Fundamentals of Enhanced Oil Recovery Methods for Unconventional Oil Reservoirs (Volume 67) (Developments in Petroleum Science, Volume 67)

Description

Fundamentals of Enhanced Oil Recovery Methods for Unconventional Oil Reservoirs, Volume 67 provides important guidance on which EOR methods work in shale and tight oil reservoirs. This book helps readers learn the main fluid and rock properties of shale and tight reservoirs―which are the main target for EOR techniques―and understand the physical and chemical mechanisms for the injected EOR fluids to enhance oil recovery in shale and tight oil reservoirs. The book explains the effects of complex hydraulic fractures and natural fractures on the performance of each EOR technique. The book describes the parameters affecting obtained oil recovery by injecting different EOR methods in both the microscopic and macroscopic levels of ULR. This book also provides proxy models to associate the functionality of the improved oil recovery by injecting different EOR methods with different operating parameters, rock, and fluid properties. The book provides profesasionals working in the petroleum industry the know-how to conduct a successful project for different EOR methods in shale plays, while it also helps academics and students in understanding the basics and principles that make the performance of EOR methods so different in conventional reservoirs and unconventional formations. Cover Title-page_2020_Developments-in-Petroleum-Science Copyright_2020_Developments-in-Petroleum-Science Contents Author-s-bio_2020_Developments-in-Petroleum-Science Acknowledgments_2020_Developments-in-Petroleum-Science Chapter-1---Introduction-to-shale-and-tight-o_2020_Developments-in-Petroleum Chapter 1 - Introduction to shale and tight oil reservoirs Abstract Keywords Contents 1.1 - Introduction 1.2 - Concepts of unconventional resources 1.3 - Geological characteristics of unconventional liquid-rich reservoirs 1.4 - The necessity of IOR for unconventional oil reservoirs 1.5 - Possible IOR methods in unconventional reservoirs 1.5.1 - EOR methods and their applicability 1.5.2 - Injectivity problems 1.5.3 - Conformance problems for IOR methods in unconventional reservoirs 1.6 - Summary References Chapter-2---CO2-EOR-in-shale-oil-reservoirs-based_2020_Developments-in-Petro Chapter 2 - CO2-EOR in shale-oil reservoirs based on a laboratory database Abstract Keywords Contents Nomenclature 2.1 - CO2-EOR in unconventional reservoirs 2.2 - CO2-EOR mechanisms 2.3 - Rock and fluid properties of unconventional plays 2.4 - Dataset for laboratory CO2-EOR projects 2.5 - Data analysis results and discussions 2.5.1 - Effect of formation permeability on oil recovery obtained by CO2 injection 2.5.2 - Effect of total organic carbon content on oil recovery obtained by CO2 injection 2.5.3 - Effect of matrix porosity on oil recovery obtained by CO2 injection 2.5.4 - Effect of mean pore throat radius on oil recovery obtained by CO2 injection 2.5.5 - Effect of oil saturation on oil recovery obtained by CO2 injection 2.5.6 - Effect of water saturation on oil recovery obtained by CO2 injection 2.5.7 - Effect of exposure time on oil recovery obtained by CO2 injection 2.5.8 - Effect of core-sample bulk volume on oil recovery obtained by CO2 injection 2.5.9 - Effect of pressure and temperature on oil recovery obtained by CO2 injection 2.5.10 - Sensitivity analysis 2.6 - Summary References Chapter-3---Comparative-analysis-between-CO2-EOR-mechan_2020_Developments-in Chapter 3 - Comparative analysis between CO2-EOR mechanisms in conventional reservoirs versus shale and tight reservoirs Abstract Keywords Contents 3.1 - Introduction 3.2 - Production data analysis (PDA) for CO2-EOR in conventional reservoirs 3.2.1 - CO2-EOR huff-n-puff projects in conventional reservoirs 3.2.2 - History matching for CO2-EOR in conventional reservoirs 3.3 - CO2-EOR huff-n-puff operations in conventional reservoirs versus unconventional reservoirs 3.4 - Production data analysis for CO2-EOR in unconventional reservoirs 3.4.1 - CO2-EOR experiments in unconventional reservoirs 3.4.2 - History matching with the experimental results of the shale-core samples 3.4.3 - CO2-EOR huff-n-puff pilot test in the Bakken formation 3.4.4 - Reservoir modeling 3.4.5 - History matching for the CO2-EOR huff-n-puff pilot test in the Bakken formation 3.5 - Summary References Chapter-4---Natural-gas-based-EOR-versus-CO2-EOR-i_2020_Developments-in-Petr Chapter 4 - Natural gas-based EOR versus CO2-EOR in shale and tight oil reservoirs Abstract Keywords Contents 4.1 - Introduction 4.2 - Experimental setups of miscible gas-based EOR 4.3 - Simulation models of miscible gas-based EOR 4.4 - Performance of natural gas EOR in pilot projects 4.5 - Performance of CO2-EOR in pilot projects 4.6 - Lessons learned from miscible gas injection pilots 4.7 - Summary References Chapter-5---Air-injection-in-shale-and-tight-_2020_Developments-in-Petroleum Chapter 5 - Air injection in shale and tight oil reservoirs Abstract Keywords Contents 5.1 - Introduction 5.2 - Types of air combustion 5.2.1 - Dry forward combustion 5.2.2 - Wet forward combustion 5.2.3 - Reverse combustion 5.3 - Modes of combustion reactions 5.3.1 - Oxygen addition 5.3.2 - Low-temperature oxidation or bond scission 5.3.3 - Spontaneous combustion or high-temperature oxidation 5.4 - Air injection EOR modeling 5.5 - Performance of air injection in conventional reservoirs 5.6 - Advantages and disadvantages of air injection 5.7 - Performance of air injection in unconventional reservoirs 5.8 - Air injection pilots in tight oil reservoirs 5.9 - Pros and cons of applying air injection in shale-oil reservoirs 5.10 - Numerical simulation for air injection in unconventional reservoirs 5.11 - Summary References Chapter-6---Water-injection-in-unconventional_2020_Developments-in-Petroleum Chapter 6 - Water injection in unconventional reservoirs Abstract Keywords Contents 6.1 - Introduction 6.2 - Oil recovery due to waterflooding 6.3 - Factors impacting the performance of waterflooding 6.4 - Waterflooding-derived techniques 6.4.1 - Low-salinity water injection 6.4.2 - Carbonated water injection 6.5 - Water injection in unconventional reservoirs 6.6 - EOR mechanisms for water injection in unconventional reservoirs 6.7 - Smart water injection for shale-oil reservoirs 6.8 - Comparison of water injection in huff-n-puff mode versus flooding mode in shale-oil reservoirs 6.9 - Factors affecting the performance of water injection in unconventional reservoirs 6.10 - Field applications for water injection in unconventional reservoirs 6.10.1 - Case study I 6.10.2 - Case study II 6.10.3 - Case study III 6.10.4 - Case study IV 6.10.5 - Case study V 6.10.6 - Case study VI 6.10.7 - Case study VII 6.10.8 - Case study VIII 6.11 - Summary References Chapter-7---Chemical-enhanced-oil-recovery-methods_2020_Developments-in-Petr Chapter 7 - Chemical enhanced oil recovery methods for unconventional reservoirs Abstract Keywords Contents 7.1 - Introduction 7.2 - Chemical EOR methods 7.3 - Surfactant types 7.4 - Surfactant huff-n-puff EOR 7.5 - Surfactant injection during hydraulic fracturing process 7.6 - Surfactant selection 7.6.1 - Introduction of surfactant selection criteria 7.6.2 - Principles of surfactant selection criteria 7.6.3 - Data compilation 7.6.4 - Functionality of oil recovery factor with CA, IFT, and capillary pressure 7.7 - Limitations of surfactant EOR for unconventional reservoirs 7.8 - Summary References Chapter-8---Selection-criteria-for-miscible-gases-base_2020_Developments-in- Chapter 8 - Selection criteria for miscible gases-based EOR in unconventional liquid-rich reservoirs (ULR) Abstract Keywords Contents 8.1 - Introduction 8.2 - Significance of molecular diffusion 8.3 - Numerical simulation setup 8.3.1 - Model selection 8.3.2 - Compositional model 8.3.3 - Systematic methodology for diffusivity level 8.4 - Results and discussion 8.4.1 - Natural depletion 8.4.2 - Flow-type determination 8.4.3 - EOR stage for Bakken model 8.5 - Closing remarks 8.6 - Summary References Chapter-9---Other-enhanced-oil-recovery-methods-f_2020_Developments-in-Petro Chapter 9 - Other enhanced oil recovery methods for unconventional reservoirs Abstract Keywords Contents 9.1 - Thermal enhanced oil recovery (EOR) techniques 9.2 - Electromagnetic EOR techniques for shale oil reservoirs 9.3 - Microbial EOR 9.3.1 - Introduction of microbial EOR 9.3.2 - Mechanisms of microbial EOR (MEOR) 9.3.3 - Field applications of microbial EOR 9.3.4 - Pros and cons of microbial EOR 9.4 - Air-foam injection 9.5 - Energized fluids for EOR 9.6 - Other EOR methods 9.6.1 - CO2 huff-n-puff followed by surfactant assist spontaneous imbibition (SASI) technique 9.6.2 - Chemical blend-based EOR for tight and shale oil reservoirs 9.6.3 - Fracturing improved oil recovery (IOR) techniques 9.7 - Summary References Chapter-10---The-effects-of-nanopore-confinement-on-_2020_Developments-in-Pe Chapter 10 - The effects of nanopore confinement on different enhanced oil recovery methods Abstract Keywords Contents 10.1 - Introduction 10.2 - Effect of pore confinement on primary production 10.3 - Effect of pore confinement on enhanced oil recovery methods 10.3.1 - Effect of nanopore confinement on air injection performance 10.3.2 - Effect of nanopore confinement on CO2-EOR performance 10.3.2.1 - Identification of flow type in shale oil reservoirs 10.3.2.2 - Effect of nanopore confinement on minimum miscible pressure 10.3.3 - Effect of nanopore confinement on natural gas-based EOR 10.3.4 - Effect of nanopore confinement on N2-EOR 10.4 - Summary References Chapter-11---The-impacts-of-geomechanics-coupl_2020_Developments-in-Petroleu Chapter 11 - The impacts of geomechanics coupling on CO2-EOR Abstract Keywords Contents 11.1 - Theory 11.1.1 - Flow type in unconventional liquid-rich reservoirs 11.1.2 - Molecular diffusion 11.1.3 - Dissolution 11.1.4 - Multicomponent adsorption 11.1.5 - Coupling between the geomechanics module and the reservoir flow model 11.2 - Compositional models for the formation fluids 11.3 - Reservoir modeling 11.4 - Results and discussion 11.4.1 - Molecular diffusion effect 11.4.2 - Adsorption effect 11.4.3 - Dissolution effect (water solubility effect) 11.4.4 - Geomechanic coupling effects 11.5 - Summary References Chapter-12---Comparative-and-optimization-of-CO2-_2020_Developments-in-Petro Chapter 12 - Comparative and optimization of CO2 and natural gas EOR methods Abstract Keywords Contents 12.1 - Reservoir modeling 12.2 - Sensitivity analysis 12.3 - Results and discussion 12.3.1 - Parameters which control CO2-EOR 12.3.2 - Parameters control NG-EOR 12.3.3 - Comparison between CO2-EOR and NGs-EOR 12.4 - Summary References Index_2020_Developments-in-Petroleum-Science Back_cover