Effect of CO2-Oil Contact Time on the Swelling Factor and Viscosity of Paraffinic Oil at Reservoir Temperature
The objective of this experimental study is to investigate the effect of CO2-oil contact time to oil swelling factor and viscosity. A sample from the central Sumatra basin was utilized in this study, which is categorized into paraffinic oil. The experiment condition follows the reservoir condition, which has a low fracture pressure. Thus, miscible injection scheme is impossible to apply. Therefore, the role of CO2 in reducing oil viscosity and oil swelling is emphasized. The experiments were performed under reservoir temperature by using PVT cell, syringe pump, and HPHT Rheometer. The result from the experiments clearly indicates that oil swelling and viscosity reduction mechanisms are quite effective during 24 h of CO2 injection. Optimum condition is obtained for the sample with 10 h of CO2-oil contact-time, where the swelling factor and viscosity reduction still show significant values.
KeywordsCO2 Paraffinic oil Swelling factor Viscosity Contact time
- 1.Bagci, S., Tuzunoglu, E.: 3D model studies of the immiscible CO, process using horizontal wells for heavy oil recovery. In: Annual Technical Meeting. Petroleum Society of Canada, Jan 1998Google Scholar
- 2.Hepple, R.P., Benson, S.M.: Geologic storage of carbon dioxide as a climate change mitigation strategy: performance requirements and the implications of surface seepage. Environ. Geol. 47(4), 576–585 (2005)Google Scholar
- 3.Al-Abri, A., Amin, R.: Phase behaviour, fluid properties and recovery efficiency of immiscible and miscible condensate displacements by SCCO2 injection: experimental investigation. Transp. Porous Media 85(3), 743–756 (2010)Google Scholar
- 4.Li, H., Zheng, S., Yang, D.T.: Enhanced swelling effect and viscosity reduction of solvent (s)/CO2/heavy-oil systems. SPE J. 18(04), 695–707 (2013)Google Scholar
- 5.Or, C., Sasaki, K., Sugai, Y., Nakano, M., Imai, M.: Swelling and viscosity reduction of heavy oil by CO2-gas foaming in immiscible condition. SPE Reservoir Eval. Eng. 19(02), 294–304 (2016)Google Scholar