Hybrid enhanced oil recovery processes for heavy oil reservoirs /

Detalles Bibliográficos
Clasificación:Libro Electrónico
Autor principal: Dong, Xiaohu
Otros Autores: Liu, Huiqing, Chen, Zhangxin
Formato: Electrónico eBook
Idioma:Inglés
Publicado: Amsterdam : Elsevier, 2021.
Colección:Developments in Petroleum Science ; v. 73
Temas:
Enhanced oil recovery.
P�etrole > R�ecup�eration assist�ee.
Enhanced oil recovery
Acceso en línea:Texto completo
Tabla de Contenidos:
  • Front Cover
  • Hybrid Enhanced Oil Recovery Processes for Heavy Oil Reservoirs
  • Hybrid Enhanced Oil Recovery Processes for Heavy Oil Reservoirs
  • Copyright
  • Contents
  • 1
  • Introduction to hybrid enhanced oil recovery processes
  • 1.1 Introduction to heavy oil and oil sands reservoirs
  • 1.1.1 Distribution of heavy oil resources
  • 1.1.2 Characteristics of heavy crude oil
  • 1.1.3 New classification of heavy oil reservoirs
  • 1.2 Steam-based recovery processes
  • 1.2.1 Cyclic steam stimulation (huff n' puff)
  • 1.2.2 Steam flooding (steam drive)
  • 1.2.3 Steam-assisted gravity drainage
  • 1.3 Concepts of hybrid enhanced oil recovery processes
  • 1.4 Multicomponent and multiphase fluids
  • 1.5 Hybrid thermo-solvent processes
  • 1.5.1 Liquid addition to steam for enhancing recovery
  • 1.5.2 Solvent enhanced steam flooding
  • 1.5.3 Expanding solvent-steam-assisted gravity drainage
  • 1.5.4 Steam-alternating solvent
  • 1.6 Hybrid thermal-noncondensable gas processes
  • 1.6.1 Noncondensable gas-cyclic steam stimulation processes
  • 1.6.2 Hybrid steam-noncondensable gas process as poststeam flooding process
  • 1.6.3 Noncondensable gas-steam-assisted gravity drainage process
  • 1.7 Hybrid thermochemical processes
  • 1.7.1 Noncondensable gas-foam
  • 1.7.2 High-temperature gel
  • 1.7.3 Surfactant assisted-steam-assisted gravity drainage
  • 1.7.4 Chemical additive and foam-assisted steam-assisted gravity drainage
  • 1.8 Field implementation of hybrid enhanced oil recovery processes
  • 1.8.1 Field tests of hybrid thermo-solvent processes
  • 1.8.1.1 Liquid addition to steam for enhancing recovery process
  • 1.8.1.2 Expanding solvent-steam-assisted gravity drainage process
  • 1.8.2 Field tests of hybrid thermal-noncondensable gas processes
  • 1.8.2.1 N2-cyclic steam stimulation process.
  • 1.8.2.2 Flue gas/multiple thermal fluids-cyclic steam stimulation process
  • 1.8.3 Field tests of hybrid thermochemical processes
  • 1.8.31 Noncondensable gas-foam process
  • 1.8.3.2 High-temperature gel process
  • 1.8.3.3 New hybrid thermochemical processes
  • References
  • 2
  • Existing problems for steam-based enhanced oil recovery processes in heavy oil reservoirs
  • 2.1 Current status of steam-based enhanced oil recovery processes
  • 2.2 Steam overlap
  • 2.2.1 Characteristics of steam overlap
  • 2.1.1.1 Linear displacement process of steam injection
  • 2.1.1.2 Radial displacement process of steam injection
  • 2.2.2 Experimental test of steam overlap
  • 2.2.2.1 Experimental method
  • 2.2.2.2 Experimental results
  • 2.3 Steam breakthrough
  • 2.3.1 Characteristics of steam breakthrough
  • 2.3.2 Mechanisms of steam breakthrough
  • 2.3.3 Volume and strength of steam breakthrough
  • 2.3.3.1 Volume of steam breakthrough
  • 2.3.3.2 Permeability of steam breakthrough path
  • 2.4 Fine migration
  • 2.4.1 Introduction of fine migration in steam injection process
  • 2.4.1.1 Source of solid particles
  • 2.4.1.2 Fine migration by mechanical interaction
  • 2.4.1.3 Fine migration by chemical reactions
  • 2.4.2 Experimental tests of fine migration
  • 2.4.2.1 Experimental method
  • 2.4.2.2 Experimental results
  • 2.5 Mineral dissolution and transformation
  • 2.5.1 Characteristics of mineral dissolution and transformation
  • 2.5.1.1 Mechanisms of mineral transformation
  • 2.5.1.2 Mechanisms of rock-condensate reactions
  • 2.5.1.2.1 Kaolinite
  • 2.5.1.2.2 Montmorillonite
  • 2.5.1.2.3 Carbonate minerals
  • 2.5.1.2.4 Fine quartz
  • 2.5.1.3 Mechanisms of formation damage caused by mineral transformation
  • 2.5.1.3.1 Permeability reduction caused by mineral dissolution and precipitation
  • 2.5.1.3.2 Serious fine migration caused by mineral transformation.
  • 2.5.2 Experimental tests of mineral dissolution and transformation
  • 2.5.2.1 Dissolution of quartz grains
  • 2.5.2.2 Dissolution of clay minerals
  • 2.5.2.3 Dissolution of mixed fine grains
  • 2.6 Clay swelling
  • 2.6.1 Effect of clay minerals
  • 2.6.2 Mechanisms and sensitivity of clay swelling
  • 2.6.2.1 Mechanisms of clay swelling
  • 2.6.2.1.1 Surface hydration force
  • 2.6.2.1.2 Osmotic hydration force
  • 2.6.2.1.3 Capillary force
  • 2.6.2.2 Sensitive factors for clay swelling
  • 2.6.2.2.1 Effect of crystal location on a hydration film
  • 2.6.2.2.2 Effect of clay species on hydration behavior
  • 2.6.2.2.3 Effect of exchangeable cation on hydration behavior
  • 2.6.3 Migration of clay grains
  • 2.6.3.1 Critical salinity
  • 2.6.3.2 Critical flow rate
  • 2.7 Water coning
  • 2.7.1 Evaluation methods of water coning behavior
  • 2.7.1.1 Evaluation method of recovery performance
  • 2.7.1.2 Evaluation method of Hall's curve
  • 2.7.1.2.1 Theory of Hall's curve in vertical wells
  • 2.7.1.2.1.1 Theory of Hall's curve in horizontal wells
  • 2.7.1.3 Numerical simulation of water coning behavior for different heavy oil reservoirs
  • 2.7.2 Prohibition methods of water coning
  • 2.8 Other steam-rock interactions
  • 2.8.1 Asphaltene deposition
  • 2.8.2 Wettability alteration
  • 2.8.3 Emulsification
  • 2.9 Remaining oil saturation distribution
  • 2.9.1 Macroscopic distribution of remaining oil saturation
  • 2.9.2 Microscopic distribution of remaining oil saturation
  • 2.10 Discussion of enhanced oil recovery research directions
  • 2.10.1 Enhanced oil recovery research directions after cyclic steam stimulation process
  • 2.10.1.1 Improving the performance of reservoir heating
  • 2.10.1.2 Improving the performance of oil viscosity reduction
  • 2.10.2 Enhanced oil recovery research directions after steam flooding process.
  • 2.10.3 Enhanced oil recovery research directions after steam-assisted gravity drainage process
  • References
  • 3
  • Calculations of wellbore heat loss
  • 3.1 Introduction to wellbore heat loss
  • 3.1.1 Wellbore heat loss in a single-pipe wellbore configuration
  • 3.1.2 Wellbore heat loss in a dual-pipe wellbore configuration
  • 3.2 Configuration of vertical steam injection wells
  • 3.2.1 Thermal insulation pipes
  • 3.2.2 Thermal recovery packers
  • 3.2.3 N2 thermal insulation process in annulus space
  • 3.3 Configuration of horizontal steam injection wells
  • 3.3.1 Onshore horizontal wellbore configuration
  • 3.3.2 Offshore horizontal wellbore configuration
  • 3.4 Types of heat transfer
  • 3.4.1 Heat conduction
  • 3.4.2 Heat convection
  • 3.4.3 Heat radiation
  • 3.5 Wellbore heat loss models in pure steam injection processes
  • 3.5.1 Assumptions
  • 3.5.2 Pressure drop model
  • 3.5.3 Heat transfer models of single and dual-pipe well configurations
  • 3.5.3.1 Single-pipe wellbore configuration
  • 3.5.3.2 Concentric dual-pipe wellbore configuration
  • 3.5.3.3 Parallel dual-pipe wellbore configuration
  • 3.5.4 Steam quality model
  • 3.5.5 Intermediate parameters treatment
  • 3.5.5.1 Thermophysical properties of a formation
  • 3.5.5.2 Frictional resistance coefficient in gas-liquid two-phase flow
  • 3.5.5.3 Simplification of annulus flow
  • 3.5.5.4 Correlation for saturated steam
  • 3.5.6 Case study
  • 3.5.6.1 Differences among three configurations
  • 3.5.6.2 Results of concentric configuration
  • 3.5.6.3 Results in a parallel configuration
  • 3.5.7 Optimization of operation parameters
  • 3.6 Wellbore heat loss models for steam-NCG coinjection process
  • 3.6.1 Assumptions
  • 3.6.2 Models for single gas-phase flow process
  • 3.6.2.1 Pressure drop model
  • 3.6.2.2 Heat transfer model
  • 3.6.3 Models for gas-liquid two-phase flow process.
  • 3.6.3.1 Pressure drop model
  • 3.6.3.2 Steam quality model
  • 3.6.3.3 Heat transfer model
  • 3.6.4 Intermediate parameters treatment
  • 3.6.4.1 Density of a fluid mixture
  • 3.6.4.2 Viscosity of a fluid mixture
  • 3.6.5 Case study
  • 3.6.6 Optimization of operation parameters
  • 3.7 Wellbore heat loss models for offshore wellbore configurations
  • 3.7.1 Model development
  • 3.7.2 Case study
  • 3.7.2.1 Pure (saturated) steam injection process
  • 3.7.2.2 Steam-NCG coinjection process
  • 3.8 Discussion on wellbore heat loss
  • References
  • 4
  • Heat and mass transfer behavior between wellbores and reservoirs
  • 4.1 Flow behavior of heavy oil in porous media
  • 4.1.1 Introduction to heavy oil properties in porous media
  • 4.1.2 Experimental tests on heavy oil flow behavior in porous media
  • 4.1.2.1 Experimental method
  • 4.1.2.2 Experimental results
  • 4.2 New productivity models for thermal wells
  • 4.2.1 Productivity model for vertical wells
  • 4.2.2 Productivity model for horizontal wells
  • 4.2.3 Evaluation on productivity of thermal wells
  • 4.3 Experimental tests for steam conformance along wellbores
  • 4.3.1 Experimental method
  • 4.3.2 Experimental results
  • 4.3.2.1 General behavior of hot fluids flow along a wellbore
  • 4.3.2.2 Effect of well configuration
  • 4.3.2.3 Effect of hot fluid type
  • 4.4 Mathematical models for pure steam injection processes
  • 4.4.1 Assumptions
  • 4.4.2 Model development
  • 4.4.2.1 Mass conservation equation
  • 4.4.2.2 Momentum conservation equation:
  • 4.4.2.3 Energy conservation equation
  • 4.4.2.4 Treatment of intermediate parameters
  • 4.4.2.4.1 Radial heat transfer behavior
  • 4.4.2.4.2 Equation of steam flow in reservoirs
  • 4.4.2.4.3 Constraints for steam mass flow along wellbores
  • 4.4.3 Simulation procedure
  • 4.4.4 Case study
  • 4.4.4.1 Laboratory-scale simulation
  • 4.4.4.2 Field-scale simulation.

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