylstyrene/acrylate copolymer filtration control agent. 225. The method of claim 202 wherein the drilling fluid further comprises a thinner. 226. The method of claim 202 wherein the drilling fluid further 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. 227. The method of claim 202 wherein the drilling fluid further comprises one or more additives selected from the group consisting of: an emulsion stabilizer, a viscosifier, an HTHP additive, and a water activity lowering material. 228. The method of claim 202 wherein the drilling fluid meets or exceeds the minimum requirements for year 2002 environmental compatibility as tested in a 10-day Liptocheirus test and year 2002 biodegradability requirements of the United States Environmental Protection Agency. 229. The method of claim 202 wherein the drilling fluid has a lower yield point at a temperature of about 40�� F. than at a temperature of about 120�� F. when measured at a shear rate of about 0.03 s31 1. 230. The method of claim 202 wherein the drilling fluid has a G'10/G'200 elastic modulus ratio greater than about 2. 231. The method of claim 202 wherein the drilling fluid has a yield point in the range of from about 1.6 Pa to about 2.9 Pa at a shear rate in the range of from 0.03 s-1 to 3.0 s-1. 232. The method of claim 202 wherein the drilling fluid has a Stress Build Function greater than about 3.8. 233. The method of claim 202 wherein the drilling is offshore. 234. The method of claim 202 wherein the drilling is conducted without a substantial loss of drilling fluid. 235. The method of claim 202 wherein the drilling fluid is viscoelastic. 236. The method of claim 202 wherein the drilling fluid is used in running casing and cementing with loss of the drilling fluid being less than about 100 barrels of total drilling fluid. 237. The method of claim 202 wherein the drilling fluid is used in drilling, running casing and cementing with loss of the drilling fluid being less than about 500 barrels of total drilling fluid. 238. The method of claim 202 wherein the drilling fluid is used in running casing and/or cementing a wellbore in the subterranean formation. 239. The method of claim 202 wherein the interval is at a depth in the range of 11,000 feet to 12,000 feet. 240. The method of claim 202 wherein the drilling is at a water depth of at least about 1,500 ft. 241. The method of claim 202 wherein the average ECD of less than 0.5 is maintained over an interval of at least about 300 feet. 242. The method of claim 202 wherein the average ECD of less than 0.5 is maintained over an interval of at least about 500 feet. 243. The method of claim 202 wherein the average ECD of less than 0.5 is maintained over an interval of at least about 1000 feet. 244. A method of drilling in a subterranean formation comprising the steps of: providing an invert emulsion drilling fluid, comprising: a continuous phase, an internal phase, an emulsifier, and a weighting agent, wherein the drilling fluid has substantially equal dial readings at 40�� F. and at 120�� F. when measured at 3 rpm using a FANN viscometer at atmospheric pressure; drilling in the subterranean formation with the drilling fluid; stopping the drilling with substantially no sag in the drilling fluid; measuring pressure with pressure-while-drilling equipment or instruments; and resuming the drilling with substantially no pressure spike as detected by the pressure-while-drilling equipment or instruments. 245. The method of claim 244 wherein the continuous phase of the drilling fluid comprises an olefin. 246. The method of claim 244 wherein the continuous phase of the drilling fluid comprises an internal olefin. 247. The method of claim 244 wherein the continuous phase of the drilling fluid comprises an ester. 248. The method of claim 244 wherein the continuous phase of the drilling fluid comprises a paraffin hydrocarbon. 249. The method of claim 244 wherein the continuous phase of the drilling fluid comprises a mineral oil hydrocarbon. 250. The method of claim 244 wherein the continuous phase of the drilling fluid comprises a glyceride triester. 251. The method of claim 244 wherein the continuous phase of the drilling fluid comprises a naphthenic hydrocarbon. 252. The method of claim 244 wherein the continuous phase of the drilling fluid comprises a combination of components selected from the group consisting of: an ester, an olefin, a paraffin hydrocarbon, a mineral oil hydrocarbon, a glyceride triester, and a naphthenic hydrocarbon. 253. The method of claim 244 wherein the internal phase of the drilling fluid comprises water. 254. The method of claim 244 wherein the drilling fluid is substantially free of an organophilic filtration control agent. 255. The method of claim 244 wherein the drilling fluid is substantially free of lignite. 256. The method of claim 244 wherein the drilling fluid comprises substantially no organophilic clay and lignite. 257. The method of claim 244 wherein the drilling fluid comprises 0 to about 3 pounds per barrel of organophilic clay. 258. The method of claim 244 wherein the drilling fluid further comprises about 0 to about 1 pound per barrel of organophilic clay. 259. The method of claim 244 wherein the drilling fluid comprises 0 to about 2 pounds per barrel of organophilic clay. 260. The method of claim 244 wherein the drilling fluid further comprises about 0 to about 3 pounds per barrel of organophilic clay. 261. The method of claim 244 wherein the drilling fluid further comprises about 1 to about 3 pounds per barrel of organophilic clay. 262. The method of claim 244 wherein the drilling fluid further comprises a rheology modifier. 263. The method of claim 244 wherein the drilling fluid further comprises a rheology modifier comprising dimeric and trimeric fatty acids. 264. The method of claim 244 wherein the drilling fluid further comprises a filtration control agent. 265. The method of claim 244 wherein the drilling fluid further comprises a copolymer filtration control agent. 266. The method of claim 244 wherein the drilling fluid further comprises a methylstyrene/acrylate copolymer filtration control agent. 267. The method of claim 244 wherein the drilling fluid further comprises a thinner. 268. The method of claim 244 wherein the drilling fluid further 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. 269. The method of claim 244 wherein the drilling fluid further comprises one or more additives selected from the group consisting of: an emulsion stabilizer, a viscosifier, an HTHP additive, and a water activity lowering material. 270. The method of claim 244 wherein the drilling fluid meets or exceeds the minimum requirements for year 2002 environmental compatibility as tested in a 10-day Liptocheirus test and year 2002 biodegradability requirements of the United States Environmental Protection Agency. 271. The method of claim 244 wherein the drilling fluid has a lower yield point at a temperature of about 40�� F. than at a temperature of about 120�� F. when measured at a shear rate of about 0.03 s-1. 272. The method of claim 244 wherein the drilling fluid has a G'10/G'200 elastic modulus ratio greater than about 2. 273. The method of claim 244 wherein the drilling fluid has a yield point in the range of from about 1.6 Pa to about 2.9 Pa at a shear rate in the range of from 0.03 s-1 to 3.0 s-1. 274. The method of claim 244 wherein the drilling fluid has a Stress Build Function greater than about 3.8. 275. The method of claim 244 wherein the drilling is offshore. 276. The method of claim 244 wherein the drilling is conducted without a substantial loss of drilling fluid. 277. The method of claim 244 wherein the drilling fluid is viscoelastic. 278. The method of claim 244 wherein the drilling fluid is used in running casing and cementing with loss of the drilling fluid being less than about 100 barrels of total drilling fluid. 279. The method of claim 244 wherein the drilling fluid is used in drilling, running casing and cementing with loss of the drilling fluid being less than about 500 barrels of total drilling fluid. 280. The method of claim 244 wherein the drilling fluid is used in running casing and/or cementing a wellbore in the subterranean formation. 281. The method of claim 244 wherein the drilling comprises maintaining an average LCD of less than 0.5 over an interval of at least about 200 feet. 282. The method of claim 244 wherein the drilling is at a water depth of at least about 1,500 ft. 283. A method of drilling in a subterranean formation comprising the steps of: providing an invert emulsion drilling fluid comprising: a continuous phase, an internal phase, an emulsifier, and a weighting agent, wherein the drilling fluid has substantially equal dial readings at 40�� F. and at 120�� F. when measured at 3 rpm using a FANN viscometer at atmospheric pressure; drilling in the subterranean formation with the drilling fluid while maintaining an average ECD of less than 0.5 over an interval of at least about 200 feet; and stopping the drilling with substantially no sag in the drilling fluid. 284. The method of claim 283 wherein the continuous phase of the drilling fluid comprises an olefin. 285. The method of claim 283 wherein the continuous phase of the drilling fluid comprises an internal olefin. 286. The method of claim 283 wherein the continuous phase of the drilling fluid comprises an ester. 287. The method of claim 283 wherein the continuous phase of the drilling fluid comprises a paraffin hydrocarbon. 288. The method of claim 283 wherein the continuous phase of the drilling fluid comprises a mineral oil hydrocarbon. 289. The method of claim 283 wherein the continuous phase of the drilling fluid comprises a glyceride triester. 290. The method of claim 283 wherein the continuous phase of the drilling fluid comprises a naphthenic hydrocarbon. 291. The method of claim 283 wherein the continuous phase of the drilling fluid comprises a combination of components selected from the group consisting of: an ester, an olefin, a paraffin hydrocarbon, a mineral oil hydrocarbon, a glyceride triester, and a naphthenic hydrocarbon. 292. The method of claim 283 wherein the internal phase of the drilling fluid comprises water. 293. The method of claim 283 wherein the drilling fluid is substantially free of an organophilic filtration control agent. 294. The method of claim 283 wherein the drilling fluid is substantially free of lignite. 295. The method of claim 283 wherein the drilling fluid comprises substantially no organophilic clay and lignite. 296. The method of claim 283 wherein the drilling fluid comprises 0 to about 3 pounds per barrel of organophilic clay. 297. The method of claim 283 wherein the drilling fluid further comprises about 0 to about 1 pound per barrel of organophilic clay. 298. The method of claim 283 wherein the drilling fluid comprises 0 to about 2 pounds per barrel of organophilic clay. 299. The method of claim 283 wherein the drilling fluid further comprises about 0 to about 3 pounds per barrel of organophilic clay. 300. The method of claim 283 wherein the drilling fluid further comprises about 1 to about 3 pounds per barrel of organophilic clay. 301. The method of claim 283 wherein the drilling fluid further comprises a rheology modifier. 302. The method of claim 283 wherein the drilling fluid further comprises a rheology modifier comprising dimeric and trimeric fatty acids. 303. The method of claim 283 wherein the drilling fluid further comprises a filtration control agent. 304. The method of claim 283 wherein the drilling fluid further comprises a copolymer filtration control agent. 305. The method of claim 283 wherein the drilling fluid further comprises a methylstyrene/acrylate copolymer filtration control agent. 306. The method of claim 283 wherein the drilling fluid further comprises a thinner. 307. The method of claim 283 wherein the drilling fluid further 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. 308. The method of claim 283 wherein the drilling fluid further comprises one or more additives selected from the group consisting of: an emulsion stabilizer, a viscosifier, an HTHP additive, and a water activity lowering material. 309. The method of claim 283 wherein the drilling fluid meets or exceeds the minimum requirements for year 2002 environmental compatibility as tested in a 10-day Liptocheirus test and year 2002 biodegradability requirements of the United States Environmental Protection Agency. 310. The method of claim 283 wherein the drilling fluid has a lower yield point at a temperature of about 40�� F. than at a temperature of about 120�� F. when measured at a shear rate of about 0.03 s-1. 311. The method of claim 283 wherein the drilling fluid has a G'10/G'200 elastic modulus ratio greater than about 2. 312. The method of claim 283 wherein the drilling fluid has a yield point in the range of from about 1.6 Pa to about 2.9 Pa at a shear rate in the range of from 0.03 s-1 to 3.0 s-1. 313. The method of claim 283 wherein the drilling fluid has a Stress Build Function greater than about 3.8. 314. The method of claim 283 wherein the drilling is offshore. 315. The method of claim 283 wherein the drilling is conducted without a substantial loss of drilling fluid. 316. The method of claim 283 wherein the drilling fluid is viscoelastic. 317. The method of claim 283 wherein the drilling fluid is used in running casing and cementing with loss of the drilling fluid being less than about 100 barrels of total drilling fluid. 318. The method of claim 283 wherein the drilling fluid is used in drilling, running casing and cementing with loss of the drilling fluid being less than about 500 barrels of total drilling fluid. 319. The method of claim 283 wherein the drilling fluid is used in running casing and/or cementing a wellbore in the subterranean formation. 320. The method of claim 283 wherein the interval is at a depth in the range of 11,000 feet to 12,000 feet. 321. The method of claim 283 wherein the drilling is at a water depth of at least about 1,500 ft. 322. The method of claim 283 wherein the average ECD of less than 0.5 is maintained over an interval of at least about 300 feet. 323. The method of claim 283 wherein the average ECD of less than 0.5 is maintained over an interval of at least about 500 feet. 324. The method of claim 283 wherein the average ECD of less than 0.5 is maintained over an interval of at least about 1000 feet.
Copyright KISTI. All Rights Reserved.
※ AI-Helper는 부적절한 답변을 할 수 있습니다.