Novel Large-Hydrophobe Alkoxy Carboxylate Surfactants for Enhanced Oil Recovery
- Jun Lu (Ultimate EOR Services) | Christopher Britton (Ultimate EOR Services) | Sriram Solairaj (ConocoPhillips) | Pathma J. Liyanage (The University of Texas at Austin) | Do Hoon Kim (Chevron) | Stephanie Adkins (Ultimate EOR Services) | Gayani W. P. Pinnawala Arachchilage (The University of Texas at Austin) | Upali Weerasooriya (The University of Texas at Austin) | Gary A. Pope (The University of Texas at Austin)
- Document ID
- Society of Petroleum Engineers
- SPE Journal
- Publication Date
- December 2014
- Document Type
- Journal Paper
- 1,024 - 1,034
- 2014.Society of Petroleum Engineers
- 2.5.2 Fracturing Materials (Fluids, Proppant), 5.4.7 Chemical Flooding Methods (e.g., Polymer, Solvent, Nitrogen, Immiscible CO2, Surfactant, Vapex)
- surfactant/polymer flood, carboxylate surfactant, chemical EOR
- 9 in the last 30 days
- 1,653 since 2007
- Show more detail
- View rights & permissions
|SPE Member Price:||USD 10.00|
|SPE Non-Member Price:||USD 30.00|
A new class of surfactants has been developed and tested for chemical enhanced oil recovery (EOR) that shows excellent performance under harsh reservoir conditions. These novel Guerbet alkoxy carboxylate (GAC) surfactants fulfill this need by providing large, branched hydrophobes; flexibility in the number of alkoxylate groups; and stability in both alkaline and nonalkaline environments at temperatures up to at least 120°C. The new carboxylate surfactants were recently manufactured at a cost comparable to other commercial EOR surfactants by use of commercially available feedstocks. A formulation containing the combination of a carboxylate surfactant and a sulfonate cosurfactant resulted in a synergistic interaction that has the potential to reduce the total chemical cost further. One can obtain both ultralow interfacial tension (IFT) with the oils and a clear aqueous solution (even under harsh conditions such as high salinity, high hardness, and high temperature with or without alkali) with these new large-hydrophobe alkoxy carboxylate surfactants. Both sandstone and carbonate corefloods were conducted with excellent results. Formulations have been developed for both active oils (contains naturally occurring carboxylic acids) and inactive oils (oils that do not produce sufficient amounts of soap/carboxylic acid), with excellent results.
|File Size||1 MB||Number of Pages||11|
Adkins, S., Liyanage, P.J., Arachchilage, G.W.P. et al. 2010.A New Process for Manufacturing and Stabilizing High-Performance EOR Surfactants at Low Cost for High-Temperature, High-Salinity Oil Reservoirs. Presented at the SPE IOR Symposium, Tulsa, Oklahoma, 25–28 April. SPE-129923-MS. http://dx.doi.org/10.2118/129923-MS.
Adkins, S., Pinnawala-Arachchilage, G., Solairaj, S. et al. 2012. Development of Thermally and Chemically Stable Large-Hydrophobe Alkoxy Carboxylate Surfactants. Presented at the SPE IOR Symposium, Tulsa, Oklahoma, 14–18 April. SPE-154256-MS. http://dx.doi.org/10.2118/154256-MS.
Bourrel, M. and Schechter, R.S. 1988. Microemulsions and Related Systems, New York: Marcel Dekker, Inc.
Cayias, J.L., Schechter, R.S., and Wade, W.H. 1976. Modeling Crude Oils for Low Interfacial Tension. Presented at the SPE-AIME IOR Symposium, Tulsa, Oklahoma, 22–24 March. SPE-5813-MS. http://dx.doi.org/10.2118/5813-MS.
Flaaten, A.K., Nguyen, Q.P., Zhang, J. et al. 2010. Alkaline/Surfactant/Polymer Chemical Flooding Without the Need for Soft Water. SPE J. 15 (1): 184–196. SPE-116754-PA. http://dx.doi.org/10.2118/116754-PA.
Glinsmann, G.R. 1979. Surfactant Flooding With Microemulsions Formed In-situ—Effect of Oil Characteristics. Presented at the SPE-AIME ATCE Symposium, Dallas, Texas, 11–13 February. http://dx.doi.org/10.2118/8326-MS.
Glover, C.J., Puerto, M.C., Maerker, J.M. et al. 1979. Surfactant Phase Behavior and Retention in Porous Media. SPE J.19 (3): 183–193. SPE-7053-PA. http://dx.doi.org/10.2118/7053-PA.
Green, D.W. and Willhite, G.P. 1998. Enhanced Oil Recovery, Vol. 6, SPE Textbook Series, Henry L. Doherty Memorial Fund of AIME, Richardson, Texas: Society of Petroleum Engineers.
Hill, H.J., Helfferich, F.G., Lake, L.W. et al. 1977. Cation Exchange and Chemical Flooding. J. Pet Technol 29 (10): 1336–1338. SPE-6642-PA. http://dx.doi.org/10.2118/6642-PA.
Hirasaki, G.J., van Domselaar, H.R., and Nelson, R.C. 1983. Evaluation of the Salinity Gradient Concept in Surfactant Flooding. SPE J. 23 (3): 486–500. SPE-8825-PA. http://dx.doi.org/10.2118/8825-PA.
Huh, C. 1979. Interfacial Tensions and Solubilizing Ability of a Microemulsion Phase That Coexists With Oil and Brine. J. Colloid Interface Sci. 71 (2): 408–426. http://dx.doi.org/10.1016/0021-9797(79)90249-2.
Jackson, A.C. 2006. Experimental Study of the Benefits of Sodium Carbonate on Surfactants for Enhanced Oil Recovery, MS thesis, University of Texas at Austin, Austin Texas (December 2006).
Levitt, D.B., Dufour, S., Pope, G.A. et al. 2012. Design of an ASP Flood in a High-Temperature, High-Salinity, Low-Permeability Carbonate. Presented at the IPTC, Bangkok, Thailand, 7–9 February. IPTC 14915.
Levitt, D.B., Jackson, A.C., Heinson, C. et al. 2009. Identification and Evaluation of High-Performance EOR Surfactants. SPE Res. Eval. Eng. 12 (2): 243–253. SPE-100089-PA. http://dx.doi.org/10.2118/100089-PA.
Pope, G.A., Lake, L.W., and Helfferich, F.G. 1978. Cation Exchange in Chemical Flooding: Part 1—Basic Theory Without Dispersion. SPE J. 18 (6): 418–434. SPE-6771-PA. http://dx.doi.org/10.2118/6771-PA.
Pope, G.A., Wang, B., and Tsaur, K. 1979. A Sensitivity Study of Micellar/Polymer Flooding. SPE J. 19 (6): 357–368. SPE-7079-PA. http://dx.doi.org/10.2118/7079-PA.
Puerto, M., Hirasaki, G.J., Miller, C.A. et al. 2012. Surfactant Systems for EOR in High-Temperature, High-Salinity Environments. SPE J. 17 (1): 11–19. SPE-129675-PA. http://dx.doi.org/10.2118/129675-PA.
Puerto, M.C. and Reed, R.L. 1983. A Three Parameter Representation of Surfactant/Oil/Brine Interaction. SPE J. 23 (4): 669–682. SPE-10678-PA. http://dx.doi.org/10.2118/10678-PA.
Roshanfekr, M. 2010. Effect of Pressure and Methane on Microemulsion Phase Behavior and Its Impact on Surfactant-Polymer Flood Oil Recovery, PhD dissertation, University of Texas at Austin (December 2010).
Roshanfekr, M., Johns, R.T., Pope, G.A. et al. 2012. Simulation of the Effect of Pressure and Solution Gas on Oil Recovery From Surfactant/Polymer Floods. SPE J. 17 (3): 705–716. SPE-125095-PA. http://dx.doi.org/10.2118/125095-PA.
Sahni, V., Dean, R.M., Britton, C. et al. 2010. Low-Cost, High-Performance Chemicals for Enhanced Oil Recovery. Proc., SPE Improved Oil Recovery Symposium, Tulsa, Oklahoma, 24–28 April. SPE-130007-MS. http://dx.doi.org/10.2118/130007-MS.
Salager, J.L., Bourrel, M.U., Schechter, R.S. et al. 1979. Mixing Rules for Optimum Phase-Behavior Formulations of Surfactant/Oil/Water Systems. SPE J. 19 (5): 271–278. SPE-7584-PA. http://dx.doi.org/10.2118/7584-PA.
Solairaj, S. 2011. New Method of Predicting Optimum Surfactant Structure for EOR, MS thesis, University of Texas at Austin, Austin Texas (December 2011).
Solairaj, S., Britton, C., Lu, J. et al. 2012. New Correlation to Predict the Optimum Surfactant Structure for EOR. Presented at the SPE IOR Symposium, Tulsa, Oklahoma, 14–18 April. SPE-154262-MS. http://dx.doi.org/10.2118/154262-MS.
Yang, H., Britton, C., Liyanage, P.J. et al. 2010. Low-cost, High-performance Chemicals for Enhanced Oil Recovery. Presented at the SPE IOR Symposium, Tulsa, Oklahoma, 24–28 April. SPE-129978-MS. http://dx.doi.org/10.2118/129978-MS.
Zhao, P., Jackson, A.C., Britton, C. et al. 2008 Development of High-Performance Surfactants for Difficult Oils. Presented at the SPE/DOE IOR Symposium, Tulsa, Oklahoma, 20–23 April. SPE-113432-MS. http://dx.doi.org/10.2118/113432-MS.