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.