Contributors |
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xi | |
Preface |
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xv | |
Acknowledgments |
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xvii | |
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1 Introduction to chemical enhanced oil recovery |
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1 | (32) |
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1 | (2) |
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3 | (20) |
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23 | (10) |
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26 | (7) |
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33 | (62) |
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33 | (1) |
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2.2 Classification of EOR polymers |
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34 | (2) |
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2.3 Polymers features and screening criteria |
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36 | (7) |
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43 | (7) |
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2.5 Polymer as fracturing fluid in oil reservoir |
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50 | (1) |
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51 | (1) |
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2.7 Displacement mechanisms in polymer flooding |
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52 | (4) |
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2.8 Fractional flow curve analysis |
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56 | (4) |
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2.9 Polymer flooding performance |
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60 | (2) |
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2.10 Polymer flooding in heavy oil recovery |
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62 | (3) |
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2.11 Polymer flooding design and offshore experiences |
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65 | (3) |
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2.12 Modeling and simulations |
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68 | (6) |
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74 | (1) |
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2.14 Laboratory tests and interpretation of the results |
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75 | (4) |
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79 | (4) |
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83 | (1) |
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84 | (2) |
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86 | (1) |
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87 | (2) |
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2.20 Economics and feasibility study of polymer flooding processes |
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89 | (6) |
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92 | (3) |
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3 Enhanced oil recovery using surfactants |
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95 | (46) |
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95 | (1) |
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96 | (3) |
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3.3 Chemicals used in surfactant flooding |
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99 | (1) |
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3.4 Thermal and aqueous stability |
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100 | (3) |
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103 | (4) |
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107 | (3) |
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3.7 Emulsion formation and treatment |
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110 | (1) |
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111 | (17) |
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128 | (2) |
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130 | (3) |
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133 | (8) |
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136 | (5) |
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141 | (80) |
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141 | (1) |
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4.2 Commonly used alkaline agents |
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141 | (1) |
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142 | (7) |
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149 | (11) |
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4.5 Effect of reservoir condition on alkaline process |
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160 | (1) |
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4.6 Geology and lithologic variation of reservoir |
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161 | (1) |
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162 | (1) |
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4.8 Salinity effect on alkaline flooding |
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163 | (3) |
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4.9 Effects of oil composition on alkaline flooding |
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166 | (5) |
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4.10 Ternary diagram in alkaline flooding |
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171 | (3) |
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4.11 Success rate and screening criteria |
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174 | (1) |
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4.12 Displacement efficiency in alkaline process |
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175 | (2) |
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4.13 Combined flooding processes |
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177 | (1) |
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4.14 Simulation and modeling |
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178 | (10) |
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4.15 Application of machine learning |
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188 | (5) |
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4.16 Surveillance and monitoring of alkaline flooding |
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193 | (1) |
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4.17 Application conditions of the alkaline flooding project |
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194 | (27) |
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196 | (17) |
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213 | (8) |
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5 Alkaline-surfactant polymer (ASP) |
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221 | (28) |
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221 | (1) |
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5.2 Synergy of alkaline, surfactant, and polymer constituents |
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221 | (2) |
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223 | (3) |
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5.4 Emulsion properties and stability |
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226 | (1) |
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227 | (1) |
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5.6 Mechanism descriptions |
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228 | (1) |
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5.7 Factors that influence IFT |
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229 | (1) |
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5.8 Factors that influence wettability |
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229 | (1) |
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230 | (1) |
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5.10 Surfactant polymer adsorption |
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230 | (1) |
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5.11 Modeling and simulations |
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231 | (1) |
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5.12 Application of machine learning |
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232 | (1) |
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5.13 Optimization the design of ASP injection |
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233 | (1) |
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234 | (2) |
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236 | (1) |
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237 | (1) |
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5.17 Field examples and performance |
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238 | (1) |
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5.18 ASP flooding: Field challenges |
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239 | (10) |
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242 | (7) |
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6 Improved oil recovery by gel technology: Water shutoff and conformance control |
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249 | (64) |
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249 | (2) |
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6.2 Excessive water control |
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251 | (3) |
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254 | (8) |
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262 | (11) |
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6.5 Preformed particle gel (PPG) |
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273 | (15) |
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6.6 Temperature-activated polymer gel (TAP) |
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288 | (4) |
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6.7 pH-sensitive microgel |
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292 | (21) |
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302 | (11) |
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313 | (44) |
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313 | (1) |
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7.2 Condition for smart water injection in sandstone reservoirs |
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313 | (1) |
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7.3 Condition for smart water injection in carbonate reservoirs |
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314 | (1) |
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7.4 Factors influencing smart water |
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315 | (5) |
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7.5 Physical and chemical mechanisms of recovery |
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320 | (12) |
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7.6 Injected and formation brine interaction |
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332 | (1) |
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333 | (1) |
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334 | (1) |
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7.9 Dynamic investigation of contact angle and interfacial tension |
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335 | (2) |
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7.10 Heterogeneity and fluid diversion 9 |
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337 | (1) |
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7.11 Effect on relative permeability curve |
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337 | (1) |
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338 | (1) |
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338 | (1) |
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339 | (2) |
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341 | (1) |
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342 | (2) |
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344 | (1) |
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345 | (1) |
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345 | (1) |
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7.20 Economic and environmental feasibility |
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345 | (12) |
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346 | (11) |
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8 A comprehensive review on the use of eco-friendly surfactants in oil industry |
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357 | (44) |
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357 | (1) |
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357 | (18) |
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375 | (1) |
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8.4 Surfactant EOR mechanisms |
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375 | (7) |
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8.5 Effect of eco-friendly surfactants on the I FT, wettability alteration, and oil recovery |
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382 | (5) |
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8.6 Other applications of surfactant |
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387 | (1) |
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8.7 Future perspectives, recommendations, and challenges |
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388 | (13) |
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390 | (11) |
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9 Combination of chemical methods |
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401 | (32) |
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401 | (1) |
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9.2 Key components of combined chemical methods |
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401 | (4) |
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9.3 Combined chemical EOR methods |
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405 | (12) |
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9.4 Comparison of different methods |
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417 | (1) |
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9.5 Screening criteria for selecting the combined EOR methods |
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417 | (3) |
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9.6 Modeling and simulations |
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420 | (1) |
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9.7 Application of machine learning |
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420 | (1) |
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421 | (2) |
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423 | (1) |
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9.10 Economic and environmental feasibility |
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424 | (9) |
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425 | (8) |
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10 Chemical enhanced oil recovery in unconventional reservoirs |
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433 | (28) |
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433 | (2) |
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10.2 Unconventional reservoirs description |
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435 | (6) |
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10.3 Coalbed methane reservoirs |
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441 | (2) |
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10.4 Heavy oil and tar sands |
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443 | (3) |
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10.5 Shale oil and gas reservoirs |
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446 | (7) |
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453 | (2) |
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10.7 Screening criteria/challenging |
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455 | (6) |
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457 | (4) |
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11 Formation damage during chemical flooding |
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461 | (15) |
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461 | (2) |
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11.2 Problems associated with different chemical methods |
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463 | (7) |
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11.3 Combined CEOR processes |
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470 | (3) |
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11.4 Techniques to mitigate FD during EOR processes |
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473 | (1) |
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11.5 Identification of risk and opportunity of EOR projects |
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474 | (2) |
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11.6 Summary and conclusions |
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476 | (1) |
References |
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476 | (3) |
Index |
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479 | |