Working Guide to Petroleum and Natural Gas Production Engineering

Working Guide to Petroleum and Natural Gas Production Engineering, 1st Edition

Working Guide to Petroleum and Natural Gas Production Engineering, 1st Edition,William Lyons,ISBN9781856178457


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Key Features

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


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.


Production engineers, Facilities engineers and Reservoir engineers

William Lyons

William C. Lyons, Ph.D., P.E. (retired), holds nine patents in industrial drilling and has been responsible for the development of several important innovations in drilling and production technology. He is the lead Editor of the Standard Handbook of Petroleum and Gas Engineering, 3rd edition, publishing with Elsevier and co-author of several other professional books in drilling and production engineering for the petroleum industry. Dr. Lyons was a Professor in Petroleum Engineering and in Mechanical Engineering at the New Mexico Institute of Mining and Technology for 30 years. He also served two one-year tours as a Distinguished Visiting Professor in Mechanical Engineering at the U.S. Air Force Academy in Colorado Springs during his academic career. Since retiring from teaching, Dr. Lyons is currently a Technical Learning Advisor with Chevron's Clear Leader Center in Houston, TX.

Affiliations and Expertise

Technical Learning Advisor, Chevron, Houston, TX

View additional works by William Lyons

Working Guide to Petroleum and Natural Gas Production Engineering, 1st Edition

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


Chapter 2 Flow of Fluids

2.1 Basic Parameters of Multiphase Flow [1]

2.1.1 Flow Regimes

2.2 Slightly Inclined Pipes (-10°
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 (?=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 (?=-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]

2.13.1 Bubble Flow

2.13.2 Slug Flow

2.13.3 Transition Flow

2.13.4 Mist-Flow

2.14 The Hagedorn-Brown Method [9, 12, 13]

2.15 The Beggs-Brill Method [2, 9, 15]

2.16 Mechanistic Models

2.17 Hasan and Kabir Model [18, 19]

2.18 Summary


Chapter 3 Natural Flow Performance

3.1 Inflow Performance

3.1.1 Predicting Future Oil Well IPR

3.1.2 Tubing Performance

3.1.3 Choke Performance

3.1.4 Flowline Performance

3.1.5 Gas Flow Performances

3.1.6 Gas Inflow Performance

3.1.7 Low-Permeability Well Tests

3.1.8 Predicting Future IPR

3.1.9 Tubing Performance

3.1.10 Choke Performance

3.1.11 Flowline Performance

3.2 Two-Phase Flow Performance

3.2.1 Two-Phase Inflow Performance

3.2.2 Vogel’s Method

3.2.3 Fetkovich Method

3.2.4 Modified Standing’s Method

3.2.5 Predicting Future IPR

3.2.6 Tubing Performance

3.2.7 Use of Vertical Pressure Gradients

3.2.8 Water Content

3.2.9 Wellhead Pressure

3.2.10 Predicting the Flowing Life

3.2.11 Choke Performance

3.2.12 Gilbert’s Correlation

3.2.13 Poetmann–Beck’s Correlation

3.2.14 Ashford’s Correlations

3.2.15 Flowline Performance


Chapter 4 Gas Production Engineering

4.1 Surface Production/Separation Facility

4.1.1 Nomenclature of Separating Pressure Vessels

4.2 Pressure Vessel Relief Systems

4.2.1 Product Storage

4.2.2 Prime Movers

4.2.3 Piping Guidelines

4.2.4 Pressure Vessel Design—Phase Separation [11, 14–16]

4.3 Separator Design and Construction

4.4 Vertical Separators

4.5 Horizontal Separator

4.6 Vessel Internals [18]

4.7 Oil–Water–Gas Separation

4.8 Two-Stage Separation Systems

4.9 Crude Oil Treating Systems

4.9.1 Treating Equipment

4.9.2 Heat Input Requirements [21, 22]



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