Fluid phase behavior for conventional and unconventional oil and gas reservoirs / Alireza Bahadori.

Format:

Book

Author/Creator:

Bahadori, Alireza, author.

Language:

English

Subjects (All):

Oil reservoir engineering.

Petroleum reserves--Mathematical models.

Petroleum reserves.

Physical Description:

1 online resource (556 pages) : illustrations, tables

Edition:

1st edition

Place of Publication:

Amsterdam, [Netherlands] : Gulf Professional Publishing, 2017.

System Details:

text file

Summary:

Fluid Phase Behavior for Conventional and Unconventional Oil and Gas Reservoirs delivers information on the role of PVT (pressure-volume-temperature) tests/data in various aspects, in particular reserve estimation, reservoir modeling, flow assurance, and enhanced oil recovery for both conventional and unconventional reservoirs. This must-have reference also prepares engineers on the importance of PVT tests, how to evaluate the data, develop an effective management plan for flow assurance, and gain perspective of flow characterization, with a particular focus on shale oil, shale gas, gas hydrates, and tight oil making. This book is a critical resource for today’s reservoir engineer, helping them effectively manage and maximize a company’s oil and gas reservoir assets. Provides tactics on reservoir phase behavior and dynamics with new information on shale oil and gas hydrates Helps readers Improve on the effect of salt concentration and application to C02-Acid Gas Disposal with content on water-hydrocarbon systems Provides practical experience with PVT and tuning of EOS with additional online excel spreadsheet examples

Contents:

Front Cover

Fluid Phase Behavior for Conventional and Unconventional Oil and Gas Reservoirs

Fluid Phase Behaviorfor Conventional and Unconventional Oiland Gas Reservoirs

Copyright

Dedication

CONTENTS

LIST OF CONTRIBUTORS

BIOGRAPHY

PREFACE

ACKNOWLEDGMENTS

One - Oil and Gas Properties and Correlations

1.1 INTRODUCTION

1.2 CRUDE OIL PROPERTIES

1.2.1 Oil Density

1.2.1.1 Equation of State Method

1.2.1.2 Alani-Kennedy Equation

1.2.1.3 Standing-Katz Method

1.2.1.4 American Petroleum Institute Method

1.2.1.5 Other Methods

1.2.2 Oil Gravity

1.2.3 Oil Compressibility

1.2.3.1 Vasquez and Beggs Correlation

1.2.3.2 Petrosky Correlation

1.2.4 Oil Bubble Point Pressure

1.2.4.1 Standing Correlation

1.2.4.2 Vasquez and Beggs Correlation

1.2.4.3 Al-Marhoun Correlation

1.2.4.4 Glaso Correlation

1.2.4.5 Petrosky Correlation

1.2.5 Solution Gas Oil Ratio

1.2.5.1 Standing Correlation

1.2.5.2 Vasquez-Beggs Correlation

1.2.5.3 Al-Marhoun Correlation

1.2.5.4 Glaso Correlation

1.2.5.5 Petrosky Correlation

1.2.6 Oil Formation Volume Factor

1.2.6.1 Standing Correlation

1.2.6.2 Vasquez and Beggs Correlation

1.2.6.3 Kartoatmodjo and Schmidt Correlation

1.2.6.4 Al-Marhoun Correlation

1.2.6.5 Glaso Correlation

1.2.6.6 Petrosky Correlation

1.2.6.7 Arps Correlation

1.2.7 Oil Viscosity

1.2.7.1 Corresponding State Method

1.2.7.2 Lohrenz-Bary-Clark Method

1.2.7.3 Quiñones-Cisneros et al. Method

1.2.7.4 Vasquez and Beggs Correlation

1.2.7.5 Glaso Correlation

1.2.7.6 Chew and Connally Correlation

1.2.7.7 Beggs and Robinson Correlation

1.2.7.8 Beal Correlation

1.3 GAS PROPERTIES

1.3.1 Gas Density

1.3.1.1 Theoretical Determination of Gas Density

1.3.2 Gas Compressibility

1.3.3 Gas Formation Volume Factor.

1.3.4 Total Formation Volume Factor

1.3.4.1 Al-Marhoun Correlation

1.3.4.2 Glaso Correlation

1.3.5 Gas Viscosity

1.3.5.1 Carr et al. Method

1.3.5.2 Lee et al. Method

1.4 INTERFACIAL TENSION

1.4.1 Parachor Model

Problems

REFERENCES

Two - Equations of State

2.1 INTRODUCTION

2.2 CUBIC EQUATION OF STATE (EOS)

2.3 NONCUBIC EOS

2.4 CORRESPONDING STATE CORRELATIONS

2.5 MIXING RULES

Three - Plus Fraction Characterization

3.1 INTRODUCTION

3.2 EXPERIMENTAL METHODS

3.2.1 True Boiling Point Distillation Method

3.2.2 Chromatography

3.3 SPLITTING METHODS

3.3.1 Katz Method

3.3.2 Pedersen Method

3.3.3 Gamma Distribution Method

3.4 PROPERTIES ESTIMATION

3.4.1 Watson Characterization Factor Estimation

3.4.2 Boiling Point Estimation

3.4.3 Critical Properties and Acentric Factor Estimation

3.4.4 Molecular Weight Estimation

3.4.5 Specific Gravity Estimation

3.5 RECOMMENDED PLUS FRACTION CHARACTERIZATION PROCEDURE

Four - Tuning Equations of State

4.1 MATCHING THE SATURATION PRESSURE USING THE EXTENDED GROUPS

4.2 GROUPING METHODS

4.2.1 Whitson Method

4.2.2 Pedersen et al. Method (Equal Weight Method)

4.2.3 The Cotterman and Prausnitz Method (Equal Mole Method)

4.2.4 Danesh et al. Method

4.2.5 The Aguilar and McCain Method

4.3 COMPOSITION RETRIEVAL

4.4 ASSIGNING PROPERTIES TO MULTIPLE CARBON NUMBER

4.5 MATCHING THE SATURATION PRESSURE USING THE GROUPED COMPOSITION

4.6 VOLUME TRANSLATION

Five - Vapor-Liquid Equilibrium (VLE) Calculations

5.1 AN INTRODUCTION TO EQUILIBRIUM

5.2 FLASH CALCULATIONS

5.3 METHODS OF FINDING K-VALUE

5.3.1 Ideal Concept

5.3.1.1 Lewis Fugacity Rule

5.3.1.2 Raoult's Law

5.3.1.3 Henry's Law.

5.3.2 Fugacity-Derived Equilibrium Ratio (φ−φ Approach)

5.3.3 Activity-Derived Equilibrium Ratios (γ−φ Approach)

5.3.4 Correlations for Finding Equilibrium Ratio

5.3.4.1 Wilson's Correlation

5.3.4.2 Standing's Correlation

5.3.4.3 Whitson and Torp Correlation

5.4 BUBBLE AND DEW-POINT CALCULATIONS

5.5 A DISCUSSION ON THE STABILITY

5.6 MULTIPHASE FLASH CALCULATIONS

5.7 CALCULATION OF SATURATION PRESSURES WITH STABILITY ANALYSIS

5.8 IDENTIFYING PHASES

six - Fluid Sampling

6.1 INTRODUCTION

6.2 SAMPLING METHOD

6.2.1 Subsurface Sampling

6.2.1.1 Bottom-Hole Samplers

6.2.1.2 Formation Testers

6.2.1.3 Surface Sampling

6.2.1.4 Wellhead Sampling

6.2.1.5 Relative Advantages of Subsurface and Surface Sampling

6.3 RECOMBINATION

6.3.1 Case 1

6.3.2 Case 2

6.3.3 Case 3

6.3.4 Case 4

6.4 PVT TESTS

6.4.1 Differential Test

6.4.2 Swelling Test

6.4.3 Separator Test

6.4.4 Constant Composition Test

6.4.5 Constant Volume Depletion

6.4.6 Differential Liberation Test

6.5 FLASH CALCULATION

Seven - Retrograde Gas Condensate

7.1 INTRODUCTION

7.2 GAS-CONDENSATE FLOW REGIONS

7.2.1 Condensate Blockage

7.2.2 Composition Change and Hydrocarbon Recovery

7.3 EQUATIONS OF STATE

7.3.1 Van der Waals's Equation of State

7.3.2 Soave-Redlich-Kwong Equation of State

7.3.3 The Soave-Redlich-Kwong-Square Well Equation of State

7.3.4 Peng-Robinson Equation of State

7.3.5 Peng-Robinson-Gasem Equation of State

7.3.6 Nasrifar and Moshfeghian (NM) Equation of State

7.3.7 Schmidt and Wenzel Equation of State

7.3.8 The Patel-Teja Equation of State and Modifications

7.3.9 Mohsen-Nia-Modarress-Mansoori Equation of State

7.3.10 Adachi-Lu-Sugie Equation of State

7.4 MIXING RULES

7.5 HEAVY FRACTIONS.

7.6 GAS PROPERTIES

7.6.1 Viscosity

7.6.1.1 Empirical Correlations

7.6.1.1.1 Lee-Gonzalez-Eakin Method (1966)

7.6.1.1.2 Dempsey's Standing Method (1965)

7.6.1.1.3 Chen and Ruth Method (1993)

7.6.1.1.4 Elsharkawy Method (2004)

7.6.1.1.5 Sutton Method (2007)

7.6.1.1.6 Shokir and Dmour Method (2009)

7.6.1.1.7 Sanjari-Nemati Lay-Peymani Method (2011)

7.6.2 Z Factor

7.6.2.1 Empirical Correlations

7.6.2.1.1 Papay (1968)

7.6.2.1.2 Beggs and Brill (1973)

7.6.2.1.3 Shell Oil Company

7.6.2.1.4 Bahadori et al. (2007)

7.6.2.1.5 Azizi et al. (2010)

7.6.2.1.6 Sanjari and Nemati Lay (2012)

7.6.2.1.7 Shokir et al. (2012)

7.6.2.1.8 Mahmoud (2014)

7.6.2.2 Equations of State

7.6.3 Density

7.6.3.1 Empirical Correlations

7.6.3.1.1 Nasrifar and Moshfeghian

7.6.3.2 Equation of State

7.6.4 Formation Volume Factor

7.6.5 Equilibrium Ratio

7.6.5.1 Equilibrium Ratio for Hydrocarbon Mixtures

7.6.5.1.1 Wilson's Correlation

7.6.5.1.2 Standing's Correlation

7.6.5.1.3 Whitson and Torp's Method

7.6.5.2 Equilibrium Ratio for Nonhydrocarbon Mixtures

7.6.6 Dew-Point Pressure

7.6.6.1 Empirical Correlations

7.6.6.1.1 Nemeth and Kennedy (1967)

7.6.6.1.2 Elsharkawy (2002)

7.6.6.1.3 Humoud and Al-Marhoun (2001)

7.6.6.1.4 Alternating Conditional Expectations

7.6.6.1.4.1 Marruffo-Maita-Him-Rojas (2002)

7.6.6.2 Iterative Method

Eight - Gas Hydrates

8.1 INTRODUCTION

8.2 TYPES AND PROPERTIES OF HYDRATES

8.3 THERMODYNAMIC CONDITIONS FOR HYDRATE FORMATION

8.3.1 Calculating Hydrate Formation Condition

8.3.1.1 Correlations

8.3.1.1.1 Makogon (1981)

8.3.1.1.2 Kobayashi et al. (1987)

8.3.1.1.3 Motiee (1991)

8.3.1.1.4 Østergaard et al. (2000)

8.3.1.1.5 Sun et al. (2003)

8.3.1.1.6 Towler and Mokhatab (2005).

8.3.1.1.7 Bahadori and Vuthaluru (2009)

8.3.1.2 Equation of States

8.3.1.2.1 The Cubic-Plus-Association Equation of State

8.3.1.2.2 Peng-Robinson Equation of State

8.3.1.2.3 Perturbed Chain-Statistical Associating Fluid Theory

8.3.1.2.3.1 Mathematical Formulation of PC-SAFT

8.3.1.2.3.1.1 Hard-chain Reference Fluid

8.3.1.2.3.1.2 Dispersion Interactions

8.3.1.2.3.1.3 Association Interactions

8.3.1.3 Iterative Method (K-value Method)

8.4 HYDRATE DEPOSITION

8.5 HYDRATE INHIBITIONS

8.5.1 Calculating the Amount of Hydrate Inhibitors

8.5.1.1 The Hammerschmidt Method

8.5.1.2 The Nielsen-Bucklin Method

8.5.1.3 McCain Method

8.5.1.4 Østergaard et al. (2005)

8.5.2 Calculating Inhibitor Loss in Hydrocarbon Phase

8.5.3 Inhibitor Injection Rates

Nine - Characterization of Shale Gas

9.1 INTRODUCTION

9.2 SHALE GAS RESERVOIR CHARACTERISTICS

9.3 BASIC SCIENCE BEHIND CONFINEMENT

9.3.1 Impact of Confinement on Critical Properties

9.3.2 Diffusion Effect Due to Confinement

9.3.3 Capillary Pressure

9.3.4 Adsorption Phenomenon in Shale Reservoirs

9.4 EFFECT OF CONFINEMENT ON PHASE ENVELOPE

Ten - Characterization of Shale Oil

10.1 INTRODUCTION

10.2 TYPES OF FLUIDS IN SHALE RESERVOIRS AND GENESIS OF LIQUID IN SHALE PORES

10.3 SHALE PORE STRUCTURE AND HETEROGENEITY

10.4 SHALE OIL EXTRACTION

10.4.1 History

10.4.2 Processing Principles

10.4.3 Extraction Technologies

10.5 INCLUDING CONFINEMENT IN THERMODYNAMICS

10.5.1 Classical Thermodynamics

10.5.1.1 Equation of State

10.5.1.2 Condition of Equilibrium

10.5.1.3 Vapor-Liquid Equilibrium/Flash Computation

10.5.2 Modification of Flash to Incorporate Capillary Pressure in Tight Pores

10.5.3 Stability Test Using Gibbs Free Energy Approach.

10.5.4 Impact of Critical Property Shifts Due to Confinement on Hydrocarbon Production.

Notes:

Includes bibliographical references at the end of each chapters and index.

Description based on online resource; title from PDF title page (ebrary, viewed December 9, 2016).

ISBN:

9780128034460

0128034467