A Review of CO 2 -Enhanced Oil Recovery with a Simulated Sensitivity Analysis

Mandadige Samintha Anne Perera, Ranjith Pathegama Gamage, Tharaka Dilanka Rathnaweera, Ashani Savinda Ranathunga, Andrew Koay and Xavier Choi
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Mandadige Samintha Anne Perera: Department of Civil Engineering, Deep Earth Energy Laboratory, Monash University, Building 60, Melbourne 3800, Victoria, Australia
Ranjith Pathegama Gamage: Department of Civil Engineering, Deep Earth Energy Laboratory, Monash University, Building 60, Melbourne 3800, Victoria, Australia
Tharaka Dilanka Rathnaweera: Department of Civil Engineering, Deep Earth Energy Laboratory, Monash University, Building 60, Melbourne 3800, Victoria, Australia
Ashani Savinda Ranathunga: Department of Civil Engineering, Deep Earth Energy Laboratory, Monash University, Building 60, Melbourne 3800, Victoria, Australia
Andrew Koay: Department of Civil Engineering, Deep Earth Energy Laboratory, Monash University, Building 60, Melbourne 3800, Victoria, Australia
Xavier Choi: Commonwealth Scientific and Industrial Research Organisation (CSIRO), Ian Wark Laboratory, Clayton 3168, Victoria, Australia

Energies, 2016, vol. 9, issue 7, 1-22

Abstract: This paper reports on a comprehensive study of the CO 2 -EOR (Enhanced oil recovery) process, a detailed literature review and a numerical modelling study. According to past studies, CO 2 injection can recover additional oil from reservoirs by reservoir pressure increment, oil swelling, the reduction of oil viscosity and density and the vaporization of oil hydrocarbons. Therefore, CO 2 -EOR can be used to enhance the two major oil recovery mechanisms in the field: miscible and immiscible oil recovery, which can be further increased by increasing the amount of CO 2 injected, applying innovative flood design and well placement, improving the mobility ratio, extending miscibility, and controlling reservoir depth and temperature. A 3-D numerical model was developed using the CO 2 -Prophet simulator to examine the effective factors in the CO 2 -EOR process. According to that, in pure CO 2 injection, oil production generally exhibits increasing trends with increasing CO 2 injection rate and volume (in HCPV (Hydrocarbon pore volume)) and reservoir temperature. In the WAG (Water alternating gas) process, oil production generally increases with increasing CO 2 and water injection rates, the total amount of flood injected in HCPV and the distance between the injection wells, and reduces with WAG flood ratio and initial reservoir pressure. Compared to other factors, the water injection rate creates the minimum influence on oil production, and the CO 2 injection rate, flood volume and distance between the flood wells have almost equally important influence on oil production.

Keywords: CO 2 -EOR; miscible recovery; immiscible recovery; effective factors; review study; numerical modelling (search for similar items in EconPapers)
JEL-codes: Q Q0 Q4 Q40 Q41 Q42 Q43 Q47 Q48 Q49 (search for similar items in EconPapers)
Date: 2016
References: View references in EconPapers View complete reference list from CitEc
Citations: View citations in EconPapers (4)

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