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Carbon Dioxide Sequestration and Related Technologies - Ying Wu
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Ying Wu:
Carbon Dioxide Sequestration and Related Technologies - new book

ISBN: 9781118175545

ID: 9781118175545

Inhaltsangabe< b> Introduction< /b> < p> < b> The Three Sisters - CCS, AGI, and EOR xix< br> < /b> < i> Ying Wu, John J. Carroll and Zhimin Du< /i> < p> < b> Section 1: Data and Correlation< /b> < p> < b> 1. Prediction of Acid Gas Dew Points in the Presence of Water and Volatile Organic Compounds 3< /b> < br> < i> Ray. A. Tomcej< /i> < p> 1.1 Introduction 3< p> 1.2 Previous Studies 4< p> 1.3 Thermodynamic Model 5< p> 1.4 Calculation Results 6< p> 1.5 Discussion 10< p> < b> 2. Phase Behavior of China Reservoir Oil at Different C02 Injected Concentrations 13< /b> < br> < i> Fengguang Li, Xin Yang, Changyu Sun, and Guangjin Chen< /i> < p> 2.1 Introduction 14< p> 2.2 Preparation of Reservoir Fluid 14< p> 2.3 PVT Phase Behavior for the C02 Injected Crude Oil 15< p> 2.4 Viscosity of the C02 Injected Crude Oil 17< p> 2.5 Interfacial Tension for C02 Injected Crude Oil/Strata Water 19< p> 2.6 Conclusions 20< p> < b> 3. Viscosity and Density Measurements for Sour Gas Fluids at High Temperatures and Pressures 23< br> < /b> < i> B.R. Giri, P. Biais and R.A. Marriott< /i> < p> 3.1 Introduction 24< p> 3.2 Experimental 25< p> 3.3 Results 31< p> 3.4 Conclusions 37< p> < b> 4. Acid Gas Viscosity Modeling with the Expanded Fluid Viscosity Correlation 41< br> < /b> < i> H. Motahhari, M.A. Satyro, H.W. Yarranton< /i> < p> 4.1 Introduction 41< p> 4.2 Expanded Fluid Viscosity Correlation 42< p> 4.3 Results and Discussion 47< p> 4.4 Conclusions 52< p> 4.5 Acknowledgements 52< p> < b> 5. Evaluation and Improvement of Sour Property Packages in Unisim Design 55< br> < /b> < i> Jianyong Yang, Ensheng Zhao, Laurie Wang, and Sanjoy Saha< /i> < p> 5.1 Introduction 55< p> 5.2 Model Description 56< p> 5.3 Phase Equilibrium Calculation 58< p> 5.4 Conclusions 62< p> 5.5 Future Work 62< p> < b> 6. Compressibility Factor of High C02-Content Natural Gases: Measurement and Correlation 65< br> < /b> < i> Xiaoqiang Bian, Zhimin Du, Yong Tang, and Jianfen Du< /i> < p> 6.1 Introduction 65< p> 6.2 Experiment 67< p> 6.3 Methods 68< p> 6.5 Comparison of the Proposed Method and Other Methods 78< p> 6.6 Conclusions 83< p> 6.7 Acknowledgements 84< p> 6.8 Nomenclature 84< p> < b> Section 2: Process Engineering< /b> < p> < b> 7. Analysis of Acid Gas Injection Variables 89< br> < /b> < i> Edward Wiehert and James van der Lee< /i> < p> 7.1 Introduction 89< p> 7.2 Discussion 90< p> 7.3 Program Design 93< p> 7.4 Results 94< p> 7.5 Discussion of Results 96< p> 7.6 Conclusion 105< p> < b> 8. Glycol Dehydration as a Mass Transfer Rate Process 107< br> < /b> < i> Nathan A. Hatcher, Jaime L. Nava and Ralph H. Weiland< /i> < p> 8.1 Phase Equilibrium 108< p> 8.2 Process Simulation 110< p> 8.3 Dehydration Column Performance 111< p> 8.4 Stahl Columns and Stripping Gas 114< p> 8.5 Interesting Observations from a Mass Transfer Rate Model 115< p> 8.6 Factors That Affect Dehydration of Sweet Gases 118< p> 8.7 Dehydration of Acid Gases 119< p> 8.8 Conclusions 119< p> < b> 9. Carbon Capture Using Amine-Based Technology 121< br> < /b> < i> Ben Spooner and David Engel< /i> < p> 9.1 Amine Applications 121< p> 9.2 Amine Technology 122< p> 9.3 Reaction Chemistry 124< p> 9.4 Types of Amine 126< p> 9.5 Challenges of Carbon Capture 128< p> 9.6 Conclusion 131< p> < b> 10. Dehydration-through-Compression (DTC): Is It Adequate A Tale of Three Gases 133< br> < /b> < i> Wes H. Wright< /i> < p> 10.1 Background 133< p> 10.2 Water Saturation 138< p> 10.3 Is It Adequate 138< p> 10.4 The Gases 141< p> 10.5 Results 147< p> 10.6 Discussion 151< p> < b> 11. Diaphragm P 211< p> 13.3 Model Parameters 216< p> 13.4 Results 218< p> 13.5 Discussion 221< p> 13.6 Conclusions 223< p> 13.7 Acknowledgment 224< p> < b> 14. Complex Flow Mathematical Model of Gas Pool with Sulfur Deposition 227< br> < /b> < i> W. Zhu, Y. Long, Q. Liu, Y. Ju, and X. Huang< /i> < p> 14.1 Introduction 227< p> 14.2 The Mathematical Model of Multiphase Complex Flow 228< p> 14.3 Mathematical Models of Flow Mechanisms 232< p> 14.4 Solution of the Mathematical Model Equations 238< p> 14.5 Example 240< p> 14.6 Conclusions 242< p> 14.7 Acknowledgement 242< p> < b> Section 4: Enhanced Oil Recovery (EOR)< /b> < p> < b> 15. Enhanced Oil Recovery Project: Dunvegan C Pool 247< br> < /b> < i> Darryl Burns< /i> < p> 15.1 Introduction 248< p> 15.2 Pool Data Collection 249< p> 15.3 Pool Event Log 252< p> 15.4 Reservoir Fluid Characterization 255< p> 15.5 Material Balance 263< p> 15.6 Geological Model 264< p> 15.7 Geological Uncertainty 269< p> 15.8 History Match 272< p> 15.9 Black Oil to Compositional Model Conversion 282< p> 15.10 Recovery Alternatives 290< p> 15.11 Economics 307< p> 15.12 Economic Uncertainty 312< p> 15.13 Discussion and Learning 312< p> 15.14 End Note 317< p> < b> 16. C02 Flooding as an EOR Method for Low Permeability Reservoirs 319< br> < /b> < i> Yongle Hu, Yunpeng Hu, Qin Li, Lei Huang, Mingqiang Hao, and Siyu Yang< /i> < p> 16.1 Introduction 319< p> 16.2 Field Experiment of C02 Flooding in China 320< p> 16.3 Mechanism of C02 Flooding Displacement 321< p> 16.4 Perspective 324< p> 16.5 Conclusion 326< p> < b> 17. Pilot Test Research on C02 Drive in Very Low Permeability Oil Field of in Daqing Changyuan 329< br> < /b> < i> Weiyao Zhu, Jiecheng Cheng, Xiaohe Huang, Yunqian Long, and Y. Lou< /i> < p> 17.1 Introduction 329< p> 17.2 Laboratory Test Study on C02 Flooding in Oil Reservoirs with Very Low Permeability 330< p> 17.3 Field Testing Research 333< p> 17.4 Conclusion 346< p> 17.5 Acknowledgement 349< p> < b> 18. Operation Control of C02-Driving in Field Site. Site Test in Wellblock Shu 101, Yushulin Oil Field, Daqing 351< br> < /b> < i> Xinde Wan, Tao Sun, Yingzhi Zhang, Tiejun Yang, and Changhe Mu< /i> < p> 18.1 Test Area Description 352< p> 18.2 Test Effect and Cognition 353< p> 18.3 Conclusions 359< p> < b> 19. Application of Heteropolysaccharide in Acid Gas Injection 361< br> < /b> < i> Jie Zhang, Gang Guo and Shugang Li< /i> < p> 19.1 Introduction 361< p> 19.2 Application of Heteropolysaccharide in C02 Reinjection Miscible Phase Recovery 363< p> 19.3 Application of Heteropolysaccharide in H2S Reinjection formation 370< p> 19.4 Conclusions 373< p> < b> Section 5: Geology and Geochemistry< /b> < p> < b> 20. Impact of S02 and NO on Carbonated Rocks Submitted to a Geological Storage of C02: An Experimental Study 377< br> < /b> < i> St& #233 phane Renard, J& #233 r& #244 me Sterpenich, Jacques Pironon, Aur& #233 lien Randi, Pierre Chiquet and Marc Lescanne< /i> < p> 20.1 Introduction 377< p> 20.2 Apparatus and Methods 378< p> 20.3 Results and Discussion 381< p> 20.4 Conclusion 391< p> < b> 21. Geochemical Modeling of Huff &apos N&apos Puff Oil Recovery With C02 at the Northwest Mcgregor Oil Field 393< br> < /b> < i> Yevhen I. Holubnyak, Blaise A.F. Mibeck, Jordan M. Bremer, Steven A. Smith, James A. Sorensen, Charles D. Gorecki, Edward N. Steadman, and John A. Harju< /i> < p> 21.1 Introduction 393< p> 21.2 Northwest McGregor Location and Geological Setting 395< p> 21.3 The Northwest McGregor Field, E. Goetz #1 Well Operational History 395< p> 21.4 Reservoir Mineralogy 397< p> 21.5 Preinjection and Postinjection Reservoir Fluid Analysis 398< p> 21.6 Major Observations and the Anal < b> Section 6: Well Technology< /b> < p> < b> 23 Well Cement Aging in Various H2S-C02 Flui( is at High Pressure and High Temperature: Experiments and Modelling 423< br> < /b> < i> Nicolas Jacquemet, Jacques Pironon, Vincent Lagneau, J& #233 r& #233 mie Saint-Marc< /i> < p> 23.1 Introduction 424< p> 23.2 Experimental equipment 425< p> 23.3 Materials, Experimental Conditions and Analysis 426< p> 23.4 Results and Discussion 428< p> 23.5 Reactive Transport Modelling 430< p> 23.6 Conclusion 432< p> < b> 24. Casing Selection and Correlation Technology for Ultra-Deep, Ultra- High Pressure, High H2S Gas Wells 437< br> < /b> < i> Yongxing Sun, Yuanhua Lin, Taihe Shi, Zhongsheng Wang, Dajiang Zhu, Liping Chen, Sujun Liu, and Dezhi Zeng< /i> < p> 24.1 Introduction 438< p> 24.2 Material Selection Recommended Practice 438< p> 24.3 Casing Selection and Correlation Technology 441< p> 24.4 Field Applications 443< p> 24.4 Conclusions 445< p> 24.5 Acknowledgments 447< p> < b> 25. Coupled Mathematical Model of Gas Migration in Cemented Annulus with Mud Column in Acid Gas Well 449< br> < /b> < i> Hongjun Zhu, Yuanhua Lin, Yongxing Sun, Dezhi Zeng, Zhi Zhang, and Taihe Shi< /i> < p> 25.1 Introduction 449< p> 25.2 Coupled Mathematical Model 450< p> 25.3 Illustration 458< p> 25.4 Conclusions 459< p> 25.5 Nomenclature 460< p> 25.6 Acknowledgment 461< p> < b> Section 7: Corrosion< /b> < p> < b> 26. Study on Corrosion Resistance of L245/825 Lined Steel Pipe Welding Gap in H2S+C02 Environment 465< br> < /b> < i> Dezhi Zeng, Yuanhua Lin, Liming Huang, Daijiang Zhu, Tan Gu, Taihe Shi, and Yongxing Sun< /i Carbon Dioxide Sequestration and Related Technologies: Inhaltsangabe< b> Introduction< /b> < p> < b> The Three Sisters - CCS, AGI, and EOR xix< br> < /b> < i> Ying Wu, John J. Carroll and Zhimin Du< /i> < p> < b> Section 1: Data and Correlation< /b> < p> < b> 1. Prediction of Acid Gas Dew Points in the Presence of Water and Volatile Organic Compounds 3< /b> < br> < i> Ray. A. Tomcej< /i> < p> 1.1 Introduction 3< p> 1.2 Previous Studies 4< p> 1.3 Thermodynamic Model 5< p> 1.4 Calculation Results 6< p> 1.5 Discussion 10< p> < b> 2. Phase Behavior of China Reservoir Oil at Different C02 Injected Concentrations 13< /b> < br> < i> Fengguang Li, Xin Yang, Changyu Sun, and Guangjin Chen< /i> < p> 2.1 Introduction 14< p> 2.2 Preparation of Reservoir Fluid 14< p> 2.3 PVT Phase Behavior for the C02 Injected Crude Oil 15< p> 2.4 Viscosity of the C02 Injected Crude Oil 17< p> 2.5 Interfacial Tension for C02 Injected Crude Oil/Strata Water 19< p> 2.6 Conclusions 20< p> < b> 3. Viscosity and Density Measurements for Sour Gas Fluids at High Temperatures and Pressures 23< br> < /b> < i> B.R. Giri, P. Biais and R.A. Marriott< /i> < p> 3.1 Introduction 24< p> 3.2 Experimental 25< p> 3.3 Results 31< p> 3.4 Conclusions 37< p> < b> 4. Acid Gas Viscosity Modeling with the Expanded Fluid Viscosity Correlation 41< br> < /b> < i> H. Motahhari, M.A. Satyro, H.W. Yarranton< /i> < p> 4.1 Introduction 41< p> 4.2 Expanded Fluid Viscosity Correlation 42< p> 4.3 Results and Discussion 47< p> 4.4 Conclusions 52< p> 4.5 Acknowledgements 52< p> < b> 5. Evaluation and Improvement of Sour Property Packages in Unisim Design 55< br> < /b> < i> Jianyong Yang, Ensheng Zhao, Laurie Wang, and Sanjoy Saha< /i> < p> 5.1 Introduction 55< p> 5.2 Model Description 56< p> 5.3 Phase Equilibrium Calculation 58< p> 5.4 Conclusions 62< p> 5.5 Future Work 62< p> < b> 6. Compressibility Factor of High C02-Content Natural Gases: Measurement and Correlation 65< br> < /b> < i> Xiaoqiang Bian, Zhimin Du, Yong Tang, and Jianfen Du< /i> < p> 6.1 Introduction 65< p> 6.2 Experiment 67< p> 6.3 Methods 68< p> 6.5 Comparison of the Proposed Method and Other Methods 78< p> 6.6 Conclusions 83< p> 6.7 Acknowledgements 84< p> 6.8 Nomenclature 84< p> < b> Section 2: Process Engineering< /b> < p> < b> 7. Analysis of Acid Gas Injection Variables 89< br> < /b> < i> Edward Wiehert and James van der Lee< /i> < p> 7.1 Introduction 89< p> 7.2 Discussion 90< p> 7.3 Program Design 93< p> 7.4 Results 94< p> 7.5 Discussion of Results 96< p> 7.6 Conclusion 105< p> < b> 8. Glycol Dehydration as a Mass Transfer Rate Process 107< br> < /b> < i> Nathan A. Hatcher, Jaime L. Nava and Ralph H. Weiland< /i> < p> 8.1 Phase Equilibrium 108< p> 8.2 Process Simulation 110< p> 8.3 Dehydration Column Performance 111< p> 8.4 Stahl Columns and Stripping Gas 114< p> 8.5 Interesting Observations from a Mass Transfer Rate Model 115< p> 8.6 Factors That Affect Dehydration of Sweet Gases 118< p> 8.7 Dehydration of Acid Gases 119< p> 8.8 Conclusions 119< p> < b> 9. Carbon Capture Using Amine-Based Technology 121< br> < /b> < i> Ben Spooner and David Engel< /i> < p> 9.1 Amine Applications 121< p> 9.2 Amine Technology 122< p> 9.3 Reaction Chemistry 124< p> 9.4 Types of Amine 126< p> 9.5 Challenges of Carbon Capture 128< p> 9.6 Conclusion 131< p> < b> 10. Dehydration-through-Compression (DTC): Is It Adequate A Tale of Three Gases 133< br> < /b> < i> Wes H. Wright< /i> < p> 10.1 Background 133< p> 10.2 Water Saturation 138< p> 10.3 Is It Adequate 138< p> 10.4 The Gases 141< p> 10.5 Results 147< p> 10.6 Discussion 151< p> < b> 11. Diaphragm P 211< p> 13.3 Model Parameters 216< p> 13.4 Results 218< p> 13.5 Discussion 221< p> 13.6 Conclusions 223< p> 13.7 Acknowledgment 224< p> < b> 14. Complex Flow Mathematical Model of Gas Pool with Sulfur Deposition 227< br> < /b> < i> W. Zhu, Y. Long, Q. Liu, Y. Ju, and X. Huang< /i> < p> 14.1 Introduction 227< p> 14.2 The Mathematical, John Wiley & Sons

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Carbon Dioxide Sequestration and Related Technologies - Ying Wu
book is out-of-stock
(*)
Ying Wu:
Carbon Dioxide Sequestration and Related Technologies - new book

ISBN: 9781118175545

ID: 9781118175545

InhaltsangabeIntroductionThe Three Sisters - CCS, AGI, and EOR xixYing Wu, John J. Carroll and Zhimin DuSection 1: Data and Correlation1. Prediction of Acid Gas Dew Points in the Presence of Water and Volatile Organic Compounds 3Ray. A. Tomcej1.1 Introduction 31.2 Previous Studies 41.3 Thermodynamic Model 51.4 Calculation Results 61.5 Discussion 102. Phase Behavior of China Reservoir Oil at Different C02 Injected Concentrations 13Fengguang Li, Xin Yang, Changyu Sun, and Guangjin Chen2.1 Introduction 142.2 Preparation of Reservoir Fluid 142.3 PVT Phase Behavior for the C02 Injected Crude Oil 152.4 Viscosity of the C02 Injected Crude Oil 172.5 Interfacial Tension for C02 Injected Crude Oil/Strata Water 192.6 Conclusions 203. Viscosity and Density Measurements for Sour Gas Fluids at High Temperatures and Pressures 23B.R. Giri, P. Biais and R.A. Marriott3.1 Introduction 243.2 Experimental 253.3 Results 313.4 Conclusions 374. Acid Gas Viscosity Modeling with the Expanded Fluid Viscosity Correlation 41H. Motahhari, M.A. Satyro, H.W. Yarranton4.1 Introduction 414.2 Expanded Fluid Viscosity Correlation 424.3 Results and Discussion 474.4 Conclusions 524.5 Acknowledgements 525. Evaluation and Improvement of Sour Property Packages in Unisim Design 55Jianyong Yang, Ensheng Zhao, Laurie Wang, and Sanjoy Saha5.1 Introduction 555.2 Model Description 565.3 Phase Equilibrium Calculation 585.4 Conclusions 625.5 Future Work 626. Compressibility Factor of High C02-Content Natural Gases: Measurement and Correlation 65Xiaoqiang Bian, Zhimin Du, Yong Tang, and Jianfen Du6.1 Introduction 656.2 Experiment 676.3 Methods 686.5 Comparison of the Proposed Method and Other Methods 786.6 Conclusions 836.7 Acknowledgements 846.8 Nomenclature 84Section 2: Process Engineering7. Analysis of Acid Gas Injection Variables 89Edward Wiehert and James van der Lee7.1 Introduction 897.2 Discussion 907.3 Program Design 937.4 Results 947.5 Discussion of Results 967.6 Conclusion 1058. Glycol Dehydration as a Mass Transfer Rate Process 107Nathan A. Hatcher, Jaime L. Nava and Ralph H. Weiland8.1 Phase Equilibrium 1088.2 Process Simulation 1108.3 Dehydration Column Performance 1118.4 Stahl Columns and Stripping Gas 1148.5 Interesting Observations from a Mass Transfer Rate Model 1158.6 Factors That Affect Dehydration of Sweet Gases 1188.7 Dehydration of Acid Gases 1198.8 Conclusions 1199. Carbon Capture Using Amine-Based Technology 121Ben Spooner and David Engel9.1 Amine Applications 1219.2 Amine Technology 1229.3 Reaction Chemistry 1249.4 Types of Amine 1269.5 Challenges of Carbon Capture 1289.6 Conclusion 13110. Dehydration-through-Compression (DTC): Is It Adequate A Tale of Three Gases 133Wes H. Wright10.1 Background 13310.2 Water Saturation 13810.3 Is It Adequate 13810.4 The Gases 14110.5 Results 14710.6 Discussion 15111. Diaphragm P 21113.3 Model Parameters 21613.4 Results 21813.5 Discussion 22113.6 Conclusions 22313.7 Acknowledgment 22414. Complex Flow Mathematical Model of Gas Pool with Sulfur Deposition 227W. Zhu, Y. Long, Q. Liu, Y. Ju, and X. Huang14.1 Introduction 22714.2 The Mathematical Model of Multiphase Complex Flow 22814.3 Mathematical Models of Flow Mechanisms 23214.4 Solution of the Mathematical Model Equations 23814.5 Example 24014.6 Conclusions 24214.7 Acknowledgement 242Section 4: Enhanced Oil Recovery (EOR)15. Enhanced Oil Recovery Project: Dunvegan C Pool 247Darryl Burns15.1 Introduction 24815.2 Pool Data Collection 24915.3 Pool Event Log 25215.4 Reservoir Fluid Characterization 25515.5 Material Balance 26315.6 Geological Model 26415.7 Geological Uncertainty 26915.8 History Match 27215.9 Black Oil to Compositional Model Conversion 28215.10 Recovery Alternatives 29015.11 Economics 30715.12 Economic Uncertainty 31215.13 Discussion and Learning 31215.14 End Note 31716. C02 Flooding as an EOR Method for Low Permeability Reservoirs 319Yongle Hu, Yunpeng Hu, Qin Li, Lei Huang, Mingqiang Hao, and Siyu Yang16.1 Introduction 31916.2 Field Experiment of C02 Flooding in China 32016.3 Mechanism of C02 Flooding Displacement 32116.4 Perspective 32416.5 Conclusion 32617. Pilot Test Research on C02 Drive in Very Low Permeability Oil Field of in Daqing Changyuan 329Weiyao Zhu, Jiecheng Cheng, Xiaohe Huang, Yunqian Long, and Y. Lou17.1 Introduction 32917.2 Laboratory Test Study on C02 Flooding in Oil Reservoirs with Very Low Permeability 33017.3 Field Testing Research 33317.4 Conclusion 34617.5 Acknowledgement 34918. Operation Control of C02-Driving in Field Site. Site Test in Wellblock Shu 101, Yushulin Oil Field, Daqing 351Xinde Wan, Tao Sun, Yingzhi Zhang, Tiejun Yang, and Changhe Mu18.1 Test Area Description 35218.2 Test Effect and Cognition 35318.3 Conclusions 35919. Application of Heteropolysaccharide in Acid Gas Injection 361Jie Zhang, Gang Guo and Shugang Li19.1 Introduction 36119.2 Application of Heteropolysaccharide in C02 Reinjection Miscible Phase Recovery 36319.3 Application of Heteropolysaccharide in H2S Reinjection formation 37019.4 Conclusions 373Section 5: Geology and Geochemistry20. Impact of S02 and NO on Carbonated Rocks Submitted to a Geological Storage of C02: An Experimental Study 377St& #233 phane Renard, J& #233 r& #244 me Sterpenich, Jacques Pironon, Aur& #233 lien Randi, Pierre Chiquet and Marc Lescanne20.1 Introduction 37720.2 Apparatus and Methods 37820.3 Results and Discussion 38120.4 Conclusion 39121. Geochemical Modeling of Huff &apos N&apos Puff Oil Recovery With C02 at the Northwest Mcgregor Oil Field 393Yevhen I. Holubnyak, Blaise A.F. Mibeck, Jordan M. Bremer, Steven A. Smith, James A. Sorensen, Charles D. Gorecki, Edward N. Steadman, and John A. Harju21.1 Introduction 39321.2 Northwest McGregor Location and Geological Setting 39521.3 The Northwest McGregor Field, E. Goetz #1 Well Operational History 39521.4 Reservoir Mineralogy 39721.5 Preinjection and Postinjection Reservoir Fluid Analysis 39821.6 Major Observations and the Anal Section 6: Well Technology23 Well Cement Aging in Various H2S-C02 Flui( is at High Pressure and High Temperature: Experiments and Modelling 423Nicolas Jacquemet, Jacques Pironon, Vincent Lagneau, J& #233 r& #233 mie Saint-Marc23.1 Introduction 42423.2 Experimental equipment 42523.3 Materials, Experimental Conditions and Analysis 42623.4 Results and Discussion 42823.5 Reactive Transport Modelling 43023.6 Conclusion 43224. Casing Selection and Correlation Technology for Ultra-Deep, Ultra- High Pressure, High H2S Gas Wells 437Yongxing Sun, Yuanhua Lin, Taihe Shi, Zhongsheng Wang, Dajiang Zhu, Liping Chen, Sujun Liu, and Dezhi Zeng24.1 Introduction 43824.2 Material Selection Recommended Practice 43824.3 Casing Selection and Correlation Technology 44124.4 Field Applications 44324.4 Conclusions 44524.5 Acknowledgments 44725. Coupled Mathematical Model of Gas Migration in Cemented Annulus with Mud Column in Acid Gas Well 449Hongjun Zhu, Yuanhua Lin, Yongxing Sun, Dezhi Zeng, Zhi Zhang, and Taihe Shi25.1 Introduction 44925.2 Coupled Mathematical Model 45025.3 Illustration 45825.4 Conclusions 45925.5 Nomenclature 46025.6 Acknowledgment 461Section 7: Corrosion26. Study on Corrosion Resistance of L245/825 Lined Steel Pipe Welding Gap in H2S+C02 Environment 465Dezhi Zeng, Yuanhua Lin, Liming Huang, Daijiang Zhu, Tan Gu, Taihe Shi, and Yongxing Sun Carbon Dioxide Sequestration and Related Technologies: InhaltsangabeIntroductionThe Three Sisters - CCS, AGI, and EOR xixYing Wu, John J. Carroll and Zhimin DuSection 1: Data and Correlation1. Prediction of Acid Gas Dew Points in the Presence of Water and Volatile Organic Compounds 3Ray. A. Tomcej1.1 Introduction 31.2 Previous Studies 41.3 Thermodynamic Model 51.4 Calculation Results 61.5 Discussion 102. Phase Behavior of China Reservoir Oil at Different C02 Injected Concentrations 13Fengguang Li, Xin Yang, Changyu Sun, and Guangjin Chen2.1 Introduction 142.2 Preparation of Reservoir Fluid 142.3 PVT Phase Behavior for the C02 Injected Crude Oil 152.4 Viscosity of the C02 Injected Crude Oil 172.5 Interfacial Tension for C02 Injected Crude Oil/Strata Water 192.6 Conclusions 203. Viscosity and Density Measurements for Sour Gas Fluids at High Temperatures and Pressures 23B.R. Giri, P. Biais and R.A. Marriott3.1 Introduction 243.2 Experimental 253.3 Results 313.4 Conclusions 374. Acid Gas Viscosity Modeling with the Expanded Fluid Viscosity Correlation 41H. Motahhari, M.A. Satyro, H.W. Yarranton4.1 Introduction 414.2 Expanded Fluid Viscosity Correlation 424.3 Results and Discussion 474.4 Conclusions 524.5 Acknowledgements 525. Evaluation and Improvement of Sour Property Packages in Unisim Design 55Jianyong Yang, Ensheng Zhao, Laurie Wang, and Sanjoy Saha5.1 Introduction 555.2 Model Description 565.3 Phase Equilibrium Calculation 585.4 Conclusions 625.5 Future Work 626. Compressibility Factor of High C02-Content Natural Gases: Measurement and Correlation 65Xiaoqiang Bian, Zhimin Du, Yong Tang, and Jianfen Du6.1 Introduction 656.2 Experiment 676.3 Methods 686.5 Comparison of the Proposed Method and Other Methods 786.6 Conclusions 836.7 Acknowledgements 846.8 Nomenclature 84Section 2: Process Engineering7. Analysis of Acid Gas Injection Variables 89Edward Wiehert and James van der Lee7.1 Introduction 897.2 Discussion 907.3 Program Design 937.4 Results 947.5 Discussion of Results 967.6 Conclusion 1058. Glycol Dehydration as a Mass Transfer Rate Process 107Nathan A. Hatcher, Jaime L. Nava and Ralph H. Weiland8.1 Phase Equilibrium 1088.2 Process Simulation 1108.3 Dehydration Column Performance 1118.4 Stahl Columns and Stripping Gas 1148.5 Interesting Observations from a Mass Transfer Rate Model 1158.6 Factors That Affect Dehydration of Sweet Gases 1188.7 Dehydration of Acid Gases 1198.8 Conclusions 1199. Carbon Capture Using Amine-Based Technology 121Ben Spooner and David Engel9.1 Amine Applications 1219.2 Amine Technology 1229.3 Reaction Chemistry 1249.4 Types of Amine 1269.5 Challenges of Carbon Capture 1289.6 Conclusion 13110. Dehydration-through-Compression (DTC): Is It Adequate A Tale of Three Gases 133Wes H. Wright10.1 Background 13310.2 Water Saturation 13810.3 Is It Adequate 13810.4 The Gases 14110.5 Results 14710.6 Discussion 15111. Diaphragm P 21113.3 Model Parameters 21613.4 Results 21813.5 Discussion 22113.6 Conclusions 22313.7 Acknowledgment 22414. Complex Flow Mathematical Model of Gas Pool with Sulfur Deposition 227W. Zhu, Y. Long, Q. Liu, Y. Ju, and X. Huang14.1 Introduction 22714.2 The Mathematical Model of Multiphase Complex Flow 22814.3 Mathematical Models of Flow Mechanisms 23214.4 Solution of the Mathematical Model Equations 23814.5 Example 24014.6 Conclusions 24214.7 Acknowledgement 242Section 4: Enhanced Oil Recovery (EOR)15. Enhanced Oil Recovery Project: Dunvegan C Pool 247Darryl Burns15.1 Introduction 24815.2 Pool Data Collection 24915.3 Pool Event Log 25215.4 Reservoir Fluid Characterization 25515.5 Material Balance 26315.6 Geological Model 26415.7 Geological Uncertainty 26915.8 History Match 27215.9 Black Oil to Compositional Model Conversion 28215.10 Recovery Alternatives 29015.11 Economics 30715.12 Economic Uncertainty 31215.13 Discussion and Learning 31215.14 End Note 31716. C02 Flooding as an EOR Method for Low Permeability Reservoirs 319Yongle Hu, Yunpeng Hu, Qin Li, Lei Huang, Mingqiang Hao, and Siyu Yang16.1 Introduction 31916.2 Field Experiment of C02 Flooding in China 32016.3 Mechanism of C02 Flooding Displacement 32116.4 Perspective 32416.5 Conclusion 32617. Pilot Test Research on C02 Drive in Very Low Permeability Oil Field of in Daqing Changyuan 329Weiyao Zhu, Jiecheng Cheng, Xiaohe Huang, Yunqian Long, and Y. Lou17.1 Introduction 32917.2 Laboratory Test Study on C02 Flooding in Oil Reservoirs with Very Low Permeability 33017.3 Field Testing Research 33317.4 Conclusion 34617.5 Acknowledgement 34918. Operation Control of C02-Driving in Field Site. Site Test in Wellblock Shu 101, Yushulin Oil Field, Daqing 351Xinde Wan, Tao Sun, Yingzhi Zhang, Tiejun Yang, and Changhe Mu18.1 Test Area Description 35218.2 Test Effect and Cognition 35318.3 Conclusions 35919. Application of Heteropolysaccharide in Acid Gas Injection 361Jie Zhang, Gang Guo and Shugang Li19.1 Introduction 36119.2 Application of Heteropolysaccharide in C02 Reinjection Miscible Phase Recovery 36319.3 Application of Heteropolysaccharide in H2S Reinjection formation 37019.4 Conclusions 373Section 5: Geology and Geochemistry20. Impact of S02 and NO on Carbonated Rocks Submitted to a Geological Storage of C02: An Experimental Study 377St& #233 phane Renard, J& #233 r& #244 me Sterpenich, Jacques Pironon, Aur& #233 lien Randi, Pierre Chiquet and Marc Lescanne20.1 Introduction 37720.2 Apparatus and Methods 37820.3 Results and Discussion 38120.4 Conclusion 39121. Geochemical Modeling of Huff &apos N&apos Puff Oil Recovery With C02 at the Northwest Mcgregor Oil Field 393Yevhen I. Holubnyak, Blaise A.F. Mibeck, Jordan M. Bremer, Steven A. Smith, James A. Sorensen, Charles D. Gorecki, Edward N. Steadman, and John A. Harju21.1 Introduction 39321.2 Northwest McGregor Location and Geological Setting 39521.3 The Northwest McGregor Field, E. Goetz #1 Well Operational History 39521.4 Reservoir Mineralogy 39721.5 Preinjection and Postinjection Reservoir Fluid Analysis 39821.6 Major Observations and the Anal Section 6: Well Technology23 Well Cement Aging in Various H2S-C02 Flui( is at High Pressure and High Temperature: Experiments and Modelling 423Nicolas Jacquemet, Jacques Pironon, Vincent Lagneau, J& #233 r& #233 mie Saint-Marc23.1 Introduction 42423.2 Experimental equipment 42523.3 Materials, Experimental Conditions and Analysis 42623.4 Results and Discussion 42823.5 Reactive Transport Modelling 43023.6 Conclusion 43224. Casing Selection and Correlation Technology for Ultra-Deep, Ultra- High Pressure, High H2S Gas Wells 437Yongxing Sun, Yuanhua Lin, Taihe Shi, Zhongsheng Wang, Dajiang Zhu, Liping Chen, Sujun Liu, and Dezhi Zeng24.1 Introduction 43824.2 Material Selection Recommended Practice 43824.3 Casing Selection and Correlation Technology 44124.4 Field Applications 44324.4 Conclusions 44524.5 Acknowledgments 44725. Coupled Mathematical Model of Gas Migration in Cemented Annulus with Mud Column in Acid Gas Well 449Hongjun Zhu, Yuanhua Lin, Yongxing Sun, Dezhi Zeng, Zhi Zhang, and, John Wiley & Sons

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InhaltsangabeIntroductionThe Three Sisters - CCS, AGI, and EOR xixYing Wu, John J. Carroll and Zhimin DuSection 1: Data and Correlation1. Prediction of Acid Gas Dew Points in the Presence of Water and Volatile Organic Compounds 3Ray. A. Tomcej1.1 Introduction 31.2 Previous Studies 41.3 Thermodynamic Model 51.4 Calculation Results 61.5 Discussion 102. Phase Behavior of China Reservoir Oil at Different C02 Injected Concentrations 13Fengguang Li, Xin Yang, Changyu Sun, and Guangjin Chen2.1 Introduction 142.2 Preparation of Reservoir Fluid 142.3 PVT Phase Behavior for the C02 Injected Crude Oil 152.4 Viscosity of the C02 Injected Crude Oil 172.5 Interfacial Tension for C02 Injected Crude Oil/Strata Water 192.6 Conclusions 203. Viscosity and Density Measurements for Sour Gas Fluids at High Temperatures and Pressures 23B.R. Giri, P. Biais and R.A. Marriott3.1 Introduction 243.2 Experimental 253.3 Results 313.4 Conclusions 374. Acid Gas Viscosity Modeling with the Expanded Fluid Viscosity Correlation 41H. Motahhari, M.A. Satyro, H.W. Yarranton4.1 Introduction 414.2 Expanded Fluid Viscosity Correlation 424.3 Results and Discussion 474.4 Conclusions 524.5 Acknowledgements 525. Evaluation and Improvement of Sour Property Packages in Unisim Design 55Jianyong Yang, Ensheng Zhao, Laurie Wang, and Sanjoy Saha5.1 Introduction 555.2 Model Description 565.3 Phase Equilibrium Calculation 585.4 Conclusions 625.5 Future Work 626. Compressibility Factor of High C02-Content Natural Gases: Measurement and Correlation 65Xiaoqiang Bian, Zhimin Du, Yong Tang, and Jianfen Du6.1 Introduction 656.2 Experiment 676.3 Methods 686.5 Comparison of the Proposed Method and Other Methods 786.6 Conclusions 836.7 Acknowledgements 846.8 Nomenclature 84Section 2: Process Engineering7. Analysis of Acid Gas Injection Variables 89Edward Wiehert and James van der Lee7.1 Introduction 897.2 Discussion 907.3 Program Design 937.4 Results 947.5 Discussion of Results 967.6 Conclusion 1058. Glycol Dehydration as a Mass Transfer Rate Process 107Nathan A. Hatcher, Jaime L. Nava and Ralph H. Weiland8.1 Phase Equilibrium 1088.2 Process Simulation 1108.3 Dehydration Column Performance 1118.4 Stahl Columns and Stripping Gas 1148.5 Interesting Observations from a Mass Transfer Rate Model 1158.6 Factors That Affect Dehydration of Sweet Gases 1188.7 Dehydration of Acid Gases 1198.8 Conclusions 1199. Carbon Capture Using Amine-Based Technology 121Ben Spooner and David Engel9.1 Amine Applications 1219.2 Amine Technology 1229.3 Reaction Chemistry 1249.4 Types of Amine 1269.5 Challenges of Carbon Capture 1289.6 Conclusion 13110. Dehydration-through-Compression (DTC): Is It Adequate A Tale of Three Gases 133Wes H. Wright10.1 Background 13310.2 Water Saturation 13810.3 Is It Adequate 13810.4 The Gases 14110.5 Results 14710.6 Discussion 15111. Diaphragm P 21113.3 Model Parameters 21613.4 Results 21813.5 Discussion 22113.6 Conclusions 22313.7 Acknowledgment 22414. Complex Flow Mathematical Model of Gas Pool with Sulfur Deposition 227W. Zhu, Y. Long, Q. Liu, Y. Ju, and X. Huang14.1 Introduction 22714.2 The Mathematical Model of Multiphase Complex Flow 22814.3 Mathematical Models of Flow Mechanisms 23214.4 Solution of the Mathematical Model Equations 23814.5 Example 24014.6 Conclusions 24214.7 Acknowledgement 242Section 4: Enhanced Oil Recovery (EOR)15. Enhanced Oil Recovery Project: Dunvegan C Pool 247Darryl Burns15.1 Introduction 24815.2 Pool Data Collection 24915.3 Pool Event Log 25215.4 Reservoir Fluid Characterization 25515.5 Material Balance 26315.6 Geological Model 26415.7 Geological Uncertainty 26915.8 History Match 27215.9 Black Oil to Compositional Model Conversion 28215.10 Recovery Alternatives 29015.11 Economics 30715.12 Economic Uncertainty 31215.13 Discussion and Learning 31215.14 End Note 31716. C02 Flooding as an EOR Method for Low Permeability Reservoirs 319Yongle Hu, Yunpeng Hu, Qin Li, Lei Huang, Mingqiang Hao, and Siyu Yang16.1 Introduction 31916.2 Field Experiment of C02 Flooding in China 32016.3 Mechanism of C02 Flooding Displacement 32116.4 Perspective 32416.5 Conclusion 32617. Pilot Test Research on C02 Drive in Very Low Permeability Oil Field of in Daqing Changyuan 329Weiyao Zhu, Jiecheng Cheng, Xiaohe Huang, Yunqian Long, and Y. Lou17.1 Introduction 32917.2 Laboratory Test Study on C02 Flooding in Oil Reservoirs with Very Low Permeability 33017.3 Field Testing Research 33317.4 Conclusion 34617.5 Acknowledgement 34918. Operation Control of C02-Driving in Field Site. Site Test in Wellblock Shu 101, Yushulin Oil Field, Daqing 351Xinde Wan, Tao Sun, Yingzhi Zhang, Tiejun Yang, and Changhe Mu18.1 Test Area Description 35218.2 Test Effect and Cognition 35318.3 Conclusions 35919. Application of Heteropolysaccharide in Acid Gas Injection 361Jie Zhang, Gang Guo and Shugang Li19.1 Introduction 36119.2 Application of Heteropolysaccharide in C02 Reinjection Miscible Phase Recovery 36319.3 Application of Heteropolysaccharide in H2S Reinjection formation 37019.4 Conclusions 373Section 5: Geology and Geochemistry20. Impact of S02 and NO on Carbonated Rocks Submitted to a Geological Storage of C02: An Experimental Study 377Sté phane Renard, Jé rô me Sterpenich, Jacques Pironon, Auré lien Randi, Pierre Chiquet and Marc Lescanne20.1 Introduction 37720.2 Apparatus and Methods 37820.3 Results and Discussion 38120.4 Conclusion 39121. Geochemical Modeling of Huff &apos N&apos Puff Oil Recovery With C02 at the Northwest Mcgregor Oil Field 393Yevhen I. Holubnyak, Blaise A.F. Mibeck, Jordan M. Bremer, Steven A. Smith, James A. Sorensen, Charles D. Gorecki, Edward N. Steadman, and John A. Harju21.1 Introduction 39321.2 Northwest McGregor Location and Geological Setting 39521.3 The Northwest McGregor Field, E. Goetz #1 Well Operational History 39521.4 Reservoir Mineralogy 39721.5 Preinjection and Postinjection Reservoir Fluid Analysis 39821.6 Major Observations and the Anal Section 6: Well Technology23 Well Cement Aging in Various H2S-C02 Flui( is at High Pressure and High Temperature: Experiments and Modelling 423Nicolas Jacquemet, Jacques Pironon, Vincent Lagneau, Jé ré mie Saint-Marc23.1 Introduction 42423.2 Experimental equipment 42523.3 Materials, Experimental Conditions and Analysis 42623.4 Results and Discussion 42823.5 Reactive Transport Modelling 43023.6 Conclusion 43224. Casing Selection and Correlation Technology for Ultra-Deep, Ultra- High Pressure, High H2S Gas Wells 437Yongxing Sun, Yuanhua Lin, Taihe Shi, Zhongsheng Wang, Dajiang Zhu, Liping Chen, Sujun Liu, and Dezhi Zeng24.1 Introduction 43824.2 Material Selection Recommended Practice 43824.3 Casing Selection and Correlation Technology 44124.4 Field Applications 44324.4 Conclusions 44524.5 Acknowledgments 44725. Coupled Mathematical Model of Gas Migration in Cemented Annulus with Mud Column in Acid Gas Well 449Hongjun Zhu, Yuanhua Lin, Yongxing Sun, Dezhi Zeng, Zhi Zhang, and Taihe Shi25.1 Introduction 44925.2 Coupled Mathematical Model 45025.3 Illustration 45825.4 Conclusions 45925.5 Nomenclature 46025.6 Acknowledgment 461Section 7: Corrosion26. Study on Corrosion Resistance of L245/825 Lined Steel Pipe Welding Gap in H2S+C02 Environment 465Dezhi Zeng, Yuanhua Lin, Liming Huang, Daijiang Zhu, Tan Gu, Taihe Shi, and Yongxing Sun Carbon Dioxide Sequestration and Related Technologies: InhaltsangabeIntroductionThe Three Sisters - CCS, AGI, and EOR xixYing Wu, John J. Carroll and Zhimin DuSection 1: Data and Correlation1. Prediction of Acid Gas Dew Points in the Presence of Water and Volatile Organic Compounds 3Ray. A. Tomcej1.1 Introduction 31.2 Previous Studies 41.3 Thermodynamic Model 51.4 Calculation Results 61.5 Discussion 102. Phase Behavior of China Reservoir Oil at Different C02 Injected Concentrations 13Fengguang Li, Xin Yang, Changyu Sun, and Guangjin Chen2.1 Introduction 142.2 Preparation of Reservoir Fluid 142.3 PVT Phase Behavior for the C02 Injected Crude Oil 152.4 Viscosity of the C02 Injected Crude Oil 172.5 Interfacial Tension for C02 Injected Crude Oil/Strata Water 192.6 Conclusions 203. Viscosity and Density Measurements for Sour Gas Fluids at High Temperatures and Pressures 23B.R. Giri, P. Biais and R.A. Marriott3.1 Introduction 243.2 Experimental 253.3 Results 313.4 Conclusions 374. Acid Gas Viscosity Modeling with the Expanded Fluid Viscosity Correlation 41H. Motahhari, M.A. Satyro, H.W. Yarranton4.1 Introduction 414.2 Expanded Fluid Viscosity Correlation 424.3 Results and Discussion 474.4 Conclusions 524.5 Acknowledgements 525. Evaluation and Improvement of Sour Property Packages in Unisim Design 55Jianyong Yang, Ensheng Zhao, Laurie Wang, and Sanjoy Saha5.1 Introduction 555.2 Model Description 565.3 Phase Equilibrium Calculation 585.4 Conclusions 625.5 Future Work 626. Compressibility Factor of High C02-Content Natural Gases: Measurement and Correlation 65Xiaoqiang Bian, Zhimin Du, Yong Tang, and Jianfen Du6.1 Introduction 656.2 Experiment 676.3 Methods 686.5 Comparison of the Proposed Method and Other Methods 786.6 Conclusions 836.7 Acknowledgements 846.8 Nomenclature 84Section 2: Process Engineering7. Analysis of Acid Gas Injection Variables 89Edward Wiehert and James van der Lee7.1 Introduction 897.2 Discussion 907.3 Program Design 937.4 Results 947.5 Discussion of Results 967.6 Conclusion 1058. Glycol Dehydration as a Mass Transfer Rate Process 107Nathan A. Hatcher, Jaime L. Nava and Ralph H. Weiland8.1 Phase Equilibrium 1088.2 Process Simulation 1108.3 Dehydration Column Performance 1118.4 Stahl Columns and Stripping Gas 1148.5 Interesting Observations from a Mass Transfer Rate Model 1158.6 Factors That Affect Dehydration of Sweet Gases 1188.7 Dehydration of Acid Gases 1198.8 Conclusions 1199. Carbon Capture Using Amine-Based Technology 121Ben Spooner and David Engel9.1 Amine Applications 1219.2 Amine Technology 1229.3 Reaction Chemistry 1249.4 Types of Amine 1269.5 Challenges of Carbon Capture 1289.6 Conclusion 13110. Dehydration-through-Compression (DTC): Is It Adequate A Tale of Three Gases 133Wes H. Wright10.1 Background 13310.2 Water Saturation 13810.3 Is It Adequate 13810.4 The Gases 14110.5 Results 14710.6 Discussion 15111. Diaphragm P 21113.3 Model Parameters 21613.4 Results 21813.5 Discussion 22113.6 Conclusions 22313.7 Acknowledgment 22414. Complex Flow Mathematical Model of Gas Pool with Sulfur Deposition 227W. Zhu, Y. Long, Q. Liu, Y. Ju, and X. Huang14.1 Introduction 22714.2 The Mathematical Model of Multiphase Complex Flow 22814.3 Mathematical Models of Flow Mechanisms 23214.4 Solution of the Mathematical Model Equations 23814.5 Example 24014.6 Conclusions 24214.7 Acknowledgement 242Section 4: Enhanced Oil Recovery (EOR)15. Enhanced Oil Recovery Project: Dunvegan C Pool 247Darryl Burns15.1 Introduction 24815.2 Pool Data Collection 24915.3 Pool Event Log 25215.4 Reservoir Fluid Characterization 25515.5 Material Balance 26315.6 Geological Model 26415.7 Geological Uncertainty 26915.8 History Match 27215.9 Black Oil to Compositional Model Conversion 28215.10 Recovery Alternatives 29015.11 Economics 30715.12 Economic Uncertainty 31215.13 Discussion and Learning 31215.14 End Note 31716. C02 Flooding as an EOR Method for Low Permeability Reservoirs 319Yongle Hu, Yunpeng Hu, Qin Li, Lei Huang, Mingqiang Hao, and Siyu Yang16.1 Introduction 31916.2 Field Experiment of C02 Flooding in China 32016.3 Mechanism of C02 Flooding Displacement 32116.4 Perspective 32416.5 Conclusion 32617. Pilot Test Research on C02 Drive in Very Low Permeability Oil Field of in Daqing Changyuan 329Weiyao Zhu, Jiecheng Cheng, Xiaohe Huang, Yunqian Long, and Y. Lou17.1 Introduction 32917.2 Laboratory Test Study on C02 Flooding in Oil Reservoirs with Very Low Permeability 33017.3 Field Testing Research 33317.4 Conclusion 34617.5 Acknowledgement 34918. Operation Control of C02-Driving in Field Site. Site Test in Wellblock Shu 101, Yushulin Oil Field, Daqing 351Xinde Wan, Tao Sun, Yingzhi Zhang, Tiejun Yang, and Changhe Mu18.1 Test Area Description 35218.2 Test Effect and Cognition 35318.3 Conclusions 35919. Application of Heteropolysaccharide in Acid Gas Injection 361Jie Zhang, Gang Guo and Shugang Li19.1 Introduction 36119.2 Application of Heteropolysaccharide in C02 Reinjection Miscible Phase Recovery 36319.3 Application of Heteropolysaccharide in H2S Reinjection formation 37019.4 Conclusions 373Section 5: Geology and Geochemistry20. Impact of S02 and NO on Carbonated Rocks Submitted to a Geological Storage of C02: An Experimental Study 377Sté phane Renard, Jé rô me Sterpenich, Jacques Pironon, Auré lien Randi, Pierre Chiquet and Marc Lescanne20.1 Introduction 37720.2 Apparatus and Methods 37820.3 Results and Discussion 38120.4 Conclusion 39121. Geochemical Modeling of Huff &apos N&apos Puff Oil Recovery With C02 at the Northwest Mcgregor Oil Field 393Yevhen I. Holubnyak, Blaise A.F. Mibeck, Jordan M. Bremer, Steven A. Smith, James A. Sorensen, Charles D. Gorecki, Edward N. Steadman, and John A. Harju21.1 Introduction 39321.2 Northwest McGregor Location and Geological Setting 39521.3 The Northwest McGregor Field, E. Goetz #1 Well Operational History 39521.4 Reservoir Mineralogy 39721.5 Preinjection and Postinjection Reservoir Fluid Analysis 39821.6 Major Observations and the Anal Section 6: Well Technology23 Well Cement Aging in Various H2S-C02 Flui( is at High Pressure and High Temperature: Experiments and Modelling 423Nicolas Jacquemet, Jacques Pironon, Vincent Lagneau, Jé ré mie Saint-Marc23.1 Introduction 42423.2 Experimental equipment 42523.3 Materials, Experimental Conditions and Analysis 42623.4 Results and Discussion 42823.5 Reactive Transport Modelling 43023.6 Conclusion 43224. Casing Selection and Correlation Technology for Ultra-Deep, Ultra- High Pressure, High H2S Gas Wells 437Yongxing Sun, Yuanhua Lin, Taihe Shi, Zhongsheng Wang, Dajiang Zhu, Liping Chen, Sujun Liu, and Dezhi Zeng24.1 Introduction 43824.2 Material Selection Recommended Practice 43824.3 Casing Selection and Correlation Technology 44124.4 Field Applications 44324.4 Conclusions 44524.5 Acknowledgments 44725. Coupled Mathematical Model of Gas Migration in Cemented Annulus with Mud Column in Acid Gas Well 449Hongjun Zhu, Yuanhua Lin, Yongxing Sun, Dezhi Zeng, Zhi Zhang, and Taihe Shi25.1 Introduction 44925.2 Coupled Math, John Wiley & Sons

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Carbon Dioxide Sequestration and Related Technologies - Ying Wu;  John J. Carroll;  Zhimin Du
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InhaltsangabeIntroductionThe Three Sisters - CCS, AGI, and EOR xix, John Wiley & Sons

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Details of the book
Carbon Dioxide Sequestration and Related Technologies
Author:

Wu, Ying; Carroll, John J.; Du, Zhimin

Title:

Carbon Dioxide Sequestration and Related Technologies

ISBN:

Details of the book - Carbon Dioxide Sequestration and Related Technologies


EAN (ISBN-13): 9781118175545
ISBN (ISBN-10): 1118175549
Publishing year: 2011
Publisher: Wiley, J
508 Pages
Language: eng/Englisch

Book in our database since 14.12.2008 14:36:41
Book found last time on 26.03.2017 16:04:23
ISBN/EAN: 9781118175545

ISBN - alternate spelling:
1-118-17554-9, 978-1-118-17554-5


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