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Introduction to modelling, simulation and optimization of CO2 sequestration in various types of reservoirs /

Carbon capture and sequestration has become an essential technology for addressing the mitigation of global warming and adverse climate change due to increasing CO2 emissions from fossil fuel combustion worldwide.

Bibliographic Details
Main Authors: Agarwal, Ramesh (Author), Liu, Danqing (Author)
Corporate Author: ScienceDirect (Online service)
Format: eBook
Language:English
Published: Amsterdam, Netherlands : Elsevier, [2025]
Subjects:
Carbon sequestration > Simulation methods.
Piégeage du carbone > Méthodes de simulation.
Electronic books.
Online Access:Connect to the full text of this electronic book
Table of Contents:
  • Front Cover
  • Introduction to Modeling, Simulation and Optimization of CO2 Sequestration in Various Types of Reservoirs
  • Copyright
  • Contents
  • Preface
  • Acknowledgments
  • Chapter 1: Carbon capture, utilization, and storage: Technology development and applications, policy considerations, and ...
  • 1.1. Introduction
  • 1.2. Progress in CCUS technology research
  • 1.2.1. CO2 capture
  • 1.2.1.1. Precombustion capture
  • 1.2.1.2. Capture with oxygen-enriched combustion
  • 1.2.1.3. Postcombustion capture
  • 1.2.1.4. Direct air capture
  • 1.2.1.5. Biocapture
  • 1.2.2. CO2 transport
  • 1.2.3. CO2 storage
  • 1.2.3.1. Mechanisms for geological storage of CO2
  • 1.2.3.2. CO2 geological storage media
  • Deep saline aquifers
  • Depleted oil and gas reservoirs
  • Unmineable coal seams
  • Organic-rich shale layers
  • Basalt reservoirs
  • Seafloor sedimentary layers
  • 1.2.4. CO2 utilization
  • 1.2.4.1. Chemical utilization
  • 1.2.4.2. Bioutilization
  • 1.3. Status of CCUS technology applications
  • 1.3.1. Global CCUS projects
  • 1.3.2. Application of CCUS technology
  • 1.3.2.1. CCUS technology applications in the electric power industry
  • 1.3.2.2. Capture and utilization of CO2 in bioenergy
  • 1.4. CCUS policy
  • 1.5. CCUS economic analysis
  • 1.5.1. Factors affecting the economic viability of CCUS
  • 1.5.2. Economic model
  • 1.6. Challenges and prospects for CCUS technology
  • 1.6.1. Challenges
  • 1.6.1.1. Construction and operating costs
  • 1.6.1.2. CO2 storage safety and environmental risks
  • 1.6.1.3. Policy support
  • 1.6.1.4. Social acceptance
  • 1.6.2. Outlook
  • References
  • Chapter 2: Basic properties of CO2, groundwater, and geological storage sites
  • 2.1. Properties of CO2
  • 2.1.1. Basic properties of CO2
  • 2.1.2. Phase transformation rule of CO2
  • 2.1.3. Physical properties of CO2
  • 2.1.3.1. Density of CO2.
  • 2.1.3.2. Viscosity of CO2
  • 2.1.3.3. Diffusion coefficient of CO2
  • 2.1.3.4. Surface tension of CO2
  • 2.1.4. Thermodynamic properties in CO2-H2O system
  • 2.1.4.1. P-V-T relationship of pure CO2 fluid
  • 2.1.4.2. The equation of states of CO2 fluid
  • 2.1.4.3. Thermodynamic properties of the solution
  • 2.1.4.4. Phase balance
  • 2.2. Geological storage medium of CO2
  • 2.2.1. Storage layer
  • 2.2.1.1. Saline aquifer storage
  • 2.2.1.2. Unmineable coal seams storage
  • 2.2.1.3. Oil and gas reservoir storage
  • 2.2.1.4. Deep sea storage
  • 2.2.2. Cap layer
  • 2.2.2.1. Storage capacity of shale caprock
  • 2.2.2.2. Pathways for CO2 leakage
  • 2.3. The concept and nature of groundwater
  • 2.3.1. Groundwater definition
  • 2.3.2. Classification of underground water
  • 2.3.2.1. Differences in the origin of water
  • 2.3.2.2. Differences in the degree of salinity
  • 2.3.2.3. Differences in types of aquifers
  • 2.3.2.4. Differences in burial conditions
  • 2.3.3. The chemical properties and influencing factors of groundwater
  • 2.4. Summary
  • References
  • Chapter 3: Numerical methods and codes used in CCUS simulation and optimization
  • 3.1. Introduction
  • 3.2. TOUGH2
  • 3.3. Governing equations for underground multiphase fluid dynamics
  • 3.3.1. Mass equation
  • 3.3.2. Energy equation
  • 3.3.3. Relative permeability and capillary pressure models
  • 3.4. Numerical method: Integral finite difference scheme
  • 3.5. Genetic algorithm and GA-TOUGH2
  • 3.6. Summary
  • References
  • Chapter 4: Geological sequestration of CO2 in deep saline aquifers
  • 4.1. Basic physics, characteristics, and parameters
  • 4.1.1. Basic physics
  • 4.1.2. Characteristics
  • 4.1.2.1. Structural and stratigraphic trapping
  • 4.1.2.2. Residual trapping
  • 4.1.2.3. Solubility trapping
  • 4.1.2.4. Mineral trapping
  • 4.1.3. Parameters
  • 4.2. Review of numerical and experimental studies.
  • 4.3. Benchmark cases and simulations
  • 4.3.1. Simulation of benchmark problem #1-CO2 plume evolution and leakage through an abandoned well
  • 4.3.2. Simulation of benchmark problem #2-Enhanced CH4 recovery in combination with CO2 sequestration in depleted gas res ...
  • 4.3.3. Simulation of benchmark problem #3-CO2 injection in a heterogeneous geological formation
  • 4.3.4. Conclusions from benchmark simulations
  • 4.4. Modeling and numerical simulation of CO2 sequestration in large saline aquifers
  • 4.4.1. SAGCS simulation for Mt. Simon formation
  • 4.4.2. SAGCS simulation for Utsira formation
  • 4.4.2.1. Model #1-Generalized stratified model of Utsira formation
  • 4.4.2.2. Model #2-Detailed three-dimensional model of the Utsira layer #9 formation
  • 4.5. Optimization strategies for CO2 sequestration in saline aquifers
  • 4.5.1. Optimization of CO2 dissolution for constant gas injection rate: Validation of GA-TOUGH2 against the brute-force a ...
  • 4.5.2. Optimization of CO2 plume migration for water-alternating-gas injection scheme
  • 4.5.3. Optimal pressure management
  • 4.5.4. Performance optimization of a multiwell system
  • 4.5.4.1. The four-well injection system
  • 4.6. Summary and future outlook
  • References
  • Chapter 5: CO2 sequestration in basaltic reservoir
  • 5.1. Igneous rocks and its potential for CO2 storage
  • 5.2. CO2 sequestration mechanism of basalts
  • 5.2.1. CO2 mineralization
  • 5.2.1.1. Experimental and numerical studies
  • 5.2.1.2. CO2 storage capacity
  • 5.3. Alumina-silicate minerals dissolution and precipitation
  • 5.3.1. Dissolution and precipitation
  • 5.3.2. Impact on injectivity
  • 5.3.3. Impact of injectivity on CO2 storage security
  • 5.4. Demonstration project of CCS in basalt
  • 5.4.1. Wallula project
  • 5.4.2. Carbfix project
  • 5.4.2.1. Carbfix1
  • 5.4.2.2. Carbfix2
  • 5.4.3. Other projects.
  • 5.5. Numerical simulation examples of CO2 sequestration in basalt
  • 5.5.1. Introduction
  • 5.5.2. Materials and methods
  • 5.5.2.1. Simulation code and the governing equations
  • 5.5.2.2. Benchmark model establishment
  • 5.5.2.3. Upscaling of the field-scale model
  • 5.5.2.4. Simulations with different hydrogeological conditions
  • 5.5.3. Results and discussion
  • 5.5.3.1. Validation of the benchmark model
  • 5.5.3.2. Mineral carbonation in the field-scale model
  • 5.5.3.3. CO2 transport at the field-scale
  • 5.5.3.4. Role of fluid transport in mineral carbonation
  • 5.6. Summary, challenges, and prospects
  • 5.6.1. Summary
  • 5.6.2. Challenges and prospects
  • References
  • Chapter 6: CO2 enhanced oil recovery (CO2-EOR)
  • 6.1. Basic physics, characteristics, and parameters
  • 6.1.1. Physical parameters of tight oil reservoirs
  • 6.1.2. Carbon dioxide gas diffusion mechanism
  • 6.2. Review of numerical and experimental studies
  • 6.3. Modeling and numerical simulation of CO2 sequestration with EOR
  • 6.4. Optimization strategies for CO2 sequestration with EOR
  • 6.4.1. Simulation and optimization of a benchmark problem
  • 6.4.1.1. Optimization of recovery factor for a constant injection rate
  • 6.4.1.2. Optimization of recovery factor for a pressure-limited system
  • 6.5. Summary and future outlook
  • References
  • Chapter 7: CO2 enhanced gas recovery (CO2-EGR)
  • 7.1. Basic physics, characteristics, and parameters
  • 7.2. Review of experimental studies
  • 7.2.1. Consolidated core flooding experiments
  • 7.2.2. Unconsolidated core flooding experiments
  • 7.3. Modeling and numerical simulation of CO2 sequestration with EGR
  • 7.4. Optimization strategies for CO2 sequestration with EGR
  • 7.4.1. Example application
  • 7.4.1.1. Model development and simulation of a benchmark problem
  • 7.4.1.2. Optimization of the benchmark EGR problem.
  • Optimization of recovery factor for a constant injection rate
  • 7.4.1.3. Constant pressure injection (CPI) optimization
  • 7.5. Summary and future outlook
  • References
  • Chapter 8: CO2 enhanced geothermal system (CO2-EGS)
  • 8.1. Basic physics, characteristics, and parameters
  • 8.1.1. Basic physics
  • 8.1.2. Characteristics
  • 8.1.3. Parameters
  • 8.2. Review of numerical and experimental studies
  • 8.2.1. Changes in the mineral composition of the reservoir rock after interaction with CO2
  • 8.2.2. Changes in the structure of rock micropores after interaction with CO2
  • 8.2.3. Changes in the mechanical properties of the rock after interactions with CO2
  • 8.3. Modeling and numerical simulation of CO2 enhanced geothermal system
  • 8.3.1. Grid discretization
  • 8.3.2. Numerical simulation software
  • 8.3.2.1. Application of TOUGH2
  • 8.3.2.2. TOUGHREACT
  • 8.3.2.3. Thermal-hydraulic-chemical multifield coupling numerical model [21]
  • 8.3.3. Numerical simulation studies
  • 8.3.3.1. Simulation of mass flow characteristics and heat transfer efficiency of CO2-EGS
  • 8.3.3.2. Simulation of chemical reactions in CO2-EGS
  • 8.3.3.3. Numerical simulation of power plant based on CO2-EGS
  • 8.4. Optimization strategies for CO2 enhanced geothermal system
  • 8.4.1. Optimization of operating parameters
  • 8.4.2. Reservoir optimization
  • 8.4.3. Some guidelines for economic optimization of a power plant based on CO2-EGS
  • 8.4.4. Example application of optimization of EGS [39]
  • 8.4.4.1. Temperature profile optimization using a constant mass injection
  • 8.4.4.2. Temperature profile optimization using a constant pressure injection
  • 8.5. Summary and future work/outlook
  • References
  • Chapter 9: CO2 enhanced shale gas recovery (CO2-ESGR)
  • 9.1. Basic physics, characteristics, and parameters
  • 9.1.1. Shale
  • 9.1.2. CO2/supercritical CO2.