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About the Author.
1.1 Program Overview.
1.2 Conventional Black Oil Simulator Equations . 1.3 Extended Black Oil Simulator Equations.
1.4 Program Operation.
1.5 Input Data File - ITEMP.DAT.
1.6 Output Data Files.
Exercises. 2. Reservoir Structure. 2.1 Coordinate Orientation.
2.2 Traditional Mapping.
2.3 Computer Generated Maps.
2.4 Geostatistical Mapping.
2.5 Bulk Volume and Net Volume.
3.1 Porosity Defined.
3.2 Net Pore Volume and Saturation.
3.3 Statistics of Porosity Distributions.
3.4 Characteristic Volume.
4.1 Darcy's Law.
4.3 Directional Dependence of Permeability.
4.4 Permeability Averaging.
5.1 Critical Sample Size for Porosity.
5.2 Permeability Distributions.
5.3 Critical Sample Size for Permeability.
5.4 Measures of Permeability Heterogeneity.
6.1 Compressional and Shear Velocities.
6.2 Estimates of Moduli.
6.3 Moduli from Acoustic Velocities.
6.4 Acoustic Impedance and Reflection Coefficient.
6.5 Geostatistical Correlations.
7.1 Effective Permeability and Relative Permeability.
7.2 Two-Phase Relative Permeability.
7.3 Averaging Relative Permeability Data.
7.4 Two-Phase Relative Permeability Correlations.
7.5 Three-Phase Relative Permeability Correlations.
8. Capillary Pressure.
8.1 Basic Concepts.
8.2 Capillary Pressure.
8.3 Capillary Pressure Measurements.
8.4 Capillary Pressure Correlation Methods.
9.1 Miscible Conditions.
9.2 Solid Precipitation.
9.3 Water Blocking.
9.4 Mobility Control.
9.5 Effective Relative Permeability and Capillary Pressure. 9.6 Transmissibility.
10.1 Fundamental Fluid Property Concepts.
10.2 Black Oil Model PVT Data.
10.3 Extrapolating Saturated Curves.
10.4 Bubble Point Tracking. 10.5 Extended Fluid Properties Model.
11.2 Fractional Flow.
11.3 Recovery Efficiency.
11.4 Production Stages.
11.5 Miscible Displacement Models.
12.1 Conservation of Mass.
12.2 Flow Equations for Three-Phase Flow.
12.3 Recasting the Flow Equations.
12.4 Introduction of the Capillary Pressure Concept.
12.5 Extended Black Oil Simulator Equations.
13.1 Productivity Index.
13.2 Rate Constraint Representation.
13.3 Pressure Constraint Representation.
13.4 Well Constraints.
13.5 Aquifer Models.
14.1 The Finite Difference Concept.
14.2 Derivative of Accumulation Terms.
14.3 Volume Integration and Discretization.
14.4 Multi-Variable Newton-Raphson IMPES Procedure.
15.1 Monitoring Frontal Advance.
15.2 Scheduling 4-D Seismic Surveys.
15.3 Improved Oil Recovery Examples.
Appendix A: Introduction to IFLO.
A.1 Program Review.
A.2 Program Configuration.
A.3 Input Data File - ITEMP.DAT.
A.4 Example Input Data Sets.
B.1 Model Dimensions and Geometry.
B.2 Seismic Velocity Parameters.
B.3 Porosity, Permeability, and Transmissibility Distributions.
B.4 Rock Regions. B.5 Relative Permeability and Capillary Pressure Tables.
B.6 Fluid PVT Tables.
B.7 Miscible Solvent Data.
B.8 Pressure and Saturation Initialization.
B.9 Run Control Parameters.
B.10 Analytic Aquifer Models.
Appendix C: Recurrent Data.
C. 1 Timestep and Output Control.
C.2 Well Information.
Integrated Flow Modeling presents the formulation, development and application of an integrated flow simulator (IFLO). Integrated flow models make it possible to work directly with seismically generated data at any time during the life of the reservoir. An integrated flow model combines a traditional flow model with a petrophysical model. The text discusses properties of porous media within the context of multidisciplinary reservoir modeling, and presents the technical details needed to understand and apply the simulator to realistic problems. Exercises throughout the text direct the reader to software applications using IFLO input data sets and an executable version of IFLO provided with the text. The text-software combination provides the resources needed to convey both theoretical concepts and practical skills to geoscientists and engineers.
- No. of pages:
- © Elsevier Science 2000
- 23rd November 2000
- Elsevier Science
- eBook ISBN:
John R. Fanchi
B.S., University of Denver (1974)
M.S., University of Mississippi (1975)
Ph.D., University of Houston (1977)
Dr. Fanchi is a Professor in the Petroleum Engineering Department at the Colorado School of Mines. He has B.S., M.S. and Ph.D. degrees in Physics from the Universities of Denver, Mississippi and Houston, respectively. He has worked in the technology centers of Getty Oil Company, Cities Service Company, and Marathon Oil Company. His engineering activities have revolved around reservoir modeling, both in the areas of simulator development and applications.
In addition to being the principal author of the US Department of Energy simulator BOAST and its successor BOASTII, he has performed development work on compositional, electromagnetic heating, chemical flood, and geothermal simulators. His reservoir management experience includes project leadership or significant participation in studies of oil, gas and condensate fields in the North Sea; offshore Sakhalin Island, Russia; the Gulf of Mexico; and in many parts of the mainland US. These studies include preparing models of primary, secondary, and improved recovery applications.
Dr. Fanchi has designed and taught courses in applied reservoir simulation, waterflooding, reservoir engineering, natural gas engineering, black oil simulation, compositional simulation, and history matching. His previous publications include several articles and three books, including Principles of Applied Reservoir Simulation (Gulf, 1997) and Math Refresher for Scientists and Engineers (Wiley, 1997).
"I am establishing a research and development program that seeks to optimize the tools used by society to fulfill its responsibility as custodian of the earth's natural resources. I am interested in working with people who want to improve the ability of simulators to accurately model physical processes and make predictions."
Dr. Fanchi lives in Golden with his wife and two sons.
Golden, Colorado, USA
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