Chemical Flood of a Viscous Oil with Novel Surfactants
- Krishna Panthi (The University of Texas at Austin) | Upali Weerasooriya (The University of Texas at Austin) | Kishore Mohanty (The University of Texas at Austin)
- Document ID
- Society of Petroleum Engineers
- SPE Annual Technical Conference and Exhibition, 30 September - 2 October, Calgary, Alberta, Canada
- Publication Date
- Document Type
- Conference Paper
- 2019. Society of Petroleum Engineers
- Non-thermal EOR, Viscous oil, Chemical flood, Surfacants
- 22 in the last 30 days
- 234 since 2007
- Show more detail
- View rights & permissions
|SPE Member Price:||USD 9.50|
|SPE Non-Member Price:||USD 28.00|
The goal of this work is to evaluate the applicability of a novel set of surfactants to enhance recovery from a viscous oil, high temperature, high permeability, clastic reservoir. A large number of novel short-hydrophobe based surfactants/cosolvents were designed and synthesized. As these surfactants do not require expensive aliphatic alcohols for their synthesis, they are likely to be less costly than conventional anionic surfactants. Here only phenol hydrophobe based non-ionic surfactants with varying number of propylene oxide (PO) and ethylene oxide (EO) groups are discussed. These surfactant molecules were investigated for their aqueous stability limits, interfacial tensions (IFT) with a viscous crude oil and oil recovery from sandpack or sandstone cores. Surfactant phase behavior experiments with viscous crude oil showed low IFT (not ultralow) for single surfactant systems. Only one surfactant (Phenol-7PO-15EO) formulation was chosen for coreflood in sandpack and sandstone cores. Water flood recovered about 50% original oil in place (OOIP) and reduced the oil saturation to about 48% in the high permeability sandpacks. The tertiary surfactant polymer flood with Phenol-7PO-15EO increased the cumulative recovery to 99% for sandpacks. The oil recovery was insensitive to injection brine salinity in the range studied. As the permeability decreased, the tertiary oil recovery decreased if the permeability is lower than 7 Darcy. Surfactant-polymer (SP) formulations with this surfactant can be recommended for high permeability sandstone reservoirs with viscous oils, but not for sub-Darcy sandstones.
|File Size||1 MB||Number of Pages||17|
Adkins, S., Liyanage, P.J., Pinnawala Arachchilage, G.W.P, Mudiyanselage, T., Weerasooriya, U., Pope, G.A. 2010. A New Process for Manufacturing and Stabilizing High-Performance EOR Surfactants at Low Cost for High-Temperature, High-Salinity Oil Reservoirs. Society of Petroleum Engineers, doi: 10.2118/129923-MS.
Al-Dhafeeri, A.M., Seright, R.S., Nasr-El-Din, H.A., Sydansk, R.D. 2005. High-Permeability Carbonate Zones (Super-K) in Ghawar Field (Saudi Arabia), Identified, Characterized, and Evaluated for Gel Treatments. Presentation at the SPE International Improved Oil Recovery Conference in Asia Pacific, Kuala Lumpur, Malaysia, December 5-6, 2005, Paper SPE 97542.
Delamaide, E., Zaitoun, A., Rehard, G., Tabary, R. 2014. Pelican Lake Field: First Successful Application of Polymer Flooding in a Heavy-Oil Reservoirs. Society of Petroleum Engineers, doi: 10.2118/165234-PA.
Falls, A.H., Thigpen, D.R., Nelson, R.C., Ciaston, J.W., Lawson, J.B., Good, P.A., Ueber, R.C., Shahin, G.T. 1994. Field Test of Cosurfactant-Enhanced Alkaline Flooding. SPE Res Eng, 9(3): 217-223. SPE 24117-PA. doi: 10.2118/24117-PA.
Flaaten, A., Nguyen, Q.P., Zhang, J., Mohammadi, H., Pope, G.A. 2008. ASP Chemical Flooding Without the Need for Soft Water. Society of Petroleum Engineers, doi: 10.2118/116754-MS.
Healy, R.N., Reed, R.L. 1977. Immiscible Microemulsion Flooding. SPE Journal, 17 (2); 129-139. SPE-5817-PA. doi: 10.2118/5817-PA.
Kumar, R., Mohanty, K.K. 2010. ASP Flooding of Viscous Oils. Society of Petroleum Engineers, doi: 10.2118/125365-MS.
Li, Z., Delshad, M., Lotfollahi, M., Koh, H., Luo, H., Chang, H.L., Brennan, B. 2014. Polymer Flooding of a Heavy Oil Reservoir with an Active Aquifer. Society of Petroleum Engineers, doi: 10.2118/169149-MS.
Levitt, D., Jackson, A., Heinson, C., Britton, L.N., Malik, T., Dwarakanath, V., Pope, G.A. 2009. Identification and Evaluation of High-Performance EOR Surfactants. Society of Petroleum Engineers, doi: 10.2118/100089-PA.
Lu, J., Britton, C., Solairaj, S., Liyanage, P.J., Kim, D.H., Adkins, S., Pope, G.A. 2012. Novel Large-Hydrophobe Alkoxy carboxylate Surfactants for Enhanced Oil Recovery. Society of Petroleum Engineers, doi: 10.2118/154261-MS.
Nelson, R.C., Pope, G.A. 1978. Phase Relationships in Chemical Flooding. SPE J. 18 (5): 325-338. SPE-6773-PA. doi: 10.2118/6773-PA.
Nelson, R.C., Lawson, J.B., Thigpen, D.R., Stegemeier, G.L. 1984. Cosurfactant-Enhanced Alkaline Flooding. Paper SPE 12672 presented at the SPE enhanced Oil Recovery Symposium, Tulsa, Oklahoma, 15-18 April. doi: 10.2118/12672-MS.
Panthi, K., Sharma, H., Mohanty, K.K. 2013. ASP Flood of a Viscous Oil in a Carbonate Rock. This paper was presented at the SPE Annual Technical Conference and Exhibition held in New Orleans, Louisiana, USA, 30 September-2 October, 2013. Dio: 10.2118/166230-MS.
Taber, J.J., Martin, F.D., Seright, R.S. 1997. EOR Screening Criteria Revisited-Part 1: Introduction to Screening Criteria and Enhanced Recovery Field Projects. Society of Petroleum Engineers. Doi:10.2118/35385-PA.
Xiao, R, Teletzke, G.F., Lin, M.W., Glotzback, R.C., Aitkulov, A., Yeganeh, M., Jaishankar, A., Hegner, A. 2017. A Novel Mechanism of Alkaline Flooding to Improve Sweep Efficiency for Viscous Oils. SPE-187366-MS. The peper was presented at the SPE Annual Technical Conference and Exhibition held in San Antonio, Texas, USA, 9-11 October 2017.
Wassmuth, F.R., Green, K., Arnold, W., Cameron, N. 2009. Polymer Flood Application to Improve Heavy Oil Recovery at East Bodo. J. Can Pet. Tech., 48 (2). Doi: 10.2118/09-02-55.