Working Guide to Petroleum and Natural Gas Production Engineering provides an introduction to key concepts and processes in oil and gas production engineering. It begins by describing correlation and procedures for predicting the physical properties of natural gas and oil. These include compressibility factor and phase behavior, field sampling process and laboratory measurements, and prediction of a vapor-liquid mixture. The book discusses the basic parameters of multiphase fluid flow, various flow regimes, and multiphase flow models. It explains the natural flow performance of oil, gas, and the mixture. The final chapter covers the design, use, function, operation, and maintenance of oil and gas production facilities; the design and construction of separators; and oil and gas separation and treatment systems.

Key Features

  • Evaluate well inflow performance
  • Guide to properties of hydrocarbon mixtures
  • Evaluate Gas production and processing facilities


Production engineers, Facilities engineers and Reservoir engineers

Table of Contents

Chapter 1 Properties of Hydrocarbon Mixtures 1.1 Compressibility Factor and Phase Behavior 1.1.1 Compressibility Factor Using the Principle of Corresponding States (CSP) 1.1.2 Direct Calculation of Z Factors 1.1.3 Classification of Hydrocarbon Fluids 1.1.4 Reservoir Conditions Phase Behavior 1.2 Sampling Process and Laboratory Measurements 1.2.1 Equilibrium Cell Determinations 1.2.2 Equilibrium Flash Calculations 1.2.3 Vapor–Liquid Equilibrium Calculations 1.2.4 Predicting the Properties of Hexane Plus (C6+) Fractions 1.3 Vapor-Liquid Equilibrium by Equation of State References Chapter 2 Flow of Fluids 2.1 Basic Parameters of Multiphase Flow [1] 2.1.1 Flow Regimes 2.2 Slightly Inclined Pipes (−10°<θ<15°) 2.2.1 Step 1. Dimensionless Parameters 2.2.2 Step 2. Flow Regime Map 2.2.3 Step 3. Flow Regime Selection 2.3 Risers and Wells (θ=90°) 2.3.1 Step 1. Dimensionless Parameters 2.3.2 Step 2. Flow Regime Map 2.3.3 Step 3. Flow Regime Selection 2.4 Downcomers (θ=−90°) 2.4.1 Annular-Slug Transition 2.4.2 Slug-Bubbly Transition 2.5 Stratified Flow Regime 2.5.1 Pressure Gradient 2.5.2 Special Cases for Low and High Liquid Holdup 2.6 Annular Flow Regime 2.6.1 Liquid Entrainment Ed 2.6.2 Liquid Holdup HL 2.6.3 Pressure Gradient 2.6.4 Special Case for Low Liquid Holdup 2.7 Slug Flow Regime 2.7.1 Slug Velocity 2.7.2 Liquid Holdup 2.7.3 Pressure Gradient 2.7.4 Optional Correction 2.8 Bubby Flow Regime 2.8.1 Pressure Gradient 2.9 Correction for Acceleration Effects 2.10 Limitation 2.11 Empirical Methods 2.12 The Duns-Ros Method [20, 21] 2.13 The Orkiszewski Method [8, 9]


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© 2010
Gulf Professional Publishing
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