Basic Reservoir Engineering

ISBN-13: 9781465236845 / Angielski / Miękka / 2013 / 340 str.

Gates

Spis treści

• 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