LEADER 05261nam 2200625Ia 450 001 9911004745603321 005 20200520144314.0 010 $a1-282-87880-8 010 $a9786612878800 010 $a0-08-096163-0 035 $a(CKB)2530000000000367 035 $a(EBL)630036 035 $a(OCoLC)755777998 035 $a(SSID)ssj0000439742 035 $a(PQKBManifestationID)12163179 035 $a(PQKBTitleCode)TC0000439742 035 $a(PQKBWorkID)10464427 035 $a(PQKB)11003638 035 $a(MiAaPQ)EBC630036 035 $a(EXLCZ)992530000000000367 100 $a20100708d2010 uy 0 101 0 $aeng 135 $aur|n|---||||| 181 $ctxt 182 $cc 183 $acr 200 10$aModern chemical enhanced oil recovery $etheory and practice /$fJames J. Sheng 210 $aBurlington, MA $cGulf Professional Pub.$d2010 215 $a1 online resource (647 p.) 300 $aDescription based upon print version of record. 311 $a0-12-810220-9 311 $a1-85617-745-9 320 $aIncludes bibliographical references and index. 327 $aFront cover; Modern Chemical Enhanced Oil Recovery; Copyright page; Table of contents; Preface; Acknowledgments; Nomenclature; Greek Symbols; Superscripts; Subscripts; Chapter 1: Introduction; Enhanced Oil Recovery's Potential; Definitions of EOR and IOR; General Description of Chemical EOR Processes; Performance Evaluation of EOR Processes; Screening Criteria for Chemical EOR Processes; Naming Conventions and Units; Organization of This Book; Chapter 2: Transport of Chemicals and Fractional Flow Curve Analysis; Introduction; Diffusion; Dispersion 327 $aRetardation of Chemicals in Single-Phase FlowTypes of Fronts; Fractional Flow Curve Analysis of Two-Phase Flow; Chapter 3: Salinity Effect and Ion Exchange; Introduction; Salinity; Ion Exchange; Low-Salinity Waterflooding in Sandstone Reservoirs; Salinity Effect on Waterflooding in Carbonate Reservoirs; Chapter 4: Mobility Control Requirement in EOR Processes; Introduction; Background; Setup of Simulation Model; Discussion of the CONCEPT OF THE Mobility Control Requirement; Theoretical Investigation; Numerical Investigation; Experimental Justification; Further Discussion 327 $aChapter 5: Polymer FloodingIntroduction; Types of Polymers and Polymer-Related Systems; Properties of Polymer Solutions; Polymer Flow Behavior in Porous Media; Displacement Mechanisms in Polymer Flooding; Amount of Polymer Injected; Performance Analysis by Hall Plot; Polymer Mixing and Well Operations Related to Polymer Injection; Special Cases, Pilot Tests, and Field Applications of Polymer Flooding; Polymer Flooding Experience and Learning in China; Chapter 6: Polymer Viscoelastic Behavior and Its Effect on Field Facilities and Operations; Introduction; Viscoelasticity 327 $aPolymer Viscoelastic BehaviorObservations of Viscoelastic Effect; Displacement Mechanisms of Viscoelastic Polymers; Effect of Polymer Solution Viscoelasticity on Injection and Production Facilities; Chapter 7: Surfactant Flooding; Introduction; Surfactants; Types of Microemulsions; Phase Behavior Tests; Surfactant Phase Behavior of Microemulsions and IFT; Viscosity of Microemulsion; Capillary Number; Trapping Number; Capillary Desaturation Curve; Relative Permeabilities in Surfactant Flooding; Surfactant Retention; Displacement Mechanisms; Amount of Surfactant Needed and Process Optimization 327 $aAn Experimental Study of Surfactant FloodingChapter 8: Optimum Phase Type and Optimum Salinity Profile in Surfactant Flooding; Introduction; Literature Review; Sensitivity Study; Further Discussion; Optimum Phase Type and Optimum Salinity Profile Concepts; Summary; Chapter 9: Surfactant-Polymer Flooding; Introduction; Surfactant-Polymer Competitive Adsorption; Surfactant-Polymer Interaction and Compatibility; Optimization of Surfactant-Polymer Injection Schemes; A Field Case of SP Flooding; Chapter 10: Alkaline Flooding; Introduction; Comparison of Alkalis Used in Alkaline Flooding 327 $aAlkaline Reaction with Crude Oil 330 $aCrude oil development and production in U.S. oil reservoirs can include up to three distinct phases: primary, secondary, and tertiary (or enhanced) recovery. During primary recovery, the natural pressure of the reservoir or gravity drive oil into the wellbore, combined with artificial lift techniques (such as pumps) which bring the oil to the surface. But only about 10 percent of a reservoir's original oil in place is typically produced during primary recovery. Secondary recovery techniques to the field's productive life generally by injecting water or gas to displace oil and drive it to a pro 606 $aEnhanced oil recovery 606 $aOil reservoir engineering 606 $aOil fields$xProduction methods 615 0$aEnhanced oil recovery. 615 0$aOil reservoir engineering. 615 0$aOil fields$xProduction methods. 676 $a622/.33827 700 $aSheng$b James$01719513 801 0$bMiAaPQ 801 1$bMiAaPQ 801 2$bMiAaPQ 906 $aBOOK 912 $a9911004745603321 996 $aModern chemical enhanced oil recovery$94390893 997 $aUNINA