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The Three Sisters: Acid Gas Injection, Carbon Capture and Sequestration, and Enhanced Oil Recovery

Edited by Ying (Alice) Wu, John J. Carroll, and Yongle Hu
Series: Advances in Natural Gas Engineering
Copyright: 2019   |   Status: Published
ISBN: 9781119510062  |  Hardcover  |  
360 pages
Price: $249 USD
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One Line Description
This seventh volume in the series, Advances in Natural Gas Engineering, presents the “three sisters,” the three hottest and most important topics in the industry today, both independently and how they’re interrelated: acid gas injection, carbon capture and sequestration, and enhanced oil recovery.

Audience
Natural gas engineers, petroleum engineers, process engineers, chemical engineers, reservoir engineers, geologists, geochemists and other engineers and scientists working in natural gas, including students and professors working in these areas

Description
This is the seventh volume in the series, Advances in Natural Gas Engineering, focusing on carbon dioxide (CO2) capture and sequestration, acid gas injection, and enhanced oil recovery, the “three sisters” of natural gas engineering. This volume includes information for both upstream and downstream operations, including chapters detailing the most cutting-edge techniques in acid gas injection, 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 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 in the industry. 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.



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Supplementary Data
• Updates 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
• Presents the most recent advances in natural gas engineering for acid gas injection, one of the industry’s hottest topics
• Covers enhanced oil recovery and how it is related to CO2 capture and acid gas injection in an integrated way of thinking
• Explores technologies for working towards a zero-emission process in natural gas production
• Edited and 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.

Mr. Yongle Hu is a Professor and Chief Engineer in the Research Institute of Petroleum Exploration and Development (RIPED) of the China National Petroleum Co. (CNPC) in China. The Research Institute of Petroleum Exploration and Development was established in 1958 and is one of the famous research institutes in China. It is the R&D center of CNPC and PetroChina Company Ltd. Mr. Hu has PhD degree in Oil and Gas Development and Reservoir Engineering. He graduated from RIPED and Northeast Petroleum University, Daqing, China. Mr. Hu has published many technical papers and holds a high reputation for his technical qualifications on unconventional oil and gas development and research.

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Table of Contents
Preface xiii
1 Acid Gas Injection: Engineering Steady State in a
Dynamic World 1
Jim Maddocks
1.1 Introduction 1
1.2 Steady-State Processes 2
1.3 Basic Process Requirements 3
1.3.1 Process Needs 3
1.4 Process Input Variabilities 4
1.4.1 Compositional Variances 4
1.4.2 Flow Variances 5
1.4.3 Initial Suction Temperature Variances 6
1.4.4 Initial Suction Pressure Variances 7
1.4.5 Amine Plant Generated Instability 8
1.5 Process Output Variables 9
1.5.1 Discharge Pressure Variances 9
1.6 AGI Process Associated Variables 11
1.6.1 Variable Response Mechanisms 11
1.6.2 Cooling Variances 13
1.6.3 Speed Management Variances 16
1.6.4 Scrubber Level Management Variances 16
1.6.5 Contaminant Based Variances 17
1.6.6 Recycle Control Based Variances 18
1.7 Conclusion 20
Reference 22
2 A History of AGIS 23
Ying (Alice) Wu
2.1 Introduction 23
2.2 Venues 24
2.3 Keynote Speaker 25
2.4 Workshops 26
2.5 Roundtable 27
2.6 Sponsors 27
2.7 AGIS Books 27
2.8 Conclusion 27
3 Acid Gas Injection: Days of Future Passed 29
John J Carroll
3.1 Introduction 29
3.2 State of the Art 30
3.2.1 Third Generation 32
3.2.2 Offshore 33
3.3 New Processes 34
3.3.1 New Solvents 34
3.3.2 DexPro 34
3.3.3 CFZTM 35
3.4 Modelling 35
3.5 More Data 35
3.6 The New Future 35
References 36
4 Calorimetric and Densimetric Data to Help the Simulation of
the Impact of Annex Gases Co-Injected with CO2 During Its
Geological Storage 39
F De los Mozos, K Ballerat-Busserolles, B Liborio, N Nénot,
J-Y Coxam and Y Coulier
4.1 Introduction 40
4.2 Material and Methods 43
4.2.1 Densimetric Measurements 43
4.2.2 Calorimetric Measurements 47
4.2.3 Absorption of CO2 in Aqueous Solutions 49
4.2.4 Absorption of SO2 in Aqueous Solutions 50
4.2.5 Comparison Between the Two Gases 52
Acknowledgement 53
References 53
5 Densities and Phase Behavior Involving Dense-Phase Propane
Impurities 55
JA Commodore, CE Deering and RA Marriott
5.1 Introduction 56
5.2 Experimental Section 57
5.3 Results and Discussion 58
5.4 Conclusion and Future Work 60
References 61
6 Phase Equilibrium Computation for Acid Gas Mixtures
Containing H2S Using the CPA Equation of State 63
Hanmin Tu, Ping Guo, Na Jia and Zhouhua Wang
6.1 Introduction 64
6.2 The Cubic-Plus-Association Equation of State 67
6.3 Association Schemes 69
6.4 Results and Discussion 71
6.4.1 Binary Interaction Parameter 71
6.4.2 Solubility Calculation 75
6.5 Conclusions 84
6.6 Acknowledgment 88
References 88
7 High Pressure H2S Oxidation in CO2 91
S Lee and RA Marriott
7.1 Introduction 92
7.1.1 Experimental Section 93
7.1.2 Results and Discussion 94
7.1.3 Conclusion and Future Direction 95
References 95
8 Water Content of Carbon Dioxide --A Review 97
Eugene Grynia1, and Bogdan Ambrożek
8.1 Introduction 98
8.2 Literature Review 99
8.2.1 1924 100
8.2.2 1941 100
8.2.3 1943 100
8.2.4 1959 100
8.2.5 1963 101
8.2.6 1964 101
8.2.7 1971 101
8.2.8 1981 101
8.2.9 1982 101
8.2.10 1984 102
8.2.11 1986 102
8.2.12 1987 102
8.2.13 1988 103
8.2.14 1991 103
8.2.15 1992 103
8.2.16 1993 104
8.2.17 1995 104
8.2.18 1996 104
8.2.19 1997 104
8.2.20 2000 104
8.2.21 2002 105
8.2.22 2004 105
8.2.23 2008 105
8.2.24 2009 106
8.2.25 2011 106
8.2.26 2012 106
8.2.27 2013 107
8.2.28 2014 107
8.2.29 2015 107
8.2.30 2016 108
8.2.31 2017 109
8.3 Data Analysis 109
8.4 Experimental Methods 166
8.5 Conclusions 169
References 179
9 Molecular Simulation of pK Values and CO2 Reactive
Absorption Prediction 185
Javad Noroozi and William R Smith
9.1 Introduction 185
9.2 Thermodynamic Background 186
9.3 Molecular Simulation Methodology 188
9.4 Application to the MEA-H2O-CO2 System 189
References 191
10 A Dynamic Simulation to Aid Design of Shell--‚¬â„¢s CCS Quest
Project--‚¬â„¢s Multi-Stage Compressor Shutdown System 193
William Acevedo, Chris Arthur and James van der Lee
10.1 Introduction 194
10.2 Centrifugal Compressor Reversal 195
10.3 Dynamic Modelling 201
10.4 Simulation Results 210
10.5 Modified Blowdown System 217
10.6 Conclusions 217
References 218
11 Benefits of Diaphragm Pumps for the Compression of
Acid Gas 219
Anke-Dorothee Wöhr, Cornelia Beddies and
Rüdiger Bullert
11.1 Characteristics of Diaphragm Pumps 219
11.2 Current Projects 222
11.3 Improving Efficiency of Acid Gas Compression 224
11.4 Increasing Pressures 225
11.5 Varying Compositions 226
11.6 Pressure Pulsation and Synchronization 230
11.7 Conclusion 231
References 233
12 Dynamic Solubility of Acid Gases in a Deep Brine Aquifer 235
Liaqat Ali1 and Russell E Bentley
12.1 Introduction 236
12.2 Reservoir Simulation Modeling 237
12.3 3D Static Model 237
12.4 History Matching 240
12.5 Results 241
12.6 Summary and Conclusions 252
References 253
13 Tomakomai CCS Demonstration Project of Japan, CO2
Injection in Progress 255
Yoshihiro Sawada, Jiro Tanaka, Chiyoko Suzuki,
Daiji Tanase and Yutaka Tanaka
13.1 Introduction 255
13.2 Overview of Tomakomai Project 257
13.3 Injection Record 261
13.4 Features of Tomakomai Project 262
13.4.1 Feature 1: Extensive Monitoring System in a
Seismically Active Country 262
13.4.2 Feature 2: Deviated CO2 Injection Wells Drilled
From Onshore to Offshore 268
13.4.3 Feature 3: Application of Law Reflecting London
Protocol 268
13.4.4 Feature 4: Low Energy CO2 Capture Process
Utilizing High CO2 Partial Pressure Gas 269
13.4.5 Feature 5: Injection of CO2 Near Urban Area 271
13.5 Conclusion 273
Acknowledgments 275
References 275
14 The Development Features and Cost Analysis of CCUS
Industry in China 277
Mingqiang Hao, Yongle Hu, Shiyu Wang and Lina Song
14.1 Introduction 278
14.2 Characteristics of CCUS Project 278
14.2.1 Distribution and Characteristics of CCUS
Project 278
14.2.2 Types and Scales of CCUS Emission Sources 278
14.2.3 Emission Scales and Composition of CO2
Emission Enterprises in China 280
14.2.4 Distributions of CO2 Sources in China 280
14.2.5 Characteristic Comparison Between Projects
in China and Abroad 281
14.3 Industry Patterns & Driving Modes 285
14.3.1 CCUS Industry Patterns at Home and Aboard 285
14.3.2 Driving Modes of CCUS Industry 286
14.3.2.1 Incentive Policy: Investment and
Subsidy From Government 286
14.3.2.2 Improvement of Carbon Pricing
Mechanism 287
14.3.2.3 The Progress of CCUS Technology:
A Lower Cost 287
14.4 Composition & Factors of CO2 Source Cost 288
14.5 Conclusions 291
References 292
15 Carbon Anode Materials for Sodium-ion Batteries 295
Yong Qin
15.1 Introduction 296
15.2 Mechanism of CO2 Huff-and-Puff in Developing Low
Permeability Reservoirs 297
15.2.1 CO2 Mechanism for Oil Expansion 297
15.2.2 CO2 Mechanism for Reduction of Oil Viscosity 297
15.2.3 Acid Plugging Removal 297
15.2.4 Dissolved Gas Flooding 297
15.2.5 Improved Oil-Water Density Ratio 297
15.2.6 Improved Oil-Water Fluidity Ratio 298
15.2.7 Reduced Interfacial Tension 298
15.2.8 Formation of Miscible Fluids 298
15.3 CO2 Diffusion and Mass Transfer in Dense Pores 298
15.4 Production Simulation of CO2 Huff-and-Puff 301
15.4.1 Overview of Numerical Model 301
15.4.2 The Process of CO2 Huff-and-Puff 303
15.4.3 The Influence of Diffusion Coefficient on
Huff-and-Puff 303
15.4.4 Optimization of Soaking Duration 305
15.4.5 The Influence of Soaking Duration on
Huff-and-Puff Results 305
15.5 Conclusion 308
References 308
16 Potential Evaluation Method of Carbon Dioxide Flooding
and Sequestration 311
Yongle Hu, Mingqiang Hao, Chao Wang, Xinwei Liao and
Lina Song
16.1 Introduction 311
16.2 CO2 Miscible Flooding and Sequestration Potential
Evaluation Model and Sequestration Capacity
Calculation Method 312
16.2.1 CO2 Miscible Flooding and Sequestration
Potential Evaluation Model 312
16.2.2 CO2 Miscible Flooding and Sequestration
Capacity Calculation Method 314
16.2.3 CO2 Miscible Flooding and Sequestration
Potential Evaluation Model and Sequestration
Capacity Calculation Method 317
16.3 Potential Evaluation Model and Calculation Method of
CO2 Sequestration 318
16.3.1 Calculation Method of CO2 Theoretical
Sequestration Capacity 318
16.3.2 Calculation Method of CO2 Effective Sequestration
Capacity 319
16.3.3 Calculation Method of Carbon Dioxide
Practical Sequestration Capacity 321
16.4 An Example of CO2 Flooding and Sequestration
Potential Evaluation 321
16.4.1 Data Collection and Sorting 321
16.4.2 Calculate the Minimum Miscibility Pressure
and Judge Whether or Not to Be Miscible 321
16.4.3 Choose Suitable Reservoirs for CO2 Flooding
and Sequestration 328
16.4.4 Determine CO2 EOR and Geological
Sequestration Coefficient 328
16.4.5 Determine the Oil Increment and CO2
Sequestration Capacity 329
16.4.6 Analyze Evaluation Results 329
16.5 Conclusions 329
References 329
17 Emergency Response Planning for Acid Gas Injection Wells 333
Ray Mireault
17.1 Introduction 334
17.2 Hydrocarbon Well Blowout Control Practices 335
17.3 Acid Gas Blowout Thermodynamics 335
17.4 Acid Gas Wellbore Dynamics 336
17.5 Acid Gas Plume Behaviour 340
17.6 Analogue Performance 340
17.7 Acid Gas Well Control Procedures 341
References 343
Appendix 344

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BISAC SUBJECT HEADINGS
TEC031030 : TECHNOLOGY & ENGINEERING / Power Resources / Fossil Fuels
SCI024000 : SCIENCE / Energy
BUS070040 : BUSINESS & ECONOMICS / Industries / Energy
 
BIC CODES
THF: Fossil fuel technologies
TDCB: Chemical engineering
RBGK: Geochemistry

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