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This is the sixth volume in a series of books on natural gas engineering, focusing carbon dioxide (CO2) capture and acid gas injection. This volume includes information for both upstream and downstream operations, including chapters on well modeling, carbon capture, chemical and thermodynamic models, and much more. Written by some of the most well-known and respected chemical and process engineers working with natural gas today, the chapters in this important volume represent the most cutting-edge and state-of-the-art processes and operations being used in the field. Not available anywhere…mehr
This is the sixth volume in a series of books on natural gas engineering, focusing carbon dioxide (CO2) capture and acid gas injection. This volume includes information for both upstream and downstream operations, including chapters on well modeling, carbon capture, chemical and thermodynamic models, and much more. Written by some of the most well-known and respected chemical and process engineers working with natural gas today, the chapters in this important volume represent the most cutting-edge and state-of-the-art processes and operations being used in the field. Not available anywhere else, this volume is a must-have for any chemical engineer, chemist, or process engineer working with natural gas. There are updates of new technologies in other related areas of natural gas, in addition to the CO2 capture and acid gas injection, including testing, reservoir simulations, and natural gas hydrate formations. Advances in Natural Gas Engineering is an ongoing series of books meant to form the basis for the working library of any engineer working in natural gas today. Every volume is a must-have for any engineer or library.
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Autorenporträt
Ying (Alice) Wu is currently the President of Sphere Technology Connection Ltd. (STC) in Calgary, Canada. From 1983 to 1999 she was an Assistant Professor and Researcher at Southwest Petroleum Institute (now Southwest Petroleum University, SWPU) in Sichuan, China. She received her MSc in Petroleum Engineering from the SWPU and her BSc in Petroleum Engineering from Daqing Petroleum University in Heilongjiang, China. John J. Carroll, PhD, PEng is the Director, Geostorage Process Engineering for Gas Liquids Engineering, Ltd. in Calgary, Canada. Dr. Carroll holds bachelor and doctoral degrees in chemical engineering from the University of Alberta, Edmonton, Canada, and is a registered professional engineer in the provinces of Alberta and New Brunswick in Canada.?His fist book, Natural Gas Hydrates: A Guide for Engineers, is now in its second edition, and he is the author or co-author of 50 technical publications and about 40 technical presentations.
Inhaltsangabe
Preface xiii 1 Enthalpies of Carbon Dioxide-Methane and Carbon Dioxide-Nitrogen Mixtures: Comparison with Thermodynamic Models 1 Erin L. Roberts and John J. Carroll 1.1 Introduction 1 1.2 Enthalpy 2 1.3 Literature Review 2 1.3.1 Carbon Dioxide-Methane 4 1.3.2 Carbon Dioxide-Nitrogen 4 1.4 Calculations 5 1.4.1 Benedict-Webb-Rubin 6 1.4.2 Lee-Kesler 12 1.4.3 Soave-Redlich-Kwong 17 1.4.4 Peng-Robinson 23 1.4.5 AQUAlibrium 28 1.5 Discussion 33 1.6 Conclusion 36 References 37 2 Enthalpies of Hydrogen Sulfide-Methane Mixture: Comparison with Thermodynamic Models 39 Erin L. Roberts and John J. Carroll 2.1 Introduction 39 2.2 Enthalpy 40 2.3 Literature Review 40 2.4 Calculations 41 2.4.1 Lee-Kesler 41 2.4.2 Benedict-Webb-Rubin 43 2.4.3 Soave-Redlich-Kwong 43 2.4.4 Redlich-Kwong 47 2.4.5 Peng-Robinson 47 2.4.6 AQUAlibrium 50 2.5 Discussion 50 2.6 Conclusion 52 References 54 3 Phase Behavior and Reaction Thermodynamics Involving Dense-Phase CO2 Impurities 55 J.A. Commodore, C.E. Deering and R.A. Marriott 3.1 Introduction 55 3.2 Experimental 57 3.3 Results and Discussion 58 3.3.1 Phase Behavior Studies of SO2 Dissolved in Dense CO2 Fluid 58 3.3.2 The Densimetric Properties of CS2 and CO2 Mixtures 60 References 61 4 Sulfur Recovery in High Density CO2 Fluid 63 S. Lee and R.A. Marriott 4.1 Introduction 64 4.2 Literature Review 64 4.3 Methodology 65 4.4 Results and Discussion 66 4.5 Conclusion and Future Directions 67 References 68 5 Carbon Capture Performance of Seven Novel Immidazolium and Pyridinium Based Ionic Liquids 71 Mohamed Zoubeik, Mohanned Mohamedali and Amr Henni 5.1 Introduction 71 5.2 Experimental Work 73 5.2.1 Materials 73 5.2.2 Density Measurement 73 5.2.3 Solubility Measurement 73 5.3 Modeling 76 5.3.1 Calculation of Henry's Law Constants 76 5.3.2 Critical Properties Calculations 76 5.3.3 Peng Robinson EoS 76 5.4 Results and Discussion 77 5.4.1 Density 77 5.4.2 Critical Properties 77 5.4.3 CO2 Solubility 78 5.4.4 The Effect of Changing the Cation 81 5.4.5 The Effect of Changing the Anion 84 5.4.6 Henry's Law Constant, Enthalpy and Entropy Calculations 85 5.4.7 Thermodynamic Modeling of CO2 Solubility 86 5.5 Conclusion 87 Acknowledgements 88 References 88 6 Vitrisol a 100% Selective Process for H2S Removal in the Presence of CO2 91 W.N. Wermink, N. Ramachandran, and G.F. Versteeg 6.1 Introduction 92 6.2 Case Definition 94 6.3 "Amine-Treated" Cases by PPS 95 6.3.1 Introduction to PPS 95 6.3.2 Process Description 96 6.3.3 PFD 97 6.3.4 Results 97 6.3.4.1 Case 1 97 6.3.4.2 Case 2 97 6.4 Vitrisol ò nProcess Extended with Regeneration of Active Component 99 6.4.1 Technology Description 99 6.4.2 Parameters Determining the Process Boundary Conditions 99 6.4.3 Absorption Section 101 6.4.4 Regeneration Section 102 6.4.5 Sulphur Recovery Section 104 6.4.6 CO2-Absorber 105 6.4.7 PFD 105 6.5 Results 105 6.6 Discussion 110 6.6.1 Comparison of Amine Treating Solutions to Vitrisol ò n110 6.6.2 Enhanced H2S Removal of Barnett Shale Gas (case 2) 112viii Contents 6.7 Conclusions 113 6.8 Notation 115 References 115 Appendix 6-A: H&M Balance of Case 1 (British Columbia shale) of the Amine Process 117 Appendix 6-B H&M Balance of Case 2a (Barnett shale) of the Amine Process with Stripper Promoter 119 Appendix 6-C H&M Balance of Case 3 (Barnett shale) of the Amine Process (MEA) 121 Appendix 6-D: H&M Balance of Case 1 (British Columbia shale) of the Vitrisol nprocess 123 Appendix 6-E H&M Balance of Case 2 (Barnett shale) of the Vitrisol nProcess 125 7 New Amine Based Solvents for Acid Gas Removal 127 Yohann Coulier, Elise El Ahmar, Jean-Yves Coxam, Elise Provost, Didier Dalmazzone, Patrice Paricaud, Christophe Coquelet and Karine Ballerat-Busserolles 7.1 Introduction 128 7.2 Chemicals and Materials 131 7.3 Liquid-Liquid Equilibria 131 7.3.1 LLE in {methylpiperidines - H2O} and {methylpiperidines - H2O - CO2} 131 7.3.2 Liquid-Liquid Equilibria of Ternary Systems {Amine - H2O - Glycol} 135 7.3.3 Liquid-Liquid Equilibria of the Quaternary Systems {CO2 - NMPD - TEG - H2O} 136 7.4 Densities and Heat Capacities of Ternary Systems {NMPD - H2O - Glycol} 137 7.4.1 Densities 137 7.4.2 Specific Heat Capacities 137 7.5 Vapor-Liquid Equilibria of Ternary Systems {NMPD - TEG - H2O - CO2} 139 7.6 Enthalpies of Solution 140 7.7 Discussion and Conclusion 143 Acknowledgments 143 References 144Contents ix 8 Improved Solvents for CO2 Capture by Molecular Simulation Methodology 147 William R. Smith 8.1 Introduction 147 8.2 Physical and Chemical Models 149 8.3 Molecular-Level Models and Algorithms for Thermodynamic Property Predictions 150 8.4 Molecular-Level Models and Methodology for MEA-H2O-CO2 153 8.4.1 Extensions to Other Alkanolamine Solvents and Their Mixtures 155 Acknowledgements 157 References 157 9 Strategies for Minimizing Hydrocarbon Contamination in Amine Acid Gas for Reinjection 161 Mike Sheilan, Ben Spooner and David Engel 9.1 Introduction 162 9.2 Amine Sweetening Process 162 9.3 Hydrocarbons in Amine 164 9.4 Effect of Hydrocarbons on the Acid Gas Reinjection System 166 9.5 Effect of Hydrocarbons on the Amine Plant 167 9.6 Minimizing Hydrocarbon Content in Amine Acid Gas 171 9.6.1 Option 1. Optimization of the Amine Plant Operation 171 9.6.2 Option 2. Amine Flash Tanks 176 9.6.3 Option 3. Rich Amine Liquid Coalescers 178 9.6.4 Option 4. Use of Skimming Devices 180 9.6.5 Option 5. Technological Solutions 182 References 183 10 Modeling of Transient Pressure Response for CO2 Flooding Process by Incorporating Convection and Diffusion Driven Mass Transfer 185 Jianli Li and Gang Zhao 10.1 Introduction 186 10.2 Model Development 187 10.2.1 Pressure Diffusion 187 10.2.2 Mass Transfer 188 10.2.3 Solutions 190x Contents 10.3 Results and Discussion 191 10.3.1 Flow Regimes 191 10.3.2 Effect of Mass Transfer 192 10.3.3 Sensitivity Analysis 195 10.3.3.1 CO2 Bank 195 10.3.3.2 Reservoir Outer Boundary 196 10.4 Conclusions 196 Acknowledgments 197 References 197 11 Well Modeling Aspects of CO2 Sequestration 199 Liaqat Ali and Russell E. Bentley 11.1 Introduction 199 11.2 Delivery Conditions 200 11.3 Reservoir and Completion Data 201 11.4 Inflow Performance Relationship (IPR) and Injectivity Index 201 11.5 Equation of State (EOS) 202 11.6 Vertical Flow Performance (VFP) Curves 205 11.7 Impact of the Well Deviation on CO2 Injection 208 11.8 Implication of Bottom Hole Temperature (BHT) on Reservoir 209 11.9 Impact of CO2 Phase Change 213 11.10 Injection Rates, Facility Design Constraints and Number of Wells Required 214 11.11 Wellhead Temperature Effect on VFP Curves 214 11.12 Effect of Impurities in CO2 on VFP Curves 216 11.13 Concluding Remarks 217 Conversion Factors 218 References 218 12 Effects of Acid Gas Reinjection on Enhanced Natural Gas Recovery and Carbon Dioxide Geological Storage: Investigation of the Right Bank of the Amu Darya River 221 Qi Li, Xiaying Li, Zhiyong Niu, Dongqin Kuang, Jianli Ma, Xuehao Liu, Yankun Sun and Xiaochun Li 12.1 Introduction 222 12.2 The Amu Darya Right Bank Gas Reservoirs in Turkmenistan 223Contents xi 12.3 Model Development 223 12.3.1 State equation 224 12.3.1.1 Introduction of Traditional PR State Equation 224 12.3.1.2 Modifications for the Vapor-Aqueous System 224 12.3.2 Salinity 225 12.3.3 Diffusion 226 12.3.3.1 Diffusion Coefficients 226 12.3.3.2 The Cross-Phase Diffusion Coefficients 226 12.4 Simulation Model 227 12.4.1 Model Parameters 227 12.4.2 Grid-Sensitive Research of the Model 227 12.4.3 The Development and Exploitation Mode 230 12.5 Results and Discussion 230 12.5.1 Reservoir Pressure 230 12.5.2 Gas Sequestration 232 12.5.3 Production 235 12.5.4 Recovery Ratio and Recovery Percentage 238 12.6 Conclusions 239 12.7 Acknowledgments 240 References 241 Index 245
Preface xiii 1 Enthalpies of Carbon Dioxide-Methane and Carbon Dioxide-Nitrogen Mixtures: Comparison with Thermodynamic Models 1 Erin L. Roberts and John J. Carroll 1.1 Introduction 1 1.2 Enthalpy 2 1.3 Literature Review 2 1.3.1 Carbon Dioxide-Methane 4 1.3.2 Carbon Dioxide-Nitrogen 4 1.4 Calculations 5 1.4.1 Benedict-Webb-Rubin 6 1.4.2 Lee-Kesler 12 1.4.3 Soave-Redlich-Kwong 17 1.4.4 Peng-Robinson 23 1.4.5 AQUAlibrium 28 1.5 Discussion 33 1.6 Conclusion 36 References 37 2 Enthalpies of Hydrogen Sulfide-Methane Mixture: Comparison with Thermodynamic Models 39 Erin L. Roberts and John J. Carroll 2.1 Introduction 39 2.2 Enthalpy 40 2.3 Literature Review 40 2.4 Calculations 41 2.4.1 Lee-Kesler 41 2.4.2 Benedict-Webb-Rubin 43 2.4.3 Soave-Redlich-Kwong 43 2.4.4 Redlich-Kwong 47 2.4.5 Peng-Robinson 47 2.4.6 AQUAlibrium 50 2.5 Discussion 50 2.6 Conclusion 52 References 54 3 Phase Behavior and Reaction Thermodynamics Involving Dense-Phase CO2 Impurities 55 J.A. Commodore, C.E. Deering and R.A. Marriott 3.1 Introduction 55 3.2 Experimental 57 3.3 Results and Discussion 58 3.3.1 Phase Behavior Studies of SO2 Dissolved in Dense CO2 Fluid 58 3.3.2 The Densimetric Properties of CS2 and CO2 Mixtures 60 References 61 4 Sulfur Recovery in High Density CO2 Fluid 63 S. Lee and R.A. Marriott 4.1 Introduction 64 4.2 Literature Review 64 4.3 Methodology 65 4.4 Results and Discussion 66 4.5 Conclusion and Future Directions 67 References 68 5 Carbon Capture Performance of Seven Novel Immidazolium and Pyridinium Based Ionic Liquids 71 Mohamed Zoubeik, Mohanned Mohamedali and Amr Henni 5.1 Introduction 71 5.2 Experimental Work 73 5.2.1 Materials 73 5.2.2 Density Measurement 73 5.2.3 Solubility Measurement 73 5.3 Modeling 76 5.3.1 Calculation of Henry's Law Constants 76 5.3.2 Critical Properties Calculations 76 5.3.3 Peng Robinson EoS 76 5.4 Results and Discussion 77 5.4.1 Density 77 5.4.2 Critical Properties 77 5.4.3 CO2 Solubility 78 5.4.4 The Effect of Changing the Cation 81 5.4.5 The Effect of Changing the Anion 84 5.4.6 Henry's Law Constant, Enthalpy and Entropy Calculations 85 5.4.7 Thermodynamic Modeling of CO2 Solubility 86 5.5 Conclusion 87 Acknowledgements 88 References 88 6 Vitrisol a 100% Selective Process for H2S Removal in the Presence of CO2 91 W.N. Wermink, N. Ramachandran, and G.F. Versteeg 6.1 Introduction 92 6.2 Case Definition 94 6.3 "Amine-Treated" Cases by PPS 95 6.3.1 Introduction to PPS 95 6.3.2 Process Description 96 6.3.3 PFD 97 6.3.4 Results 97 6.3.4.1 Case 1 97 6.3.4.2 Case 2 97 6.4 Vitrisol ò nProcess Extended with Regeneration of Active Component 99 6.4.1 Technology Description 99 6.4.2 Parameters Determining the Process Boundary Conditions 99 6.4.3 Absorption Section 101 6.4.4 Regeneration Section 102 6.4.5 Sulphur Recovery Section 104 6.4.6 CO2-Absorber 105 6.4.7 PFD 105 6.5 Results 105 6.6 Discussion 110 6.6.1 Comparison of Amine Treating Solutions to Vitrisol ò n110 6.6.2 Enhanced H2S Removal of Barnett Shale Gas (case 2) 112viii Contents 6.7 Conclusions 113 6.8 Notation 115 References 115 Appendix 6-A: H&M Balance of Case 1 (British Columbia shale) of the Amine Process 117 Appendix 6-B H&M Balance of Case 2a (Barnett shale) of the Amine Process with Stripper Promoter 119 Appendix 6-C H&M Balance of Case 3 (Barnett shale) of the Amine Process (MEA) 121 Appendix 6-D: H&M Balance of Case 1 (British Columbia shale) of the Vitrisol nprocess 123 Appendix 6-E H&M Balance of Case 2 (Barnett shale) of the Vitrisol nProcess 125 7 New Amine Based Solvents for Acid Gas Removal 127 Yohann Coulier, Elise El Ahmar, Jean-Yves Coxam, Elise Provost, Didier Dalmazzone, Patrice Paricaud, Christophe Coquelet and Karine Ballerat-Busserolles 7.1 Introduction 128 7.2 Chemicals and Materials 131 7.3 Liquid-Liquid Equilibria 131 7.3.1 LLE in {methylpiperidines - H2O} and {methylpiperidines - H2O - CO2} 131 7.3.2 Liquid-Liquid Equilibria of Ternary Systems {Amine - H2O - Glycol} 135 7.3.3 Liquid-Liquid Equilibria of the Quaternary Systems {CO2 - NMPD - TEG - H2O} 136 7.4 Densities and Heat Capacities of Ternary Systems {NMPD - H2O - Glycol} 137 7.4.1 Densities 137 7.4.2 Specific Heat Capacities 137 7.5 Vapor-Liquid Equilibria of Ternary Systems {NMPD - TEG - H2O - CO2} 139 7.6 Enthalpies of Solution 140 7.7 Discussion and Conclusion 143 Acknowledgments 143 References 144Contents ix 8 Improved Solvents for CO2 Capture by Molecular Simulation Methodology 147 William R. Smith 8.1 Introduction 147 8.2 Physical and Chemical Models 149 8.3 Molecular-Level Models and Algorithms for Thermodynamic Property Predictions 150 8.4 Molecular-Level Models and Methodology for MEA-H2O-CO2 153 8.4.1 Extensions to Other Alkanolamine Solvents and Their Mixtures 155 Acknowledgements 157 References 157 9 Strategies for Minimizing Hydrocarbon Contamination in Amine Acid Gas for Reinjection 161 Mike Sheilan, Ben Spooner and David Engel 9.1 Introduction 162 9.2 Amine Sweetening Process 162 9.3 Hydrocarbons in Amine 164 9.4 Effect of Hydrocarbons on the Acid Gas Reinjection System 166 9.5 Effect of Hydrocarbons on the Amine Plant 167 9.6 Minimizing Hydrocarbon Content in Amine Acid Gas 171 9.6.1 Option 1. Optimization of the Amine Plant Operation 171 9.6.2 Option 2. Amine Flash Tanks 176 9.6.3 Option 3. Rich Amine Liquid Coalescers 178 9.6.4 Option 4. Use of Skimming Devices 180 9.6.5 Option 5. Technological Solutions 182 References 183 10 Modeling of Transient Pressure Response for CO2 Flooding Process by Incorporating Convection and Diffusion Driven Mass Transfer 185 Jianli Li and Gang Zhao 10.1 Introduction 186 10.2 Model Development 187 10.2.1 Pressure Diffusion 187 10.2.2 Mass Transfer 188 10.2.3 Solutions 190x Contents 10.3 Results and Discussion 191 10.3.1 Flow Regimes 191 10.3.2 Effect of Mass Transfer 192 10.3.3 Sensitivity Analysis 195 10.3.3.1 CO2 Bank 195 10.3.3.2 Reservoir Outer Boundary 196 10.4 Conclusions 196 Acknowledgments 197 References 197 11 Well Modeling Aspects of CO2 Sequestration 199 Liaqat Ali and Russell E. Bentley 11.1 Introduction 199 11.2 Delivery Conditions 200 11.3 Reservoir and Completion Data 201 11.4 Inflow Performance Relationship (IPR) and Injectivity Index 201 11.5 Equation of State (EOS) 202 11.6 Vertical Flow Performance (VFP) Curves 205 11.7 Impact of the Well Deviation on CO2 Injection 208 11.8 Implication of Bottom Hole Temperature (BHT) on Reservoir 209 11.9 Impact of CO2 Phase Change 213 11.10 Injection Rates, Facility Design Constraints and Number of Wells Required 214 11.11 Wellhead Temperature Effect on VFP Curves 214 11.12 Effect of Impurities in CO2 on VFP Curves 216 11.13 Concluding Remarks 217 Conversion Factors 218 References 218 12 Effects of Acid Gas Reinjection on Enhanced Natural Gas Recovery and Carbon Dioxide Geological Storage: Investigation of the Right Bank of the Amu Darya River 221 Qi Li, Xiaying Li, Zhiyong Niu, Dongqin Kuang, Jianli Ma, Xuehao Liu, Yankun Sun and Xiaochun Li 12.1 Introduction 222 12.2 The Amu Darya Right Bank Gas Reservoirs in Turkmenistan 223Contents xi 12.3 Model Development 223 12.3.1 State equation 224 12.3.1.1 Introduction of Traditional PR State Equation 224 12.3.1.2 Modifications for the Vapor-Aqueous System 224 12.3.2 Salinity 225 12.3.3 Diffusion 226 12.3.3.1 Diffusion Coefficients 226 12.3.3.2 The Cross-Phase Diffusion Coefficients 226 12.4 Simulation Model 227 12.4.1 Model Parameters 227 12.4.2 Grid-Sensitive Research of the Model 227 12.4.3 The Development and Exploitation Mode 230 12.5 Results and Discussion 230 12.5.1 Reservoir Pressure 230 12.5.2 Gas Sequestration 232 12.5.3 Production 235 12.5.4 Recovery Ratio and Recovery Percentage 238 12.6 Conclusions 239 12.7 Acknowledgments 240 References 241 Index 245
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