Search

Browse Subject Areas

For Authors

Submit a Proposal

Join Our Mailing List

Enter your email address:

Enter your first name:

Enter your last name:

Choose subjects that interest you
Hold down the CTRL key for multiple selection



Carbon Dioxide Capture and Acid Gas Injection

Edited by Ying Wu and John J. Carroll
Series: Advances in Natural Gas Engineering
Copyright: 2017   |   Expected Pub Date:April 2017//
ISBN: 9781118938669  |  Hardcover  |  

Price: $225 USD
Add To Cart

One Line Description
This sixth volume in the series, Advances in Natural Gas Engineering, offers the most in-depth and up-to-date treatment of CO2 capture and acid gas injection, two of the hottest topics in natural gas engineering.

Audience
Process engineers, chemical engineers, reservoir engineers, geologist, geochemist and other engineers and scientists working in natural gas

Description

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.



Back to Top
Supplementary Data
• Presents the state-of-the-art processes and technologies for CO2 capture, one of the most important elements in natural gas engineering that can reduce the carbon footprint
• Covers the most recent advances in natural gas engineering for acid gas injection, one of the industry’s hottest topics
• Covers technologies for working towards a zero-emission process in natural gas production
• Written by a team of the world’s most well-known scientists and engineers in the field


Author / Editor Details
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.


Back to Top

Table of Contents
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
6.3 Case Definition 94
6.4 “Amine-Treated” Cases by PPS 95
6.4.1 Introduction to PPS 95
6.4.2 Process Description 96
6.4.3 PFD 97
6.4.4 Results 97
6.4.4.1 Case 1 97
6.4.4.2 Case 2 98
6.5 Vitrisol‚ Process Extended with Regeneration of Active
Component 99
6.5.1 Technology Description 99
6.5.2 Parameters Determining the Process Boundary
Conditions 99
6.5.3 Absorption Section 101
6.5.4 Regeneration Section 102
6.5.5 Sulphur Recovery Section 104
6.5.6 CO2-Absorber 105
6.5.7 PFD 105
6.6 Results 105
6.7 Discussion 110
6.7.1 Comparison of Amine Treating
Solutions to Vitrisol‚ 111
6.7.2 Enhanced H2S Removal of Barnett
Shale Gas (case 2) 112
6.8 Conclusions 113
6.9 Notation 115
References 115
Appendix 6-A: H&M Balance of Case 1 (British
Columbia shale) of the Amine Process 118
Appendix 6-B H&M Balance of Case 2a (Barnett shale)
of the Amine Process with Stripper Promoter 120
Appendix 6-C H&M Balance of Case 3 (Barnett shale)
of the Amine Process (MEA) 122
Appendix 6-D: H&M Balance of Case 1 (British
Columbia shale) of the Vitrisol process 124
Appendix 6-E H&M Balance of Case 2 (Barnett shale)
of the Vitrisol Process 126
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
7.4.1 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 144
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 190
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 223
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

Back to Top


BISAC SUBJECT HEADINGS
TEC031030 : TECHNOLOGY & ENGINEERING / Power Resources / Fossil Fuels
SCI024000 : SCIENCE / Energy
MAT003000 : MATHEMATICS / Applied
 
BIC CODES
THFG: Gas technology
TDCB: Chemical engineering
TQ: ENVIRONMENTAL SCIENCE, ENGINEERING & TECHNOLOGY

Back to Top


Description
BISAC & BIC Codes
Author/Editor Details
Table of Contents
Bookmark this page