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Phase Behavior of Petroleum Reservoir Fluids 2nd edition [Kietas viršelis]

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  • Formatas: Hardback, 466 pages, aukštis x plotis: 254x178 mm, weight: 1020 g, 253 Tables, black and white; 248 Illustrations, black and white
  • Išleidimo metai: 18-Dec-2014
  • Leidėjas: CRC Press Inc
  • ISBN-10: 1439852235
  • ISBN-13: 9781439852231
Kitos knygos pagal šią temą:
Phase Behavior of Petroleum Reservoir Fluids 2nd editionDidesnis paveikslėlis
  • Formatas: Hardback, 466 pages, aukštis x plotis: 254x178 mm, weight: 1020 g, 253 Tables, black and white; 248 Illustrations, black and white
  • Išleidimo metai: 18-Dec-2014
  • Leidėjas: CRC Press Inc
  • ISBN-10: 1439852235
  • ISBN-13: 9781439852231
Kitos knygos pagal šią temą:
Pastovi nuoroda: https://www.kriso.lt/db/9781439852231.html
Raktažodžiai:
Pedersen, Christensen, and Shaikh set out the industry standards for modeling the phase behavior of petroleum reservoir fluids at different stages in the recovery process. Their topics include petroleum reservoir fluids, pressure-volume-temperature (PVT) experiments, equations of state, flash and phase envelope calculations, physical properties, regression to experimental PVT data, transport properties, wax formation, asphaltenes, gas hydrates, compositional variations with depth, minimum miscibility pressure, formation water and hydrate inhibitors, and scale precipitation. Annotation ©2015 Ringgold, Inc., Portland, OR (protoview.com)

Developed in conjunction with several oil companies using experimental data for real reservoir fluids,Phase Behavior of Petroleum Reservoir Fluids introduces industry standard methods for modeling the phase behavior of petroleum reservoir fluids at different stages in the process. Keeping mathematics to a minimum, this book discusses sampling, characterization, compositional analyses, and equations of state used to simulate various pressure–volume–temperature (PVT) properties of reservoir fluids.

Featuring new figures, references, and updates throughout, this Second Edition:

  • Adds simulation results for PVT data obtained with the PC-SAFT equation
  • Describes routine and EOR PVT experiments with enhanced procedural detail
  • Expands coverage of sampling, compositional analyses, and measurement of PVT data

Phase Behavior of Petroleum Reservoir Fluids, Second Edition supplies a solid understanding of the phase behavior of the various fluids present in a petroleum reservoir, providing practical knowledge essential for achieving optimal design and cost-effective operations in a petroleum processing plant.

Recenzijos

"This book offers a very good balance between experiment and theory and is written in a style that is practical and easy to comprehend. The chapters on organic and inorganic solid deposition will be of great use for professionals that are involved in flow assurance. The approach taken by the authors is very logical, i.e., starting with the basics of petroleum chemistry to scale deposition covering all aspects of petroleum reservoir fluids that one needs to know. Enhanced experimental procedures and analysis of EOR PVT data are great new additions to the Second Edition. Karen and co-authors, with their rich experience and expertise, are perhaps some of the most authoritative and widely recognized professionals in the area of petroleum reservoir fluids, and a book written by them on what they practice is the best thing one can ask for. Therefore, reservoir engineers in industry as well as those in academia will benefit immensely from this book." Abhijit Dandekar, University of Alaska Fairbanks, USA

"The big advantage of this book for me is that it has a dedicated chapter covering fluid sampling, sample quality control, and compositional analysis. The description of the way reservoir fluid composition is derived from the compositions of individual sub-samples is especially useful, as I am not aware of it being covered in such detail in other texts. The book contents give very good coverage of a broad range of phase behavior concepts. It is refreshing to see sampling techniques covered in good detail." John M. Williams, The Petroleum Institute, Abu Dhabi, UAE

Preface xi
Authors xiii
Chapter 1 Petroleum Reservoir Fluids 1(12)
1.1 Reservoir Fluid Constituents
1(1)
1.2 Properties of Reservoir Fluid Constituents
1(5)
1.3 Phase Envelopes
6(1)
1.4 Classification of Petroleum Reservoir Fluids
7(4)
References
11(2)
Chapter 2 Sampling, Quality Control, and Compositional Analyses 13(34)
2.1 Fluid Sampling
13(3)
2.2 Quality Control of Fluid Samples
16(5)
2.2.1 Bottom Hole/Wellhead Samples
16(1)
2.2.2 Separator Samples
17(4)
2.2.2.1 Quality Control of Separator Gas
18(1)
2.2.2.2 QC of Separator Liquid
19(2)
2.3 Compositional Analyses
21(13)
2.3.1 Gas Chromatography
21(9)
2.3.1.1 Preparation Oil Mixtures
21(2)
2.3.1.2 Preparation Gas Condensate Mixtures
23(1)
2.3.1.3 Gas Chromatograph
23(7)
2.3.2 TBP Analysis
30(19)
2.3.2.1 Molecular Weight from Freezing Point Depression
33(1)
2.4 Reservoir Fluid Composition from Bottom Hole Sample
34(2)
2.5 Reservoir Fluid Composition from Separator Samples
36(6)
2.6 Mud-Contaminated Samples
42(4)
References
46(1)
Chapter 3 PVT Experiments 47(36)
3.1 Routine PVT Experiments
49(18)
3.1.1 Constant-Mass Expansion Experiment
49(7)
3.1.1.1 Oil Mixtures
49(2)
3.1.1.2 Gas Condensate Mixtures
51(2)
3.1.1.3 Dry Gases
53(3)
3.1.2 Differential Liberation Experiment
56(4)
3.1.3 Constant-Volume Depletion Experiment
60(3)
3.1.4 Separator Test
63(3)
3.1.5 Viscosity Experiment
66(1)
3.2 FOR PVT Experiments
67(14)
3.2.1 Solubility Swelling Test
67(5)
3.2.2 Equilibrium Contact Experiment
72(1)
3.2.3 Multi-Contact Experiment
72(2)
3.2.4 Slim Tube Experiment
74(6)
3.2.5 Gas Revaporization Experiment
80(1)
References
81(2)
Chapter 4 Equations of State 83(22)
4.1 van der Waals Equation
83(3)
4.2 Redlich—Kwong Equation
86(1)
4.3 Soave—Redlich—Kwong Equation
87(4)
4.4 Peng—Robinson Equation
91(1)
4.5 Peneloux Volume Correction
92(3)
4.6 Other Cubic Equations of State
95(1)
4.7 Equilibrium Calculations
96(1)
4.8 Nonclassical Mixing Rules
97(1)
4.9 PC-SAFT Equation
97(5)
4.10 Other Equations of State
102(1)
References
103(2)
Chapter 5 C7+ Characterization 105(34)
5.1 Classes of Components
105(12)
5.1.1 Defined Components to C6
105(2)
5.1.2 C7 Fractions
107(3)
5.1.3 Plus Fraction
110(7)
5.2 Binary Interaction Coefficients
117(1)
5.3 Lumping
117(4)
5.4 Delumping
121(1)
5.5 Mixing of Multiple Fluids
122(3)
5.6 Characterizing of Multiple Compositions to the Same Pseudocomponents
125(2)
5.7 Heavy Oil Compositions
127(7)
5.7.1 Heavy Oil Reservoir Fluid Compositions
128(1)
5.7.2 Characterization of Heavy Oil Mixture
128(6)
5.8 PC-SAFT Characterization Procedure
134(3)
References
137(2)
Chapter 6 Flash and Phase Envelope Calculations 139(26)
6.1 Pure Component Vapor Pressures from Cubic Equations of State
140(2)
6.2 Mixture Saturation Points from Cubic Equations of State
142(2)
6.3 Flash Calculations
144(14)
6.3.1 Stability Analysis
144(5)
6.3.2 Solving the Flash Equations
149(1)
6.3.3 Multiphase PT-Flash
150(5)
6.3.4 Three Phase PT-Flash with a Pure Water Phase
155(2)
6.3.5 Other Flash Specifications
157(1)
6.4 Phase Envelope Calculations
158(4)
6.5 Phase Identification
162(1)
References
163(2)
Chapter 7 PVT Simulation 165(22)
7.1 Constant Mass Expansion
165(4)
7.2 Constant Volume Depletion
169(3)
7.3 Differential Liberation
172(2)
7.4 Separator Test
174(2)
7.5 Solubility Swelling Test
176(5)
7.6 PVT Simulations with PC-SAFT EoS
181(3)
7.7 What to Expect from a PVT Simulation
184(2)
References
186(1)
Chapter 8 Physical Properties 187(10)
8.1 Density
187(1)
8.2 Enthalpy
188(1)
8.3 Internal Energy
189(1)
8.4 Entropy
189(1)
8.5 Heat Capacity
190(1)
8.6 Joule—Thomson Coefficient
190(1)
8.7 Velocity of Sound
190(1)
8.8 Example Calculations
190(5)
References
195(2)
Chapter 9 Regression to Experimental PVT Data 197(36)
9.1 Shortcomings of Parameter Regression
197(1)
9.2 Volume Translation Parameter
198(1)
9.3 Tc, Pc, and Acentric Factor of C7+ Fractions
198(1)
9.4 Regressing on Coefficients in Property Correlations
199(1)
9.5 Object Functions and Weight Factors
199(1)
9.6 Example of Regression for Gas Condensate
200(6)
9.7 Tuning on Single Pseudocomponent Properties
206(2)
9.8 Near-Critical Fluids
208(4)
9.9 Fluids Characterized to the Same Pseudocomponents
212(4)
9.10 PVT Data with Gas Injection
216(5)
9.11 Original Reservoir Fluid Composition from Depleted Sample
221(10)
9.11.1 Numerical Example
227(2)
9.11.2 Depleted Oil and Shale Reservoir Fluid Samples
229(2)
References
231(2)
Chapter 10 Transport Properties 233(36)
10.1 Viscosity
233(19)
10.1.1 Corresponding States Viscosity Models
233(9)
10.1.2 Adaptation of Corresponding States Viscosity Model to Heavy Oils
242(1)
10.1.3 Lohrenz—Bray—Clark Method
243(2)
10.1.4 Other Viscosity Models
245(2)
10.1.5 Viscosity Data and Simulation Results
247(5)
10.2 Thermal Conductivity
252(8)
10.2.1 Data and Simulation Results for Thermal Conductivity
260(1)
10.3 Gas/Oil Surface Tension
260(5)
10.3.1 Models for Interfacial Tension
262(3)
10.3.2 Data and Simulation Results for Interfacial Tensions
265(1)
10.4 Diffusion Coefficients
265(2)
References
267(2)
Chapter 11 Wax Formation 269(30)
11.1 Experimental Studies of Wax Precipitation
269(8)
11.2 Thermodynamic Description of Melting of a Pure Component
277(5)
11.3 Modeling of Wax Precipitation
282(9)
11.3.1 Activity Coefficient Approach
283(3)
11.3.2 Ideal Solid Solution Wax Models
286(5)
11.4 Wax PT Flash Calculations
291(1)
11.5 Viscosity of Oil—Wax Suspensions
291(3)
11.6 Wax Inhibitors
294(2)
References
296(3)
Chapter 12 Asphaltenes 299(24)
12.1 Experimental Techniques for Studying Asphaltene Precipitation
303(3)
12.1.1 Quantification of Amount of Asphaltenes
303(1)
12.1.2 Detection of Asphaltene Onset Points
303(1)
12.1.2.1 Gray i metric Technique
303(1)
12.1.2.2 Acoustic Resonance Technique
303(1)
12.1.2.3 Light-Scattering Technique
304(1)
12.1.2.4 Filtration and Other Experimental Techniques
304(1)
12.1.3 Experimental Data for Asphaltene Onset Pressures
304(2)
12.2 Asphaltene Models
306(11)
12.2.1 Models Based on Cubic Equation of State
307(5)
12.2.2 Polymer Solution Models
312(1)
12.2.3 Thermodynamic—Colloidal Model
313(1)
12.2.4 PC-SAFT Model
314(1)
12.2.5 Other Asphaltene Models
315(2)
12.3 Asphaltene Tar Mat Calculation
317(2)
References
319(4)
Chapter 13 Gas Hydrates 323(24)
13.1 Types of Hydrates
323(4)
13.2 Modeling of Hydrate Formation
327(5)
13.3 Hydrate Inhibitors
332(1)
13.4 Hydrate Simulation Results
333(7)
13.5 Hydrate P/T Flash Calculations
340(4)
13.5.1 Hydrate Fugacities
340(2)
13.5.2 Flash Simulation Technique
342(2)
References
344(3)
Chapter 14 Compositional Variations with Depth 347(26)
14.1 Theory of Isothermal Reservoir
347(10)
14.1.1 Depth Gradient Calculations for Isothermal Reservoirs
349(8)
14.2 Theory of Non-isothermal Reservoir
357(13)
14.2.1 Absolute Enthalpies
364(1)
14.2.2 Examples: Calculations on Reservoir Fluids
364(6)
References
370(3)
Chapter 15 Minimum Miscibility Pressure 373(22)
15.1 Three-Component Mixtures
373(6)
15.2 MMP of Multicomponent Mixtures
379(13)
15.2.1 First Contact MMP
379(1)
15.2.2 Tie Line Approach
379(7)
15.2.3 Immiscible Systems
386(3)
15.2.4 Cell-to-Cell Simulation
389(3)
References
392(3)
Chapter 16 Formation Water and Hydrate Inhibitors 395(28)
16.1 Hydrocarbon—Water Phase Equilibrium Models
395(15)
16.1.1 Approach of Kabadi and Danner
398(3)
16.1.2 Asymmetric Mixing Rules
401(1)
16.1.3 Huron and Vidal Mixing Rule
402(5)
16.1.4 Phase Equilibria for Hydrocarbon—Salt Water
407(3)
16.1.5 Association Models
410(1)
16.2 Experimental Hydrocarbon—Water Phase Equilibrium Data
410(5)
16.3 Water Properties
415(3)
16.3.1 Viscosity of Water—Inhibitor Mixtures
417(1)
16.3.2 Properties of Salt Water
417(1)
16.3.3 Oil—Water Emulsion Viscosities
418(1)
16.4 Phase Envelopes of Hydrocarbon—Aqueous Mixtures
418(2)
References
420(3)
Chapter 17 Scale Precipitation 423(18)
17.1 Criteria for Salt Precipitation
423(2)
17.2 Equilibrium Constants
425(3)
17.3 Activity Coefficients
428(8)
17.4 Solution Procedure
436(1)
17.5 Example Calculations
437(2)
References
439(2)
Appendix A Fundamentals on Phase Equilibrium 441(6)
A.1 First and Second Laws of Thermodynamics
441(1)
A.2 Fundamental Thermodynamic Relations
441(1)
A.3 Phase Equilibrium
442(1)
A.4 Fugacities and Fugacity Coefficients
443(4)
Index 447
Karen Schou Pedersen holds a Ph.D in liquid physics from the Department of Physical Chemistry at the Technical University of Denmark. She has worked as a research associate at the Physics Department at Edinburgh University and at the nuclear research center, Institut Laue-Langevin, in Grenoble. She has been the managing director of Calsep A/S since 1984 and has been responsible for several R & D projects within reservoir fluid modeling and flow assurance. She is the author of more than 50 publications on oil and gas properties.

Peter L. Christensen holds a Ph.D from the Department of Chemical Engineering at the Technical University of Denmark. He started his career in oil and gas technology at Risų National Laboratories in Denmark focusing on studies in the fields of reservoir simulation and PVT. He has been an associate professor at the Technical University of Denmark and lectured in thermodynamics, unit operations, and oil and gas technology. He is currently a senior principal consultant at Calsep A/S.

Jawad Azeem Shaikh holds an M.Sc in petroleum technology from the University of Pune in India. He has been the regional manager and principal consultant of Calsep FZ-LLC in Dubai since 2009 and has been responsible for the project including lab coordination, designing of enhanced oil recovery studies, and equation of state modeling work of oil and gas properties. Before joining Calsep, he was an advanced studies supervisor for Core Laboratories International B.V. He has authored several papers and articles on sampling, PVT lab work, and oil and gas properties.