LEADER 05441nam 2200661Ia 450 001 9911004768103321 005 20200520144314.0 010 $a1-281-05463-1 010 $a9786611054632 010 $a0-08-053481-3 035 $a(CKB)1000000000383917 035 $a(EBL)313667 035 $a(OCoLC)190826590 035 $a(SSID)ssj0000072364 035 $a(PQKBManifestationID)12014658 035 $a(PQKBTitleCode)TC0000072364 035 $a(PQKBWorkID)10094732 035 $a(PQKB)10439059 035 $a(MiAaPQ)EBC313667 035 $a(EXLCZ)991000000000383917 100 $a20000907d2000 uy 0 101 0 $aeng 135 $aur|n|---||||| 181 $ctxt 182 $cc 183 $acr 200 10$aIntegrated flow modeling /$fJohn R. Franchi 205 $a1st ed. 210 $aAmsterdam [Netherlands] ;$aNew York $cElsevier Science B.V.$d2000 215 $a1 online resource (305 p.) 225 1 $aDevelopments in petroleum science ;$v49 300 $aDescription based upon print version of record. 311 $a0-444-50500-8 320 $aIncludes bibliographical references (p. 273-280) and index. 327 $aCover; Contents; About the Author; Preface; Chapter 1. Overview; 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; Chapter 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; Exercises; Chapter 3. Porosity; 3.1 Porosity Defined; 3.2 Net Pore Volume and Saturation; 3.3 Statistics of Porosity Distributions; 3.4 Characteristic Volume 327 $aExercisesChapter 4. Permeability; 4.1 Darcy's Law; 4.2 Permeability; 4.3 Directional De pendence of Permeability; 4.4 Permeability Averaging; Exercises; Chapter 5. Critical Sample Size; 5.1 Critical Sample Size for Porosity; 5.2 Permeability Distributions; 5.3 Critical Sample Size for Permeability; 5.4 Measures of Permeability Heterogeneity; Exercises; Chapter 6. Petrophysical Model; 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; Exercises 327 $aChapter 7. Relative Permeability7.1 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; Exercises; Chapter 8. Capillary Pressure; 8.1 Basic Concepts; 8.2 Capillary Pressure; 8.3 Capillary Pressure Measurements; 8.4 Capillary Pressure Correlation Methods; Exercises; Chapter 9. Extended Rock-Fluid Interactions; 9.1 Miscible Conditions; 9.2 Solid Precipitation; 9.3 Water Blocking; 9.4 Mobility Control 327 $a9.5 Effective Relative Permeability and Capillary Pressure9.6 Transmissibility; Exercises; Chapter 10. Fluid Properties; 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; Exercises; Chapter 11. Fluid Displacement; 11.1 Mobility; 11.2 Fractional Flow; 11.3 Recovery Efficiency; 11.4 Production Stages; 11.5 Miscible Displacement Models; Exercises; Chapter 12. Formulation of Flow Equations; 12.1 Conservation of Mass; 12.2 Flow Equations for Three-Phase Flow 327 $a12.3 Recasting the Flow Equations12.4 Introduction of the Capillary Pressure Concept; 12.5 Extended Black Oil Simulator Equations; Exercises; Chapter 13. Source/Sink Terms; 13.1 Productivity Index; 13.2 Rate Constraint Representation; 13.3 Pressure Constraint Representation; 13.4 Well Constraints; 13.5 Aquifer Models; Exercises; Chapter 14. Solution of the Extended Flow Equations; 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; Exercises; Chapter 15. IFLO Applications 327 $a15.1 Monitoring Frontal Advance 330 $aIntegrated Flow Modeling presents the formulation, development and application of an integrated flow simulator (IFLO). Integrated flow models make it possible to work directly with seismically generated data at any time during the life of the reservoir. An integrated flow model combines a traditional flow model with a petrophysical model. The text discusses properties of porous media within the context of multidisciplinary reservoir modeling, and presents the technical details needed to understand and apply the simulator to realistic problems. Exercises throughout the text direct the reade 410 0$aDevelopments in petroleum science ;$v49. 606 $aHydrocarbon reservoirs$xMathematical models 606 $aTraps (Petroleum geology) 615 0$aHydrocarbon reservoirs$xMathematical models. 615 0$aTraps (Petroleum geology) 676 $a553.28 676 $a622.3382015118 676 $a622/.3382/015118 21 676 $a622.3382015118 700 $aFanchi$b John R$0626447 801 0$bMiAaPQ 801 1$bMiAaPQ 801 2$bMiAaPQ 906 $aBOOK 912 $a9911004768103321 996 $aIntegrated flow modeling$94391022 997 $aUNINA