Confined Fluid Phase Behavior and CO2 Sequestration in Shale Reservoirs delivers the calculation components to understand pore structure and absorption capacity involving unconventional reservoirs. Packed with experimental procedures, step-by-step instructions, and published data, the reference explains measurements for capillary pressure models, absorption behavior in double nano-pore systems, and the modeling of interfacial tension in C02/CH4/brine systems. Rounding out with conclusions and additional literature, this reference gives petroleum engineers and researchers the knowledge to maximize productivity in shale reservoirs.
Author(s): Yueliang Liu, Zhenhua Rui
Publisher: Gulf Professional Publishing
Year: 2022
Language: English
Pages: 245
City: Cambridge
Front Cover
Confined Fluid Phase Behavior and CO2 Sequestration in Shale Reservoirs
Copyright
Contents
About the author
Preface
Acknowledgments
Chapter 1: Introduction
1.1. Confined fluid-phase behavior in nanopores
1.2. Adsorption behavior of pure hydrocarbons on shale
1.3. Phase behavior of gas mixtures considering competitive adsorption effect
1.4. Interfacial tension of CO2/CH4/brine system under reservoir conditions
References
Chapter 2: Confined fluid-phase behavior in shale
2.1. Comparison of Peng-Robinson EOS with capillary pressure model with engineering density functional theory in describi ...
2.1.1. Molecular model and theory
2.1.1.1. Engineering density functional theory
2.1.1.2. PR-EOS with capillary pressure model
2.1.2. Dew-point calculation
2.1.3. Critical properties of pure components
2.1.4. Phase behavior and critical properties of confined pure nC8
2.1.5. Phase behavior of confined C1-nC6 mixture
2.2. Phase behavior of N2/n-C4H10 in a partially confined space from shale
2.2.1. Measurement of the P/V isotherms in confined shale
2.2.2. Characterization of shale samples
2.2.3. Phase behavior of N2/n-C4H10 mixtures in the partially confined space
2.2.4. Sorption of individual components on shale samples
2.2.5. Effect of TOC on sorption capacity
References
Chapter 3: Adsorption behavior of reservoir fluids and CO2 in shale
3.1. Competitive adsorption behavior of hydrocarbons and hydrocarbon/CO2 mixtures in porous media from molecular perspective
3.1.1. Methodology and simulation model
3.1.1.1. Molecular dynamic simulation
3.1.1.2. Simulation model
3.1.2. Adsorption behavior of mixtures in the double-nanopore system
3.1.3. Adsorption selectivity of species in organic pores
3.1.4. Replacement of C1 and nC4 from nanopores with CO2 injection
3.2. Determination of the absolute adsorption/desorption isotherms of CH4 and n-C4H10 on shale from a nanoscale perspective
3.2.1. Characterization of shale sample
3.2.2. Excess and absolute adsorption/desorption
3.2.3. Grand canonical Monte Carlo (GCMC) simulations
3.2.4. Density distributions in nanopores
3.2.4.1. Effect of system pressure
3.2.4.2. Effect of system temperature
3.2.4.3. Effect of pore size
3.2.4.4. Identification of the adsorption phase
3.2.5. Average density of the adsorption phase
3.2.6. Absolute adsorption/desorption isotherms
3.2.7. Comparison of GCMC-based approach with conventional approach
3.3. Absolute adsorption of CH4 on shale with the simplified local density theory
3.3.1. Characterization of the four shale samples
3.3.2. Simplified local density (SLD) theory
3.3.3. Density distributions of CH4 in nanopores
3.3.4. Adsorbed CH4 density in nanopores
3.3.5. Validation of the SLD model
3.3.6. Absolute adsorption isotherms of CH4 obtained from SLD model
3.4. Determination of the absolute adsorption isotherms of CH4 on shale with low-field nuclear magnetic resonance
3.4.1. Characterization of the shale samples
3.4.2. Measurements of the excess adsorption of CH4 on shale samples
3.4.3. Absolute adsorption of CH4 on shale samples
3.4.4. NMR test of CH4s adsorption on shale samples
3.4.5. Nuclear magnetic resonance (NMR) technique
3.4.6. Grand canonical Monte Carlo (GCMC) simulations
3.4.7. Excess and absolute adsorption isotherms of CH4 on shale
3.4.7.1. Excess adsorption isotherms
3.4.7.2. Adsorption-phase density
3.4.7.3. Absolute adsorption isotherms
3.4.8. T2 spectrum of CH4 in shale samples
3.4.9. Comparison of the absolute adsorption isotherms from two approaches
Appendix 1: Position-dependent equation of state parameter [aads(z)]
Appendix 2: Density profile comparison between the SLD model and GCMC simulations
References
Chapter 4: Interfacial tension for CO2/CH4/brine systems under reservoir conditions
4.1. ADSA IFT apparatus
4.2. Mathematical formulation
4.3. Effect of pressure, temperature and salinity on IFT
4.4. Effect of CO2 concentration on IFT
4.5. IFT modeling for CO2/CH4/H2O and CO2/CH4/brine systems
4.5.1. Improved IFT model for CO2/CH4/H2O systems
4.5.2. Comparison with existing correlations
4.5.3. Validation of the improved model
4.5.4. IFT modeling for CO2/CH4/brine systems
References
Chapter 5: Oil/gas recovery and CO2 sequestration in shale
5.1. Selective adsorption of CO2/CH4 mixture on clay-rich shale using molecular simulations
5.1.1. Molecular clay-mineral models
5.1.2. Force field parameters
5.1.3. Simulation details
5.1.4. Validation of the GCMC method
5.1.5. CH4/CO2 adsorption on clay minerals
5.1.5.1. Effect of system pressure
5.1.5.2. Effect of system temperature
5.1.5.3. Effect of pore size
5.1.6. Implications for CH4 recovery and CO2 sequestration
5.2. Comparing the effectiveness of SO2 with CO2 for replacing hydrocarbons from nanopores
5.2.1. Molecular dynamics
5.2.2. Simulation model
5.2.3. Comparison of the influence of CO2 with SO2 on fluid distribution of hydrocarbons in nanopore
5.2.4. Adsorption selectivity of CO2 and SO2 over different hydrocarbon-species
5.2.5. Replacement efficiency of CO2 and SO2 on different hydrocarbon-species
References
Chapter 6: Summary and commendations
6.1. Summary of this book
6.2. Suggested future work
Index
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