Basic Reservoir Engineering
Edition: 1
Copyright: 2011
Pages: 340
Edition: 1
Copyright: 2011
Pages: 342
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Basic Reservoir Engineering, written for use in a first introductory one-semester course in reservoir engineering, introduces the underlying goals of reservoir engineering and presents a clear roadmap for analyzing reservoirs themselves.
Basic Reservoir Engineering:
- Includes chapter review questions to help students understand, practice, and retain the information presented.
- Includes a glossary that enlightens the student to much of the jargon found in the oil and gas industry.
Chapter 1 introduces the reader to the field of reservoir engineering.
Chapter 2 presents basic reservoir concepts dealing with flow through porous media including porosity, permeability, saturation, relative permeability, capillary pressure, hysteresis, and resistivity theory.
Chapter 3 deals with basic pressure-volume-temperature behaviour concepts for petroleum fluids.
Chapter 4 introduces mapping and volumetric calculations.
Chapter 5 describes decline analysis and the construction of type curves.
Chapters 6 outlines the material balance method for oil
Chapter 7 outlines the material balance method for gas systems.
Chapter 8 describes water aquifer models.
Chapter 9 describes some basic models for describing oil production including displacement theory.
Chapter 10 describes buildup and drawdown theory.
Chapter 11 introduces analysis of thermal processes including cyclic steam stimulation and steam-assisted gravity drainage.
Chapter 12 describes basic data requirements and theory of reservoir simulation.
PREFACE
CHAPTER 1 INTRODUCTION
1.1 FORCES THAT MOVE FLUIDS IN RESERVOIRS
1.2 PRODUCTION STRATEGIES
1.3 PROBLEM STATEMENT
1.4 TYPES OF RESERVOIRS
1.5 ROADMAP
1.5 PRACTICE PROBLEMS
1.6 REFERENCES
CHAPTER 2 FUNDAMENTAL RESERVOIR CONCEPTS
2.1 PORE VOLUME
2.2 POROSITY
2.2.1 Effect of Compaction on Porosity
2.3 SPECIFIC SURFACE
2.4 WATER SATURATION
2.5 OIL SATURATION
2.6 GAS SATURATION
2.7 CONVERSION OF SATURATIONS TO MASS
2.8 PERMEABILITY AND DARCY'S LAW
2.8.1 Measurement of Permeability
2.8.2 Klinkenberg Effect
2.8.3 Extensions of Darcy's Law: Brinkman's Equation
2.8.4 Extensions of Darcy's Law: Forchheimer's Equation
2.8.5 Vertical and Horizontal Permeability
2.9 POROSITY - PERMEABILITY RELATIONSHIP
2.10 WETTABILITY
2.11 RELATIVE PERMEABILITY
2.11.1 Relative Permeability Ratio
2.11.2 Fractional Flow to Water (Watercut)
2.11.3 Maximum Recoverable Oil
2.11.4 Mobility Ratio
2.11.5 Corey's Equations
2.11.6 Empirical Estimates for Relative Permeability Curves
2.11.7 Three-Phase Relative Permeability
2.11.8 Stone's Models for Three-Phase Relative Permeability
2.11.9 Baker's Model for Three-Phase Relative Permeability
2.12 CAPILLARY PRESSURE
2.12.1 Leverett J Function
2.13 HYSTERESIS OF RELATIVE PERMEABILITY AND CAPILLARY PRESSURE
2.14 ROCK COMPRESSIBILITY
2.15 BASIC RESISTIVITY THEORY
2.15.1 Formation Resistivity Factor and Porosity
2.15.2 Water Saturation
2.16 AVERAGE PROPERTIES
2.17 REFERENCES
2.18 PRACTICE PROBLEMS
CHAPTER 3 PRESSURE-VOLUME-TEMPERATURE (PVT) BEHAVIOUR
3.1 GAS BEHAVIOUR
3.1.1 Real Gas Behaviour
3.1.3 Equations of State
3.2 LIQUIDS
3.3 SINGLE-COMPONENT PRESSURE-TEMPERATURE (P-T) PHASE DIAGRAM
3.3.1 Pressure and Temperature versus Specific Volume
3.4 TWO-COMPONENT P-T PHASE DIAGRAM
3.5 MULTIPLE-COMPONENT P-T PHASE DIAGRAM
3.6 EFFECT OF COMPOSITION
3.7 RETROGRADE BEHAVIOUR
3.8 GAS FIELD DEPLETION
3.9 PRODUCTION OF GAS FROM RESERVOIR TO SURFACE
3.10 PRODUCTION OF OIL FROM RESERVOIR TO SURFACE
3.11 PRODUCTION OF GAS-CONDENSATE FROM RESERVOIR TO SURFACE
3.12 PRODUCTION OF RETROGRADE CONDENSATE FROM RESERVOIR TO SURFACE
3.13 SOLUTION GAS-TO-OIL RATIO AND FORMATION VOLUME FACTORS
3.13.1 Oil Formation Volume Factor
3.13.2 Gas Formation Volume Factor
3.14 FLASH AND DIFFERENTIAL LIBERATION TESTS
3.14.1 Flash Expansion
3.14.2 Differential Liberation
3.15 CALCULATION OF VAPOUR-LIQUID EQUILIBRIUM
3.15.1 Raoult's Law
3.15.2 Henry's Law
3.15.3 Simpler Correlations
3.15.4 Flash (Phase Split) Calculations
3.16 REFERENCES
3.17 PRACTICE PROBLEMS
CHAPTER 4 MAPPING, RESERVES, AND VOLUMETRICS
4.1 MAPPING
4.1.1 Gross Pay Map
4.1.2 Net Pay Map
4.1.3 Porosity-Pay Map
4.1.4 Permeability-Pay Map
4.1.5 Porosity-Oil Saturation-Pay Map
4.1.6 Isobaric Map
4.1.7 Isopach Maps
4.1.8 Isolith Maps
4.1.9 Bubble Map
4.1.10 Structure Map
4.1.11 Topographic Map
4.1.12 Cross-sections
4.1.13 Net-to-Gross Ratio Maps
4.2 RESERVES
4.3 VOLUMETRICS
4.4 REFERENCES
4.5 PRACTICE PROBLEMS
CHAPTER 5 DECLINE ANALYSIS
5.1 ARPS' DECLINE MODEL
5.1.1 Exponential Decline
5.1.2 Hyperbolic Decline
5.1.3 Harmonic Decline
5.2 MODIFIED DECLINE MODELS
5.3 PRODUCTION RATE - CUMULATIVE PRODUCTION PLOTS
5.4 DERIVATIVE ANALYSIS
5.5 TYPE CURVES FROM FIELD DATA
5.6 REFERENCES
5.7 PRACTICE PROBLEMS
CHAPTER 6 MATERIAL BALANCES FOR OIL RESERVOIRS
6.1 SOLUTION GAS DRIVE RESERVOIR
6.1.1 Above the Bubble Point Line (Undersaturated Oil Reservoir)
6.1.2 Below the Bubble Point Line (Saturated Oil Reservoir with Free Gas)
6.2 GAS CAP DRIVE RESERVOIR
6.3 NATURAL WATER DRIVE (UNDERSATURATED OIL) RESERVOIR
6.4 COMBINATION DRIVE RESERVOIRS
6.5 REFERENCES
6.6 PRACTICE PROBLEMS
CHAPTER 7 MATERIAL BALANCES FOR GAS RESERVOIRS
7.1 GAS DEPLETION RESERVOIRS
7.2 WATER DRIVE RESERVOIRS
7.3 CALCULATION OF P FROM P/Z
7.4 HIGH PRESSURE GAS RESERVOIRS
7.5 REFERENCES
7.6 PRACTICE PROBLEMS
CHAPTER 8 WATER AQUIFER MODELS
8.1 HURST AND VAN EVERDINGEN MODEL
8.2 PRESSURE CHANGES AT THE RESERVOIR - AQUIFER BOUNDARY
8.3 FETKOVITCH WATER INFLUX THEORY
8.4 CARTER-TRACY AQUIFER THEORY
8.5 APPLICATION
8.5.1 Hurst and van Everdingen Method
8.5.2 Fetkovitch Method
8.6 REFERENCES
8.7 PRACTICE PROBLEMS
CHAPTER 9 OIL ANALYTICAL MODELS
9.1 SOLUTION-GAS DRIVE RESERVOIRS
9.1.1 Schilthuis' Method
9.1.2 Tarner's Method
9.1.3 Tracy's Method
9.1.4 Muskat and Taylor's Method
9.1.5 Rate-Time Forecast
9.2 WATERFLOODING
9.2.1 Oil Displacement by Water
9.2.2 Buckley and Leverett Displacement Theory
9.4 REFERENCES
9.5 PRACTICE PROBLEMS
CHAPTER 10 BASIC WELL TEST ANALYSIS
10.1 SINGLE-WELL TESTS
10.2 MULTI-WELL TEST
10.3 PRESSURE BUILDUP THEORY
10.3.1 Infinite Reservoir (with line source well)
10.3.2 Bounded Cylindrical Reservoir
10.3.3 Constant Pressure at the Outer Boundary
10.3.4 Semi-Steady State Flow
10.4 PRINCIPLE OF SUPERPOSITION
10.5 PRESSURE BUILDUP ANALYSIS: SINGLE PHASE FLOW IN INFINITE RESERVOIR
10.6 WELLBORE FILLUP
10.7 SKIN
10.8 PRESSURE BUILDUP ANALYSIS: SINGLE PHASE FLOW IN BOUNDED, CYLINDRICAL RESERVOIR
10.9 PRESSURE BUILDUP ANALYSIS: TWO AND THREE PHASE FLOW
10.10 PRESSURE BUILDUP ANALYSIS IN GAS WELLS
10.11 DRILL STEM TESTS
10.12 PRESSURE DRAWDOWN ANALYSIS
10.13 MULTIPLE RATE FLOW TEST ANALYSIS
10.14 INTERFERENCE TESTS
10.15 AL-HUSSAINY, RAMEY, CRAWFORD METHOD FOR GAS WELL TESTING
10.15.1 Semi-Steady State Conditions
10.16 HIGH GAS FLOWS
10.17 PRESSURE ANALYSIS OF INJECTION WELLS
10.18 BEHAVIOUR IN NON-SYMMETRICAL DRAINAGE AREAS
10.19 WELL TESTING AND RESERVOIR SIMULATION
10.20 STATIC GRADIENT TEST
10.21 ACOUSTIC WELL SOUNDER
10.22 DETERMINATION OF AVERAGE RESERVOIR PRESSURE
10.23 REFERENCES
10.24 PRACTICE PROBLEMS
CHAPTER 11 INTRODUCTION TO THERMAL PROCESSES
11.1 EFFECT OF TEMPERATURE ON ROCK-FLUID PROPERTIES
11.2 STEAM INJECTION INTO A RESERVOIR: HEATED ZONE GROWTH
11.3 CYCLIC STEAM STIMULATION (CSS)
11.3.1 Analytical Models of CSS
11.4 STEAMFLOODING
11.5 STEAM-ASSISTED GRAVITY DRAINAGE (SAGD)
11.5.1 Simple Model for SAGD
11.5.2 Steam Requirements
15.5.3 Steam Trap Control
11.6 HOT WATERFLOODING
11.6.1 Heating by Hot Water Injection
11.7 REFERENCES
11.8 PRACTICE PROBLEMS
CHAPTER 12 INTRODUCTION TO RESERVOIR SIMULATION
12.1 INTRODUCTION
12.2 OBJECTIVES OF RESERVOIR SIMULATION
12.3 TYPES OF RESERVOIR SIMULATORS
12.4 BASIC EQUATIONS OF RESERVOIR SIMULATION
12.4.1 Darcy's Law
12.4.2 Single-Phase Flow
12.4.3 Multi-Phase Flow
12.4.4 Mass Transfer
12.5 ENERGY BALANCE
12.6 FLUIDS IN RESERVOIRS
12.7 EQUATIONS AND UNKNOWNS
12.8 INPUT DATA
12.9 REPRESENTATION OF WELLS
12.9.1 The R-Value (or Well Index)
12.10 RESULTS AND ANALYSIS OF RESERVOIR SIMULATION OUTPUT
12.11 HISTORY MATCHING
12.11.1 Target of History Match
12.11.2 History-Matching Parameters
12.11.3 Sequence of Operations
12.12 REFERENCES
APPENDIX A TERMINOLOGY
A.1 BRIEF GLOSSARY
A.2 UNIT CONVERSIONS
A.3 HOW TO READ A WESTERN CANADIAN MAP
A.4 ELEVATIONS
APPENDIX B FLUID PROPERTIES
B.1 WATER
B.1.1 Density
B.1.2 Thermal Conductivity
B.1.3 Heat Capacity
B.1.4 Viscosity
B.2 BRINE SOLUTIONS
B.3 STEAM
B.3.1 Saturation Pressure and Temperature
B.3.2 Specific Volume
B.3.4 Enthalpies
B.3.5 Viscosity
B.4 OIL
B.4.1 Density
B.4.2 Thermal Conductivity
B.4.3 Heat Capacity
B.4.4 Viscosity
B.5 BITUMEN
B.5.1 Density
B.5.2 Heat Capacity
B.5.3 Viscosity
B.6 RESERVOIR ROCK
B.6.1 Heat Capacity
B.7 OIL SANDS
B.7.1 Thermal Conductivity
B.8 PETROLEUM GAS
5.8.1 Compressibility, z Factor
B.8.2 Viscosity
B.8.3 Thermal Conductivity
B.8.4 Heat Capacity
B.9 REFERENCES
INDEX
Basic Reservoir Engineering, written for use in a first introductory one-semester course in reservoir engineering, introduces the underlying goals of reservoir engineering and presents a clear roadmap for analyzing reservoirs themselves.
Basic Reservoir Engineering:
- Includes chapter review questions to help students understand, practice, and retain the information presented.
- Includes a glossary that enlightens the student to much of the jargon found in the oil and gas industry.
Chapter 1 introduces the reader to the field of reservoir engineering.
Chapter 2 presents basic reservoir concepts dealing with flow through porous media including porosity, permeability, saturation, relative permeability, capillary pressure, hysteresis, and resistivity theory.
Chapter 3 deals with basic pressure-volume-temperature behaviour concepts for petroleum fluids.
Chapter 4 introduces mapping and volumetric calculations.
Chapter 5 describes decline analysis and the construction of type curves.
Chapters 6 outlines the material balance method for oil
Chapter 7 outlines the material balance method for gas systems.
Chapter 8 describes water aquifer models.
Chapter 9 describes some basic models for describing oil production including displacement theory.
Chapter 10 describes buildup and drawdown theory.
Chapter 11 introduces analysis of thermal processes including cyclic steam stimulation and steam-assisted gravity drainage.
Chapter 12 describes basic data requirements and theory of reservoir simulation.
PREFACE
CHAPTER 1 INTRODUCTION
1.1 FORCES THAT MOVE FLUIDS IN RESERVOIRS
1.2 PRODUCTION STRATEGIES
1.3 PROBLEM STATEMENT
1.4 TYPES OF RESERVOIRS
1.5 ROADMAP
1.5 PRACTICE PROBLEMS
1.6 REFERENCES
CHAPTER 2 FUNDAMENTAL RESERVOIR CONCEPTS
2.1 PORE VOLUME
2.2 POROSITY
2.2.1 Effect of Compaction on Porosity
2.3 SPECIFIC SURFACE
2.4 WATER SATURATION
2.5 OIL SATURATION
2.6 GAS SATURATION
2.7 CONVERSION OF SATURATIONS TO MASS
2.8 PERMEABILITY AND DARCY'S LAW
2.8.1 Measurement of Permeability
2.8.2 Klinkenberg Effect
2.8.3 Extensions of Darcy's Law: Brinkman's Equation
2.8.4 Extensions of Darcy's Law: Forchheimer's Equation
2.8.5 Vertical and Horizontal Permeability
2.9 POROSITY - PERMEABILITY RELATIONSHIP
2.10 WETTABILITY
2.11 RELATIVE PERMEABILITY
2.11.1 Relative Permeability Ratio
2.11.2 Fractional Flow to Water (Watercut)
2.11.3 Maximum Recoverable Oil
2.11.4 Mobility Ratio
2.11.5 Corey's Equations
2.11.6 Empirical Estimates for Relative Permeability Curves
2.11.7 Three-Phase Relative Permeability
2.11.8 Stone's Models for Three-Phase Relative Permeability
2.11.9 Baker's Model for Three-Phase Relative Permeability
2.12 CAPILLARY PRESSURE
2.12.1 Leverett J Function
2.13 HYSTERESIS OF RELATIVE PERMEABILITY AND CAPILLARY PRESSURE
2.14 ROCK COMPRESSIBILITY
2.15 BASIC RESISTIVITY THEORY
2.15.1 Formation Resistivity Factor and Porosity
2.15.2 Water Saturation
2.16 AVERAGE PROPERTIES
2.17 REFERENCES
2.18 PRACTICE PROBLEMS
CHAPTER 3 PRESSURE-VOLUME-TEMPERATURE (PVT) BEHAVIOUR
3.1 GAS BEHAVIOUR
3.1.1 Real Gas Behaviour
3.1.3 Equations of State
3.2 LIQUIDS
3.3 SINGLE-COMPONENT PRESSURE-TEMPERATURE (P-T) PHASE DIAGRAM
3.3.1 Pressure and Temperature versus Specific Volume
3.4 TWO-COMPONENT P-T PHASE DIAGRAM
3.5 MULTIPLE-COMPONENT P-T PHASE DIAGRAM
3.6 EFFECT OF COMPOSITION
3.7 RETROGRADE BEHAVIOUR
3.8 GAS FIELD DEPLETION
3.9 PRODUCTION OF GAS FROM RESERVOIR TO SURFACE
3.10 PRODUCTION OF OIL FROM RESERVOIR TO SURFACE
3.11 PRODUCTION OF GAS-CONDENSATE FROM RESERVOIR TO SURFACE
3.12 PRODUCTION OF RETROGRADE CONDENSATE FROM RESERVOIR TO SURFACE
3.13 SOLUTION GAS-TO-OIL RATIO AND FORMATION VOLUME FACTORS
3.13.1 Oil Formation Volume Factor
3.13.2 Gas Formation Volume Factor
3.14 FLASH AND DIFFERENTIAL LIBERATION TESTS
3.14.1 Flash Expansion
3.14.2 Differential Liberation
3.15 CALCULATION OF VAPOUR-LIQUID EQUILIBRIUM
3.15.1 Raoult's Law
3.15.2 Henry's Law
3.15.3 Simpler Correlations
3.15.4 Flash (Phase Split) Calculations
3.16 REFERENCES
3.17 PRACTICE PROBLEMS
CHAPTER 4 MAPPING, RESERVES, AND VOLUMETRICS
4.1 MAPPING
4.1.1 Gross Pay Map
4.1.2 Net Pay Map
4.1.3 Porosity-Pay Map
4.1.4 Permeability-Pay Map
4.1.5 Porosity-Oil Saturation-Pay Map
4.1.6 Isobaric Map
4.1.7 Isopach Maps
4.1.8 Isolith Maps
4.1.9 Bubble Map
4.1.10 Structure Map
4.1.11 Topographic Map
4.1.12 Cross-sections
4.1.13 Net-to-Gross Ratio Maps
4.2 RESERVES
4.3 VOLUMETRICS
4.4 REFERENCES
4.5 PRACTICE PROBLEMS
CHAPTER 5 DECLINE ANALYSIS
5.1 ARPS' DECLINE MODEL
5.1.1 Exponential Decline
5.1.2 Hyperbolic Decline
5.1.3 Harmonic Decline
5.2 MODIFIED DECLINE MODELS
5.3 PRODUCTION RATE - CUMULATIVE PRODUCTION PLOTS
5.4 DERIVATIVE ANALYSIS
5.5 TYPE CURVES FROM FIELD DATA
5.6 REFERENCES
5.7 PRACTICE PROBLEMS
CHAPTER 6 MATERIAL BALANCES FOR OIL RESERVOIRS
6.1 SOLUTION GAS DRIVE RESERVOIR
6.1.1 Above the Bubble Point Line (Undersaturated Oil Reservoir)
6.1.2 Below the Bubble Point Line (Saturated Oil Reservoir with Free Gas)
6.2 GAS CAP DRIVE RESERVOIR
6.3 NATURAL WATER DRIVE (UNDERSATURATED OIL) RESERVOIR
6.4 COMBINATION DRIVE RESERVOIRS
6.5 REFERENCES
6.6 PRACTICE PROBLEMS
CHAPTER 7 MATERIAL BALANCES FOR GAS RESERVOIRS
7.1 GAS DEPLETION RESERVOIRS
7.2 WATER DRIVE RESERVOIRS
7.3 CALCULATION OF P FROM P/Z
7.4 HIGH PRESSURE GAS RESERVOIRS
7.5 REFERENCES
7.6 PRACTICE PROBLEMS
CHAPTER 8 WATER AQUIFER MODELS
8.1 HURST AND VAN EVERDINGEN MODEL
8.2 PRESSURE CHANGES AT THE RESERVOIR - AQUIFER BOUNDARY
8.3 FETKOVITCH WATER INFLUX THEORY
8.4 CARTER-TRACY AQUIFER THEORY
8.5 APPLICATION
8.5.1 Hurst and van Everdingen Method
8.5.2 Fetkovitch Method
8.6 REFERENCES
8.7 PRACTICE PROBLEMS
CHAPTER 9 OIL ANALYTICAL MODELS
9.1 SOLUTION-GAS DRIVE RESERVOIRS
9.1.1 Schilthuis' Method
9.1.2 Tarner's Method
9.1.3 Tracy's Method
9.1.4 Muskat and Taylor's Method
9.1.5 Rate-Time Forecast
9.2 WATERFLOODING
9.2.1 Oil Displacement by Water
9.2.2 Buckley and Leverett Displacement Theory
9.4 REFERENCES
9.5 PRACTICE PROBLEMS
CHAPTER 10 BASIC WELL TEST ANALYSIS
10.1 SINGLE-WELL TESTS
10.2 MULTI-WELL TEST
10.3 PRESSURE BUILDUP THEORY
10.3.1 Infinite Reservoir (with line source well)
10.3.2 Bounded Cylindrical Reservoir
10.3.3 Constant Pressure at the Outer Boundary
10.3.4 Semi-Steady State Flow
10.4 PRINCIPLE OF SUPERPOSITION
10.5 PRESSURE BUILDUP ANALYSIS: SINGLE PHASE FLOW IN INFINITE RESERVOIR
10.6 WELLBORE FILLUP
10.7 SKIN
10.8 PRESSURE BUILDUP ANALYSIS: SINGLE PHASE FLOW IN BOUNDED, CYLINDRICAL RESERVOIR
10.9 PRESSURE BUILDUP ANALYSIS: TWO AND THREE PHASE FLOW
10.10 PRESSURE BUILDUP ANALYSIS IN GAS WELLS
10.11 DRILL STEM TESTS
10.12 PRESSURE DRAWDOWN ANALYSIS
10.13 MULTIPLE RATE FLOW TEST ANALYSIS
10.14 INTERFERENCE TESTS
10.15 AL-HUSSAINY, RAMEY, CRAWFORD METHOD FOR GAS WELL TESTING
10.15.1 Semi-Steady State Conditions
10.16 HIGH GAS FLOWS
10.17 PRESSURE ANALYSIS OF INJECTION WELLS
10.18 BEHAVIOUR IN NON-SYMMETRICAL DRAINAGE AREAS
10.19 WELL TESTING AND RESERVOIR SIMULATION
10.20 STATIC GRADIENT TEST
10.21 ACOUSTIC WELL SOUNDER
10.22 DETERMINATION OF AVERAGE RESERVOIR PRESSURE
10.23 REFERENCES
10.24 PRACTICE PROBLEMS
CHAPTER 11 INTRODUCTION TO THERMAL PROCESSES
11.1 EFFECT OF TEMPERATURE ON ROCK-FLUID PROPERTIES
11.2 STEAM INJECTION INTO A RESERVOIR: HEATED ZONE GROWTH
11.3 CYCLIC STEAM STIMULATION (CSS)
11.3.1 Analytical Models of CSS
11.4 STEAMFLOODING
11.5 STEAM-ASSISTED GRAVITY DRAINAGE (SAGD)
11.5.1 Simple Model for SAGD
11.5.2 Steam Requirements
15.5.3 Steam Trap Control
11.6 HOT WATERFLOODING
11.6.1 Heating by Hot Water Injection
11.7 REFERENCES
11.8 PRACTICE PROBLEMS
CHAPTER 12 INTRODUCTION TO RESERVOIR SIMULATION
12.1 INTRODUCTION
12.2 OBJECTIVES OF RESERVOIR SIMULATION
12.3 TYPES OF RESERVOIR SIMULATORS
12.4 BASIC EQUATIONS OF RESERVOIR SIMULATION
12.4.1 Darcy's Law
12.4.2 Single-Phase Flow
12.4.3 Multi-Phase Flow
12.4.4 Mass Transfer
12.5 ENERGY BALANCE
12.6 FLUIDS IN RESERVOIRS
12.7 EQUATIONS AND UNKNOWNS
12.8 INPUT DATA
12.9 REPRESENTATION OF WELLS
12.9.1 The R-Value (or Well Index)
12.10 RESULTS AND ANALYSIS OF RESERVOIR SIMULATION OUTPUT
12.11 HISTORY MATCHING
12.11.1 Target of History Match
12.11.2 History-Matching Parameters
12.11.3 Sequence of Operations
12.12 REFERENCES
APPENDIX A TERMINOLOGY
A.1 BRIEF GLOSSARY
A.2 UNIT CONVERSIONS
A.3 HOW TO READ A WESTERN CANADIAN MAP
A.4 ELEVATIONS
APPENDIX B FLUID PROPERTIES
B.1 WATER
B.1.1 Density
B.1.2 Thermal Conductivity
B.1.3 Heat Capacity
B.1.4 Viscosity
B.2 BRINE SOLUTIONS
B.3 STEAM
B.3.1 Saturation Pressure and Temperature
B.3.2 Specific Volume
B.3.4 Enthalpies
B.3.5 Viscosity
B.4 OIL
B.4.1 Density
B.4.2 Thermal Conductivity
B.4.3 Heat Capacity
B.4.4 Viscosity
B.5 BITUMEN
B.5.1 Density
B.5.2 Heat Capacity
B.5.3 Viscosity
B.6 RESERVOIR ROCK
B.6.1 Heat Capacity
B.7 OIL SANDS
B.7.1 Thermal Conductivity
B.8 PETROLEUM GAS
5.8.1 Compressibility, z Factor
B.8.2 Viscosity
B.8.3 Thermal Conductivity
B.8.4 Heat Capacity
B.9 REFERENCES
INDEX