tailieunhanh - Reservoir Formation Damage Episode 3 Part 11

Tham khảo tài liệu 'reservoir formation damage episode 3 part 11', kỹ thuật - công nghệ, cơ khí - chế tạo máy phục vụ nhu cầu học tập, nghiên cứu và làm việc hiệu quả | 732 Reservoir Formation Damage Deposition continued Carman-Kozeny equation altered porous media modified 84 externally introduced particles 191 301 envelopes asphaltene and wax 392 indigeneous particles 193 porosity and permeability effect of 95 303 sulfur model 669 Deposits mixed organic inorganic control 718 Depth of damage 693 Detachment mechanisms forces 147 Detection continuous real time series analysis formation damage 698 Diagnosis formation damage 679 Diagnostic charts 192 279 Diagnostic equations formation damage 191 279 Diagnostic type curves water injectivity tests 639 Diffusion force 146 Dissolution permeability porosity effect of 94 Dissolution porosity and permeability effect of 95 Distribution bi-modal 59 fractal 60 log-normal 56 pore and pore throat size 56 Drilling mud filtrate and solids invasion and mud cake formation 608 Dual-porosity model for simultaneous asphalteneparaffin deposition 428 E Efficiency flow 84 Electrostatic double-layer force 148 Emulsion formation damage completion-fluids and crude-oil emulsions control 718 Emulsion block viscosity variation index 687 wettability alteration 718 End-point saturation 72 Error analysis propagation impact estimation 556 Experimental data model assisted analysis 213 Experimental set-up formation damage testing 459 564 Expert system formation damage 702 Evaluation formation 103 Evaluation formation damage laboratory 456 478 Evaluation of drilling mud 482 Evaluation of hydraulic fracturing fluids 488 Evaluation of workover and injection fluids 488 Evaluation of workover damage and remedial chemicals 491 F Fabric 50 Factors formation damage 4 Fair-Hatch equation modified 93 Field diagnosis and measurement of formation damage 680 Field tests analysis and interpretation of 552 607 641 Filter cake formation 251 Index 733 Filtration coefficient 637 Finite differences method 538 Flow area open for 53 Flow efficiency 84 691 Flow functions alteration capillary pressure relative permeability 72 Flow functions