Chapter
1.6 Instrumentation and Set up
2 Key Technologies of Carbon Dioxide Flooding and Storage in China
2.2 Key Technologies of Carbon dioxide Flooding and Storage
2.2.1 CO2 Miscible Flooding Theory in Continental Sedimentary Reservoirs
2.2.2 The Storage Mechanism of CO2 in Reservoirs and Salt Water Layers
2.2.3 Reservoir Engineering Technology of CO2 Flooding and Storage
2.2.4 High Efficiency Technology of Injection and Production for CO2 Flooding
2.2.5 CO2 Long-Distance Pipeline Transportation and Supercritical Injection Technology
2.2.6 Fluid Treatment and Circulating Gas Injection Technology of CO2 Flooding
2.2.7 Reservoir Monitoring and Dynamic Analysis and Evaluation Technology of CO2 Flooding
2.3 Existing Problems and Technical Development Direction
2.3.1 The Vital Communal Troubles & Challenges
2.3.2 Further Orientation of Technology Development
3 Mapping CCUS Technological Trajectories and Business Models: The Case of CO2-Dissolved
3.2 CCS and Roadmaps: From Expectations to Reality ...
3.3 CCS Project Portfolio: Between Diversity and Replication
3.3.1 Demonstration Process: Between Diversity and Replication
3.3.2 Diversity of the Current Project Portfolio
3.4 Going Beyond EOR: Other Business Models for Storage?
3.4.2 From EOR to a CCS Wide-Scale Deployment
3.5 Coupling CCS and Geothermal Energy: Lessons from the CO2-DISSOLVED Project Study
3.5.1 CO2-DISSOLVED Concept
3.5.2 Techno-Economic Analysis of CO2-DISSOLVED
3.5.3 Business Models and the Replication/Diversity Dilemma
4 Feasibility of Ex-Situ Dissolution for Carbon Dioxide Sequestration
4.2 Methods to Accelerate Dissolution
4.3 Discussion and Conclusions
5 CO2 Gas Injection as an EOR Technique – Phase Behavior Considerations
5.4 Immiscible CO2 Drives and Density Effects
5.5 Asphaltene Precipitation Caused by Gas Injection
5.6 Gas Revaporization as EOR Technique
Appendix A Reservoir Fluid Compositions and Key Property Data
6 Study on Storage Mechanisms in CO2 Flooding for Water-Flooded Abandoned Reservoirs
6.2 CO2 Solubility in Coexistence of Crude Oil and Brine
6.3 Mineral Dissolution Effect
6.4 Relative Permeability Hysteresis
6.5 Effect of CO2 Storage Mechanisms on CO2 Flooding
7 The Investigation on the Key Hydrocarbons of Crude Oil Swelling via Supercritical CO2
7.2 Hydrocarbon Selection
7.3.2 Apparatus and Samples
7.3.3 Experimental Scheme Design
7.4 Results and Discussion
7.4.1 Results and Data Processing
7.4.2 Volume Swelling Influenced by the Hydrocarbon Property
7.4.3 A New Parameter of Molar Density for Evaluating Hydrocarbon Volume Swelling
7.4.4 Advantageous Hydrocarbons
8 Pore-Scale Mechanisms of Enhanced Oil Recovery by CO2 Injection in Low-Permeability Heterogeneous Reservoir
8.2 Experimental Device and Samples
8.3 Experimental Procedure
8.3.1 Experimental Results
8.4 Quantitative Analysis of Oil Recovery in Different Scale Pores
Part III: Data – Experimental and Correlation
9 Experimental Measurement of CO2 Solubility in a 1 mol/kgw CaCl2 Solution at Temperature from 323.15 to 423.15 K and Pressure up to 20 MPa
9.3.3 Operating Procedure
9.4 Results and Discussion
10 Determination of Dry-Ice Formation during the Depressurization of a CO2 Re-Injection System
10.3.1 System Description
10.3.4 Simulation Runs Conclusions
11 Phase Equilibrium Properties Aspects of CO2 and Acid Gases Transportation
11.1.1 State of the Art and Phase Diagrams
11.2 Experimental Work and Description of Experimental Setup
11.3 Models and Correlation Useful for the Determination of Equilibrium Properties
11.4 Presentation of Some Results
12 Thermodynamic Aspects for Acid Gas Removal from Natural Gas
12.2 Thermodynamic Models
12.3 Results and Discussion
12.3.1 Hydrocarbons and Mercaptans Solubilities in Aqueous Alkanolamine Solution
12.3.2 Acid Gases (CO2/H2S) Solubilities in Aqueous Alkanolamine Solution
12.3.3 Multi-component Systems Containing CO2-H2SAlkanolamine-Water-Methane-Mercaptan
12.4 Conclusion and Perspectives
13 Speed of Sound Measurements for a CO2 Rich Mixture
13.1 Experimental Section
13.1.2 Experimental Setup
13.2 Results and Discussion
14 Mutual Solubility of Water and Natural Gas with Different CO2 Content
14.2.2 Experimental Apparatus
14.2.3 Experimental Procedures
14.3.1 The Cubic-Plus-Association Equation of State
14.3.2 Parameterization of the Model
14.4 Results and Discussion
14.4.1 Phase Behavior of CO2-Water
14.4.2 The Mutual Solubility of Water-Natural Gas
15 Effect of SO2 Traces on Metal Mobilization in CCS
15.2.1 Sample Preparation
15.2.2 Experimental Set-up
15.2.3 Experimental Methodology
15.3 Results and Discussion
15.3.3 Metal Mobilization
16 Experiments and Modeling for CO2 Capture Processes Understanding
16.2 Chemicals and Materials
16.3 Vapor-Liquid Equilibria
16.3.1 Experimental VLE of Pure Amine
16.3.2 Experimental VLE of {Amine – H2O} System
16.4 Speciation at Equilibrium
16.4.1 Equilibrium Measurements 1H and 13C NMR
16.4.2 Modeling of Species Concentration
Part IV: Molecular Simulation
17 Kinetic Monte Carlo Molecular Simulation of Chemical Reaction Equilibria
18 Molecular Simulation Study on the Diffusion Mechanism of Fluid in Nanopores of Illite in Shale Gas Reservoir
18.2 Models and Simulation Details
18.2.1 Models and Simulation Parameters
18.2.2 Data Processing and Computing Methods
18.3 Results and Discussion
18.3.1 Variation Law of Self Diffusion Coefficient
18.3.2 Density Distribution
18.3.3 Radial Distribution Function
19 Molecular Simulation of Reactive Absorption of CO2 in Aqueous Alkanolamine Solutions
20 CO2 Capture from Natural Gas in LNG Production. Comparison of Low-Temperature Purification Processes and Conventional Amine Scrubbing
20.2 Description of Process Solutions
20.2.1 The Ryan-Holmes Process
20.2.2 The Dual Pressure Low-Temperature Distillation Process
20.2.3 The Chemical Absorption Process
20.4 Results and Discussion
21 CO2 Capture Using Deep Eutectic Solvent and Amine (MEA) Solution
21.1 Experimental Section
21.2 Results and Discussion
21.2.1 Validation of the Experimental Method
21.2.2 Solubility of CO2 in the Solvent DES/MEA
21.2.3 Solubility of CO2 – Comparison Between DES + MEA and DES Solvent
21.2.4 Solubility of CO2 – Comparison Between (DES + MEA) and (H2O + MEA) Solvent
22 The Impact of Thermodynamic Model Accuracy on Sizing and Operating CCS Purification and Compression Units
22.2 Thermodynamic Systems in CCUS Technologies
22.2.1 Compositional Characteristics of CO2 Captured Flows
22.2.3 Oxy-Fuel Combustion
22.3 Operating Conditions of Purification and Compression Units
22.4 Quality Specifications of CO2 Capture Flows
22.5 Cubic Equations of State for CCUS Fluids
22.6 Influence of EoS Accuracy on Purification and Compression Processes
22.7 Purification by Liquefaction
22.8 Purification by Stripping
Nomenclature and Acronyms
Cutting-Edge Technology for Carbon Capture, Utilization, and Storage
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