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[null,"1.","Record Nr.",null,"UNINA9911004745603321"]
[null,null,"Autore",null,"Sheng James"]
[null,null,"Titolo",null,"Modern chemical enhanced oil recovery : theory and practice / / James J. Sheng"]
[null,null,"Pubbl/distr/stampa",null,"Burlington, MA, : Gulf Professional Pub., 2010"]
[null,null,"ISBN",null,"1-282-87880-8"]
[{"$nulls":4},"9786612878800"]
[{"$nulls":4},"0-08-096163-0"]
[null,null,"Descrizione fisica",null,"1 online resource (647 p.)"]
[null,null,"Disciplina",null,"622/.33827"]
[null,null,"Soggetti",null,"Enhanced oil recovery"]
[{"$nulls":4},"Oil reservoir engineering"]
[{"$nulls":4},"Oil fields - Production methods"]
[null,null,"Lingua di pubblicazione",null,"Inglese"]
[null,null,"Formato",null,"Materiale a stampa"]
[null,null,null,"Livello bibliografico","Monografia"]
[null,null,null,"Note generali","Description based upon print version of record."]
[null,null,null,"Nota di bibliografia","Includes bibliographical references and index."]
[null,null,"Nota di contenuto",null,"Front 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"]
[{"$nulls":4},"Retardation of Chemicals in Single-Phase FlowTypes of Fronts; Fractional Flow Curve Analysis of Two-Phase Flow; Chapter 3: Salinity Effect and Ion Exchange; Introduction; Salinity; Ion Exchange; Low-Salinity Waterflooding in Sandstone Reservoirs; Salinity Effect on Waterflooding in Carbonate Reservoirs; Chapter 4: Mobility Control Requirement in EOR Processes; Introduction; Background; Setup of Simulation Model; Discussion of the CONCEPT OF THE Mobility Control Requirement; Theoretical Investigation; Numerical Investigation; Experimental Justification; Further Discussion"]
[{"$nulls":4},"Chapter 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 "]
[{"$nulls":4},"Plot; Polymer Mixing and Well Operations Related to Polymer Injection; Special Cases, Pilot Tests, and Field Applications of Polymer Flooding; Polymer Flooding Experience and Learning in China; Chapter 6: Polymer Viscoelastic Behavior and Its Effect on Field Facilities and Operations; Introduction; Viscoelasticity"]
[{"$nulls":4},"Polymer 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"]
[{"$nulls":4},"An Experimental Study of Surfactant FloodingChapter 8: Optimum Phase Type and Optimum Salinity Profile in Surfactant Flooding; Introduction; Literature Review; Sensitivity Study; Further Discussion; Optimum Phase Type and Optimum Salinity Profile Concepts; Summary; Chapter 9: Surfactant-Polymer Flooding; Introduction; Surfactant-Polymer Competitive Adsorption; Surfactant-Polymer Interaction and Compatibility; Optimization of Surfactant-Polymer Injection Schemes; A Field Case of SP Flooding; Chapter 10: Alkaline Flooding; Introduction; Comparison of Alkalis Used in Alkaline Flooding"]
[{"$nulls":4},"Alkaline Reaction with Crude Oil"]
[null,null,null,"Sommario/riassunto","Crude 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"]