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Enhanced oil recovery field case studies [[electronic resource] /] / James J. Sheng
| Enhanced oil recovery field case studies [[electronic resource] /] / James J. Sheng |
| Autore | Sheng James J |
| Pubbl/distr/stampa | Waltham, Mass., : Elsevier, 2013 |
| Descrizione fisica | 1 online resource (710 p.) |
| Disciplina | 622.33827 |
| Soggetto topico |
Oil fields
Gas fields |
| Soggetto genere / forma | Electronic books. |
| ISBN |
1-299-47288-5
0-12-386546-8 |
| Formato | Materiale a stampa  |
| Livello bibliografico | Monografia |
| Lingua di pubblicazione | eng |
| Nota di contenuto |
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 3.3.3 Inaccessible Pore Volume |
| Record Nr. | UNINA-9910452709403321 |
Sheng James J
|
||
| Waltham, Mass., : Elsevier, 2013 | ||
| Materiale a stampa | ||
| Lo trovi qui: Univ. Federico II | ||
| ||
Enhanced oil recovery field case studies / / James J. Sheng
| Enhanced oil recovery field case studies / / James J. Sheng |
| Autore | Sheng James J |
| Pubbl/distr/stampa | Waltham, Mass., : Elsevier, 2013 |
| Descrizione fisica | 1 online resource (xxiii, 685 pages) : illustrations (some color) |
| Disciplina | 622.33827 |
| Collana | Gale eBooks |
| Soggetto topico |
Enhanced oil recovery
Petroleum engineering Oil reservoir engineering Oil fields - Production methods |
| ISBN |
1-299-47288-5
0-12-386546-8 |
| Formato | Materiale a stampa |
| Livello bibliografico | Monografia |
| Lingua di pubblicazione | eng |
| Nota di contenuto |
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 3.3.3 Inaccessible Pore Volume |
| Record Nr. | UNINA-9910779553403321 |
|
Sheng James J
|
||
| Waltham, Mass., : Elsevier, 2013 | ||
| Materiale a stampa | ||
| Lo trovi qui: Univ. Federico II | ||
| ||
Enhanced oil recovery field case studies / / James J. Sheng
| Enhanced oil recovery field case studies / / James J. Sheng |
| Autore | Sheng James J |
| Pubbl/distr/stampa | Waltham, Mass., : Elsevier, 2013 |
| Descrizione fisica | 1 online resource (xxiii, 685 pages) : illustrations (some color) |
| Disciplina | 622.33827 |
| Collana | Gale eBooks |
| Soggetto topico |
Enhanced oil recovery
Petroleum engineering Oil reservoir engineering Oil fields - Production methods |
| ISBN |
1-299-47288-5
0-12-386546-8 |
| Formato | Materiale a stampa |
| Livello bibliografico | Monografia |
| Lingua di pubblicazione | eng |
| Nota di contenuto |
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 3.3.3 Inaccessible Pore Volume |
| Record Nr. | UNINA-9910828662803321 |
|
Sheng James J
|
||
| Waltham, Mass., : Elsevier, 2013 | ||
| Materiale a stampa | ||
| Lo trovi qui: Univ. Federico II | ||
| ||