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|Additional Physical Format:||Print version:
Enhanced Oil Recovery Field Case Studies.
Burlington : Elsevier Science, ©2013
|Material Type:||Document, Internet resource|
|Document Type:||Internet Resource, Computer File|
|All Authors / Contributors:||
James J Sheng
|Description:||1 online resource (xxiii, 685 pages :) : illustrations|
|Contents:||Front Cover; Enhanced Oil Recovery Field Case Studies; Copyright Page; Contents; Preface; Contributors; Acknowledgments; 1 Gas Flooding; 1.1 What Is Gas Flooding?; 1.2 Gas Flood Design; 1.3 Technical and Economic Screening Process; 1.4 Gas Injection Design and WAG; 1.5 Phase Behavior; 1.5.1 Standard (or Basic) PVT Data; 1.5.2 Swelling Test; 1.5.3 Slim-Tube Test; 1.5.4 Multicontact Test; 1.5.5 Fluid Characterization Using an Equation-of-State; 1.6 MMP and Displacement Mechanisms; 1.6.1 Simplified Ternary Representation of Displacement Mechanisms. 1.6.2 Displacement Mechanisms for Field Gas Floods1.6.3 Determination of MMP; 1.7 Field Cases; 1.7.1 Slaughter Estate Unit CO2 Flood; 1.7.2 Immiscible Weeks Island Gravity Stable CO2 Flood; 1.7.3 Jay Little Escambia Creek Nitrogen Flood; 1.7.4 Overview of Field Experience; 1.8 Concluding Remarks; Abbreviations; References; 2 Enhanced Oil Recovery by Using CO2 Foams: Fundamentals and Field Applications; 2.1 Foam Fundamentals; 2.1.1 Why CO2 Is so Popular in Recent Years?; 2.1.2 Why CO2 Is of Interest Compared to Other Gases?; 2.1.3 Why CO2 Is Injected as Foams? 2.1.4 Foam in Porous Media: Creation and Coalescence Mechanisms2.1.5 Foam in Porous Media: Three Foam States and Foam Generation; 2.1.6 Foam in Porous Media: Two Strong-Foam Regimes-High-Quality and Low-Quality Regimes; 2.1.7 Modeling Foams in Porous Media; 2.1.8 Foam Injection Methods and Gravity Segregation; 2.1.9 CO2-Foam Coreflood Experiments; 2.1.10 Effect of Subsurface Heterogeneity-Limiting Capillary Pressure and Limiting Water Saturation; 2.1.11 Foam-Oil Interactions; 2.2 Foam Field Applications; 2.2.1 The First Foam Field Applications, Siggins Field, Illinois. 2.2.2 Steam Foam EOR, Midway Sunset Field, California2.2.3 CO2/N2 Foam Injection in Wilmington, California (1984); 2.2.4 CO2-Foam Injection in Rock Creek, Virginia (1984-1985); 2.2.5 CO2-Foam Injection in Rangely Weber Sand Unit, Colorado (1988-1990); 2.2.6 CO2-Foam Injection in North Ward-Estes, Texas (1990-1991); 2.2.7 CO2-Foam Injection in the East Vacuum Grayburg/San Andres Unit, New Mexico (1991-1993); 2.2.8 CO2-Foam Injection in East Mallet Unit, Texas, and McElmo Creek Unit, Utah (1991-1994); 2.3 Typical Field Responses During CO2-Foam Applications. 2.3.1 Diversion from High- to Low-Permeability Layers2.3.2 Typical Responses from Successful SAG Processes; 2.3.3 Typical Responses from Successful Surfactant-Gas Coinjection Processes; 2.4 Conclusions; Acknowledgment; Appendix-Expression of Gas-Mobility Reduction in the Presence of Foams; References; 3 Polymer Flooding-Fundamentals and Field Cases; 3.1 Polymers Classification; 3.2 Polymer Solution Viscosity; 3.2.1 Salinity and Concentration Effects; 3.2.2 Shear Effect; 3.2.3 pH Effect; 3.3 Polymer Flow Behavior in Porous Media; 3.3.1 Polymer Viscosity in Porous Media; 3.3.2 Polymer Retention.|
|Responsibility:||James J. Sheng.|
"Petroleum engineers mostly from oil and equipment companies draw on the field experience of specialists in enhanced oil recovery as well as from the technical literature and other sources to provide