Ahmed T. Reservoir Engineering Handbook

2nd edition. — Gulf Professional Publishing, 2001. — 1211 p.This book explains the fundamentals of reservoir engineering and their practical application in conducting a comprehensive field study. Chapter 1 reviews fundamentals of reservoir fluid behavior with an emphasis on the classification of reservoir and reservoir fluids. Chapter 2 documents reservoir-fluid properties, while Chapter 3 presents a comprehensive treatment and description of the routine and specialized PVT laboratory tests. The fundamentals of rock properties are discussed in Chapter 4 and numerous methodologies for generating those properties are reviewed. Chapter 5 focuses on presenting the concept of relative permeability and its applications in fluid flow calculations. The fundamental mathematical expressions that are used to describe the reservoir fluid flow behavior in porous media are discussed in Chapter 6, while Chapters 7 and 8 describe the principle of oil and gas well performance calculations, respectively. Chapter 9 provides the theoretical analysis of coning and outlines many of the practical solutions for calculating water and gas coning behavior. Various water influx calculation models are shown in Chapter 10, along with detailed descriptions of the computational steps involved in applying these models. The objective of Chapter 11 is to introduce the basic principle of oil recovery mechanisms and to present the generalized form of the material balance equation. Chapters 12 and 13 focus on illustrating the practical applications of the material balance equation in oil and gas reservoirs.Preface To The Second Edition
Preface To The First EditionFundamentals Of Reservoir Fluid BehaviorClassification of reservoirs and reservoir fluids
Pressure-temperature diagram
Oil reservoirs
Gas reservoirs
Undefined petroleum fractions
ProblemsReservoir-Fluid PropertiesProperties of natural gases
Behavior of ideal gases
Behavior of real gases
Effect of nonhydrocarbon components of the Z-factor
Nonhydrocarbon adjustment methods
The Wichert-Aziz correction method
Correction for high-molecular weight gases
Direct calculation of compressibility factors
Compressibility of natural gases
Gas formation volume factor
Gas viscosity
Methods of calculating the viscosity of natural gases
Properties of crude oil systems
Crude oil gravity
Specific gravity of the solution gas
Gas solubility
Bubble-point pressure
Oil formation volume factor
Isothermal compressibility coefficient of crude oil
Oil formation volume factor for undersaturated oils
Crude oil density
Crude oil viscosity
Methods of calculating viscosity of the dead oil
Methods of calculating the saturated oil viscosity
Methods of calculating the viscosity of the undersaturated oil
Surface/interfacial tension
Properties of reservoir water
Water formation volume factor
Water viscosity
Gas solubility in water
Water isothermal compressibility
ProblemsLaboratory Analysis Of Reservoir FluidsComposition of the resevoir fluid
Constant-composition expansion tests
Differential liberation (vaporization) test Separator tests
Adjustment of differential liberation data to separator conditions
Extrapolation of resevoir fluid data
Correcting constant-composition expansion data
Correcting differential liberation data
Correcting oil viscosity data
Correcting the separator tests data
Laboratory analysis of gas condensate systems
Recombination of separator samples
Constant-composition test
Constant-volume depletion (CVD) test
ProblemsFundamentals Of Rock PropertiesPorosity
Absolute porosity
Effective porosity
Saturation
Average saturation
Wettability
Surface and interfacial tension
Capillary pressure
Capillary pressure of reservoir rocks
Capillary hysteresis
Initial saturation distribution in a reservoir
Leverett J-function
Converting laboratory capillary pressure data
Permeability
The Klinkenberg effect
Averaging absolute permeabilities
Weighted-average permeability
Harmonic-average permeability
Geometric-average permeability
Absolute permeability correlations
Rock compressibility
Net pay thickness
Resevoir heterogeneity
Vertical Heterogeneity
Areal heterogeneity
ProblemsRelative Permeability ConceptsTwo-phase relative permeability
Drainage process
Imbibition process
Two-phase relatie permeability correlations
Wyllie and Gardner correlation
Torcaso and Wyllie correlation
Pirson’s correlation
Corey’s method
Relative permeability from capillary pressure data
Relative permeability from analytical equations
Relative permeability ratio
Dynamic pseudo-relative permeabilities
Normalization and averaging realtive permeability data
Three-phase relative permeability
Three-phase relative permeability correlations
Wyllie’s correlations
Stone’s model I
Stone’s model II
The Hustad-Holt correlation
ProblemsFundamentals Of Reservoir Fluid FlowTypes of fluid
Flow regimes
Resevoir geometry
Number of flowing fluids in the resevoir
Fluid flow equations
Darcy’s Law
Steady-state flow
Linear flow of incompressible fluids
Linear flow of slightly compressible fluids
Linear flow of compressible fluids (gases)
Radial flow of incompressible fluids
Radial flow of slightly compressible fluids
Radial flow of compressible gases
Horizontal multiple-phase flow
Unsteady-state flow
Basic transient flow equation
Radial flow of slightly compressible fluids.
Constant-terminal-pressure solution
Constant-terminal-rate solution
The E-function solution
The dimensionless pressure drop (Pd) solution
Radial flow of compressible fluids
The m(p)-solution method (exact-solution)
The pressure-squared approximation method (p2-method)
The pressure-approximation method
Pseudosteady-state flow
Radial flow of slightly compressible fluids
Radial flow of compressible fluids (gases)
Pressure-squared approximation method
Pressure-approximation method
Skin factor
Turbulent flow factor
Principle of superposition
Effects of multiple wells
Effects of variable flow rates
Effects of the reservoir boundary
Accounting for pressure-change effects
Transient well testing
Drawdown test
Pressure buildup test
ProblemsOil Well PerformanceVertical oil well performance
Productivity index and IPR
Vogel’s method
Saturated oil reservoirs
Undersaturated oil reservoirs
Wiggins’ method
Standing’s method
Fetkovich’s method
The Klins-Clark method
Horizontal oil well performance
Method I
Method II
Horizontal well productivity under steady-state flow
Borisov’s method
The Giger-Reiss-Jourdan method
Joshi’s method
The Renard-Dupuy method
Horizontal well productivity under semisteady-state flow
ProblemsGas Well PerformanceVertical gas well performance
Region I. High-pressure region
Region II. Intermediate-pressure region
Region III. Low-pressure region
The simpified treatment approach
The Laminar-Inertial-Turbulent (LIT) approach
The Back-Pressure test
Future inflow performance relationships
Horizontal gas well performance
ProblemsGas And Water ConingConing
Coning in vertical wells
Vertical well critical rate correlations
The Meyer-Garder correlation
The Chierici-Ciucci approach
The Hoyland-Papatzacos-Skjaeve methods
Critical rate curves by Chaney et al.
Chaperson’s method
Schols’ method
Breakthrough time in vertical wells
The Sobocinski-Cornelius method
The Bournazel-Jeanson method
After breakthrough performance
Coning in horizontal wells
Horizontal well critical rate correlations
Chaperson’s method
Efros’ method
Karcher’s method
Joshi’s method
Horizontal well breakthrough time
The Ozkan-Raghavan method
Papatzacos’ method
ProblemsWater InfluxClassification of aquifers
Degree of pressure maintenance
Outer boundary conditions
Flow regimes
Flow geometries
Recognition of natural water influx
Water influx models
The pot aquifer model
Schilthuis’ steady-state model
Hurst’s modified steady-state model
The Van Everdingen-Hurst unsteady-state model
The edge-water drive
Bottom-water drive
The Carter-Tracey water influx model
Fetkovich’s method
ProblemsOil Recovery Mechanisms And The Material Balance EquationPrimary recovery mechanisms
Rock and liquid expansion
The depletion drive mechanism
Gas cap drive
The water-drive mechanism
The gravity-drainage-drive mechanism
The combination-drive mechanism
The material balance equation
Basic assumptions in the MBE
The MBE as an equation of a straight line
The straight-line solution method to the MBE
Case 1: Volumetric undersaturated-oil resevoirs
Case 2: Volumetric saturated-oil reservoirs
Case 3: Gas-cap-drive reservoirs
Case 4: Water-drive reservoirs
The pot-aquifer model in the MBE
The steady-state model in the MBE
The unsteady-state model in the MBE
Tracy’s form of the material balance equation
ProblemsPredicting Oil Reservoir PerformancePhase I. Reservoir performance prediction methods
Instantaneous gas-oil ratio
The resevoir saturation equations
Undersaturated-oil reservoirs
Saturated-oil reservoirs
Tracy’s method
Muskat’s method
Tarner’s method
Phase II. Relating reservoir performance to time
ProblemsGas ReservoirsThe volumetric method
The material balance method
Volumetric gas reservoirs.
Form I. In terms of p/z
Form II. In terms of Bg
Water-drive gas reservoirs
Material balance equation as a straight line
Abnormally pressured gas reservoirs
Effect on gas production rate on ultimate recovery
ProblemsPrinciples Of WaterfloodingFactors to consider in waterflooding
Reservoir geometry
Fluid properties
Reservoir depth
Lithology and rock properties
Fluid saturations
Reservoir uniformity and pay continuity
Primary reservoir driving mechanisms
Optimum time to waterflood
Effect of trapped gas on waterflood recovery
First theory
Second theory
Selection of flooding patterns
Irregular injection patterns
Irregular injection patterns
Peripheral injection patterns
Regular injection patterns
Crestal and basal injection patterns
Overall recovery efficiency
I. Displacement efficiency
II. Areal sweep efficiency
III. Vertical sweep efficiency
Calculation of vertical sweep efficiency
Methods of predicting recovery performance for layered reservoirs
Simplified Dykstra-Parsons method
Modified Dykstra-Parsons method
Craig-Geffen-Morse method
ProblemsVapor-Liquid Phase EquilibriaVapor pressure
Equilibrium ratios
Flash calculations
Equilibrium ratios for real solutions
Wilson’s correlation
Standing’s correlation
Convergence pressure method
Whitson and Torp correlation
Equilibrium ratios for the plus fraction
Campbell’s method
Winn’s method
Katz’s method
Applications of the equilibrium ratio in reservoir engineering
Dew-point pressure
Bubble-point pressure
Separator calculations
Density calculations
Equations of state
The Van der Waals equation of state
Redlick-Kwong equation of state
Soave-Redlick-Kwong equation of state and its modifications
Modifications of the SRK EOS
Peng-Robinson equation of state and its modifications
Applications of the equation of state in petroleum engineering
Determination of the equilibrium ratios
Determination of the dew-point pressure
Determination of the bubble-point pressure
Three-phase equilibrium calculations
Vapor pressure from equilibrium of state
Splitting and lumping schemes of the plus-fraction
Splitting schemes
Lumping schemes
ProblemsAppendix