Novel Application of Cationic Surfactants for Foams With Wettability Alteration in Oil-Wet Low-Permeability Carbonate Rocks
- Authors
- Pinaki Ghosh (University of Texas at Austin) | Kishore K. Mohanty (University of Texas at Austin)
- DOI
- https://doi.org/10.2118/179598-PA
- Document ID
- SPE-179598-PA
- Publisher
- Society of Petroleum Engineers
- Source
- SPE Journal
- Volume
- 23
- Issue
- 06
- Publication Date
- December 2018
- Document Type
- Journal Paper
- Pages
- 2,218 - 2,231
- Language
- English
- ISSN
- 1086-055X
- Copyright
- 2018.Society of Petroleum Engineers
- Disciplines
- Keywords
- cationic surfactant, wettability alteration, carbonate rocks, Foam, enhanced oil recovery
- Downloads
- 6 in the last 30 days
- 214 since 2007
- Show more detail
- View rights & permissions
SPE Member Price: | USD 12.00 |
SPE Non-Member Price: | USD 35.00 |
Summary
Carbonate rocks are typically heterogeneous at many scales, leading to low waterflood recoveries. Polymers and gels cannot be injected into nonfractured low-permeability carbonates (k < 10 md) because pore throats are smaller than the polymers. Foams have the potential to improve both oil-displacement efficiency and sweep efficiency in such carbonate rocks. However, foams have to overcome two adverse conditions in carbonates: oil-wettability and low permeability. This study evaluates several cationic-foam formulations that combine wettability alteration and foaming in low-permeability oil-wet carbonate cores. Contact-angle experiments were performed on initially oil-wet media to evaluate the wettability-altering capabilities of the surfactant formulations. Static foam-stability tests were conducted to evaluate their foaming performance in bulk; foam-flow experiments (without crude oil) were performed in porous media to estimate the foam strength. Finally, oil-displacement experiments were performed with a crude oil after a secondary gasflood. Two different injection strategies were studied in this work: surfactant slug followed by gas injection and coinjection of surfactant with gas at a constant foam quality. Systematic study of oil-displacement experiments in porous media showed the importance of wettability alteration in increasing tertiary oil recovery for oil-wet media. Several blends of cationic, nonionic, and zwitterionic surfactants were used in the experiments. In-house-developed Gemini cationic surfactant GC 580 was able to alter the wettability from oil-wet to water-wet and also formed strong bulk foam. Static foam tests showed an increase in bulk foam stability with the addition of zwitterionic surfactants to GC 580. Oil-displacement experiments in oil-wet carbonate cores revealed that tertiary oil recovery with injection of a wettability-altering surfactant and foam can recover a significant amount of oil [approximately 25 to 52% original oil in place (OOIP)] over the secondary gasflood. The foam rheology in the presence of oil suggested propagation of only weak foam in oil-wet low-permeability carbonate cores.
File Size | 1 MB | Number of Pages | 14 |
References
Adibhatla, B. and Mohanty, K. K. 2008. Oil Recovery From Fractured Carbonates by Surfactant-Aided Gravity Drainage: Laboratory Experiments and Mechanistic Simulations. SPE Res Eval & Eng 11 (1): 119–130. SPE-99773-PA. https://doi.org/10.2118/99773-PA.
Alvarez, J. O., Neog, A., Jais, A. et al. 2014. Impact of Surfactants for Wettability Alteration in Stimulation Fluids and the Potential for Surfactant EOR in Unconventional Liquid Reservoirs. Presented at the SPE Unconventional Resources Conference, The Woodlands, Texas, 1–3 April. SPE-169001-MS. https://doi.org/10.2118/169001-MS.
Anderson, W. G. 1987. Wettability Literature Survey—Part 4: Effects of Wettability on Capillary Pressure. J Pet Technol 39 (10): 1283–1300. SPE-15271-PA. https://doi.org/10.2118/15271-PA.
Angarska, J. K., Tachev, K. D., Ivanov, I. B. et al. 1997. Effect of Magnesium Ions on the Properties of Foam Films Stabilized With Sodium Dodecyl Sulfate. J. Colloid Interf. Sci. 195 (2): 316–328. https://doi.org/10.1006/jcis.1997.5133.
Arnaudov, L., Denkov, N. D., Surcheva, I. et al. 2001. Effect of Oily Additives on Foamability and Foam Stability. 1. Role of Interfacial Properties. Langmuir 17 (22): 6999–7010. https://doi.org/10.1021/la010600r.
Austad, T. and Milter, J. 1997. Spontaneous Imbibition of Water Into Low Permeable Chalk at Different Wettabilities Using Surfactants. Presented at the International Symposium on Oilfield Chemistry, Houston, 18–21 February. SPE-37236-MS. https://doi.org/10.2118/37236-MS.
Basheva, E. S., Ganchev, D., Denkov, N. D. et al. 2000. Role of Betaine as Foam Booster in the Presence of Silicone Oil Drops. Langmuir 16 (3): 1000–1013. https://doi.org/10.1021/la990777+.
Blaker, T., Aarra, M. G., Skauge, A. et al. 2002. Foam for Gas Mobility Control in the Snorre Field: The FAWAG Project. SPE Res Eval & Eng 5 (4): 317–323. SPE-78824-PA. https://doi.org/10.2118/78824-PA.
Boud, D. C. and Holbrook, O. C. 1958. Gas Drive Oil Recovery Process. US Patent No. 28,665,07A.
Chabert, M., Morvan, M., and Nabzar, L. 2012. Advanced Screening Technologies for the Selection of Dense CO2 Foaming. Presented at the SPE Improved Oil Recovery Symposium, Tulsa, 14–18 April. SPE-154147-MS. https://doi.org/10.2118/154147-MS.
Chilingar, G. V. and Yen, T. F. 1983. Some Notes on Wettability and Relative Permeabilities of Carbonate Reservoir Rocks, II. Energ. Source. 7 (1): 67–75. https://doi.org/10.1080/00908318308908076.
Chou, S. I., Vasicek, S. L., Pisio, D. L. et al. 1992. CO2 Foam Field Trial at North Ward-Estes. Presented at the SPE Annual Technical Conference and Exhibition, Washington, DC, 4–7 October. SPE-24643-MS. https://doi.org/10.2118/24643-MS.
du Pétrole, F. and Malmaison, F. R. 1990. Evaluation of Reservoir Wettability and Its Effect on Oil Recovery. In Interfacial Phenomena in Petroleum Recovery, ed. N. R. Morrow, Chap. 9, 319–376. Boca Raton, Florida: CRC Press.
Falls, A. H., Hirasaki, G. J., Patzek, T. W. et al. 1988. Development of a Mechanistic Foam Simulator: The Population Balance and Generation by Snap-Off. SPE Res Eng 3 (3): 884–892. SPE-14961-PA. https://doi.org/10.2118/14961-PA.
Falls, A. H., Musters, J. J., and Ratulowski, J. 1989. The Apparent Viscosity of Foams in Homogeneous Bead Packs. SPE Res Eval & Eng 4 (2): 155–164. SPE-16048-PA. https://doi.org/10.2118/16048-PA.
Farajzadeh, R., Andrianov, A., and Zitha, P. L. J. 2009. Investigation of Immiscible and Miscible Foam for Enhancing Oil Recovery. Ind. Eng. Chem. Res. 49 (4): 1910–1919. https://doi.org/10.1021/ie901109d.
Farajzadeh, R., Andrianov, A., Krastev, R. et al. 2012. Foam–Oil Interaction in Porous Media: Implications for Foam Assisted Enhanced Oil Recovery. Adv. Colloid Interf. Sci. 183–184 (15 November): 1–13. https://doi.org/10.1016/j.cis.2012.07.002.
Fuseni, A. B., Julaih, A. H., Al-Aseeri, A. A. et al. 2017. Development and Evaluation of Foam-Based Conformance Control for a High Salinity and High Temperature Carbonate. Presented at the SPE Middle East Oil & Gas Show and Conference, Manama, Bahrain, 6–9 March. https://doi.org/10.2118/183772-MS.
Gupta, R. and Mohanty, K. 2010. Temperature Effects on Surfactant-Aided Imbibition Into Fractured Carbonates. SPE J. 15 (3): 588–597. SPE-110204-PA. https://doi.org/10.2118/110204-PA.
Hadjiiski, A., Tcholakova, S., Denkov, N. D. et al. 2001. Effect of Oily Additives on Foamability and Foam Stability. 2. Entry Barriers. Langmuir 17 (22): 7011–7021. https://doi.org/10.1021/la010601j.
Haugen, Å., Fernø, M. A., Graue, A. et al. 2012. Experimental Study of Foam Flow in Fractured Oil-Wet Limestone for Enhanced Oil Recovery. SPE Res Eval & Eng 15 (2): 218–228. SPE-129763-PA. https://doi.org/10.2118/129763-PA.
Holm, L. W. 1968. The Mechanism of Gas and Liquid Flow Through Porous Media in the Presence of Foam. SPE J. 8 (4): 359–369. https://doi.org/10.2118/1848-PA.
Khatib, Z. I., Hirasaki, G. J., and Falls, A. H. 1988. Effects of Capillary Pressure on Coalescence and Phase Mobilities in Foams Flowing Through Porous Media. SPE Res Eng 3 (3): 919–926. SPE-15442-PA. https://doi.org/10.2118/15442-PA.
Kovscek, A. R., Patzek, T. W., and Radke, C. J. 1994. Mechanistic Prediction of Foam Displacement in Multidimensions: A Population Balance Approach. Presented at the SPE/DOE Improved Oil Recovery Symposium, Tulsa, 17–20 April. SPE-27789-MS. https://doi.org/10.2118/27789-MS.
Li, R. F., Hirasaki, G., Miller, C. A. et al. 2012. Wettability Alteration and Foam Mobility Control in a Layered, 2D Heterogeneous Sandpack. SPE J. 17 (4): 1207–1220. SPE-141462-PA. https://doi.org/10.2118/141462-PA.
Mahani, H., Keya, A. L., Berg, S. et al. 2015. Insights Into the Mechanism of Wettability Alteration by Low-Salinity Flooding (LSF) in Carbonates. Energy Fuels 29 (3): 1352–1367. https://doi.org/10.1021/ef5023847.
Mast, R. F. 1972. Microscopic Behavior of Foam in Porous Media. Presented at the Fall Meeting of the Society of Petroleum Engineers of AIME, San Antonio, Texas, 8–11 October. SPE-3997-MS. https://doi.org/10.2118/3997-MS.
Mohan, K., Gupta, R., and Mohanty, K. K. 2011. Wettability Altering Secondary Oil Recovery in Carbonate Rocks. Energy Fuels 25 (9): 3966–3973. https://doi.org/10.1021/ef200449y.
Montaron, B. 2005. Increasing Oil Recovery Factors: A Technical Challenge Key to Future World Energy Supply. Oral presentation given at the AFTP Conference, Paris, October.
Patzek, T. W. 1996. Field Applications of Steam Foam for Mobility Improvement and Profile Control. SPE Res Eng 11 (2): 79–86. SPE-29612-PA. https://doi.org/10.2118/29612-PA.
Ransohoff, T. C. and Radke, C. J. 1988. Mechanisms of Foam Generation in Glass-Bead Packs. SPE Res Eng 3 (2): 573–585. SPE-15441-PA. https://doi.org/10.2118/15441-PA.
Raza, S. H. 1970. Foam in Porous Media: Characteristics and Potential Applications. SPE J. 10 (4): 328–336. SPE-2421-PA. https://doi.org/10.2118/2421-PA.
Roehl, P. O. and Choquette, P. W. eds. 1985. Carbonate Petroleum Reservoirs. Berlin: Springer Science and Business Media.
Rossen, W. R. 1990. Minimum Pressure Gradient for Foam Flow in Porous Media: Effect of Interactions With Stationary Lamellae. J. Colloid Interf. Sci. 139 (2): 457–468. https://doi.org/10.1016/0021-9797(90)90118-8.
Rossen, W. R. and Gauglitz, P. A. 1990. Percolation Theory of Creation and Mobilization of Foams in Porous Media. AIChE J. 36 (8): 1176–1188. https://doi.org/10.1002/aic.690360807.
Rossen, W. R., van Duijn, C. J., Nguyen, Q. P. et al. 2010. Injection Strategies To Overcome Gravity Segregation in Simultaneous Gas and Water Injection Into Homogeneous Reservoirs. SPE J. 15 (1): 76–90. SPE-99794-PA. https://doi.org/10.2118/99794-PA.
Sanchez, J. M. and Hazlett, R. D. 1992. Foam Flow Through an Oil-Wet Porous Medium: A Laboratory Study. SPE Res Eng 7 (1): 91–97. SPE-19687-PA. https://doi.org/10.2118/19687-PA.
Schlumberger Market Analysis. 2007. https://www.slb.com/~/media/Files/industry_challenges/carbonates/brochures/cb_carbonate_reservoirs_07os003.pdf.
Schramm, L. L. and Novosad, J. J. 1992. The Destabilization of Foams for Improved Oil Recovery by Crude Oils: Effect of the Nature of the Oil. J. Pet. Sci. Eng. 7 (1–2): 77–90. https://doi.org/10.1016/0920-4105(92)90010-X.
Schramm, L. L. and Mannhardt, K. 1996. The Effect of Wettability on Foam Sensitivity to Crude Oil in Porous Media. J. Pet. Sci. Eng. 15 (1): 101–113. https://doi.org/10.1016/0920-4105(95)00068-2.
Seethepalli, A., Adibhatla, B., and Mohanty, K. K. 2004. Physicochemical Interactions During Surfactant Flooding of Fractured Carbonate Reservoirs. SPE J. 9 (4): 411–418. SPE-89423-PA. https://doi.org/10.2118/89423-PA.
Sharma, G. and Mohanty, K. 2013. Wettability Alteration in High-Temperature and High-Salinity Carbonate Reservoirs. SPE J. 18 (4): 646–655. SPE-147306-PA. https://doi.org/10.2118/147306-PA.
Siddiqui, S., Talabani, S., Saleh, S. T. et al. 1997. A Laboratory Investigation of Foam Flow in Low-Permeability Berea Sandstone Cores. Presented at the SPE Production Operations Symposium, Oklahoma City, Oklahoma, 9–11 March. SPE-37416-MS. https://doi.org/10.2118/37416-MS.
Singh, R. and Mohanty, K. K. 2015a. Foams Stabilized by In-Situ Surface-Activated Nanoparticles in Bulk and Porous Media. SPE J. 21 (1): 121–130. SPE-170942-PA. https://doi.org/10.2118/170942-PA.
Singh, R. and Mohanty, K. K. 2015b. Synergy Between Nanoparticles and Surfactants in Stabilizing Foams for Oil Recovery. Energy Fuels 29 (2): 467–479. https://doi.org/10.1021/ef5015007.
Singh, R. and Mohanty, K. K. 2016. Foams With Wettability-Altering Capabilities for Oil-Wet Carbonates: A Synergistic Approach. SPE J. 21 (4): 1126–1139. SPE-175027-PA. https://doi.org/10.2118/175027-PA.
Strand, S., Standnes, D. C., and Austad, T. 2003. Spontaneous Imbibition of Aqueous Surfactant Solutions Into Neutral to Oil-Wet Carbonate Cores: Effects of Brine Salinity and Composition. Energy Fuels 17 (5): 1133–1144. https://doi.org/10.1021/ef030051s.
Tang, G. Q. and Morrow, N. R. 1997. Salinity, Temperature, Oil Composition, and Oil Recovery by Waterflooding. SPE Res Eng 12 (4): 269–276. SPE-36680-PA. https://doi.org/10.2118/36680-PA.
Vikingstad, A. K., Skauge, A., Høiland, H. et al. 2005. Foam–Oil Interactions Analyzed by Static Foam Tests. Colloids Surfaces A 260 (1): 189–198. https://doi.org/10.1016/j.colsurfa.2005.02.034.
Wang, L. and Mohanty, K. 2014. Enhanced Oil Recovery in Gasflooded Carbonate Reservoirs by Wettability-Altering Surfactants. SPE J. 20 (1): 60–69. SPE-166283-PA. https://doi.org/10.2118/166283-PA.
Wang, L. K. and Langley, D. F. 1977. Identification and Determination of Ionic Surface Active Agents. Arch. Environ. Con. Tox. 5 (1): 447–456. https://doi.org/10.1007/BF02220924.
Yekeen, N., Manan, M. A., Idris, A. K. et al. 2017. Influence of Surfactant and Electrolyte Concentrations on Surfactant Adsorption and Foaming Characteristics. J. Pet. Sci. Eng. 149 (20 January): 612–622. https://doi.org/10.1016/j.petrol.2016.11.018.
Yousef, A. A., Al-Saleh, S., and Al-Jawfi, M. S. 2011. Smart WaterFlooding for Carbonate Reservoirs: Salinity and Role of Ions. Presented at the SPE Middle East Oil and Gas Show and Conference, Manama, Bahrain, 25–28 September. SPE-141082-MS. https://doi.org/10.2118/141082-MS.
Yu, L. and Wardlaw, N. C. 1986. The Influence of Wettability and Pore-Throat Size Ratio on Snap-Off. J. Colloid Interf. Sci. 109 (2): 461–472. https://doi.org/10.1016/0021-9797(86)90324-3.
Zhang, D. L., Liu, S., Puerto, M. et al. 2006. Wettability Alteration and Spontaneous Imbibition in Oil-Wet Carbonate Formations. J. Pet. Sci. Eng. 52 (13–4): 213–226. https://doi.org/10.1016/j.petrol.2006.03.009.
You may also be interested in…

1 download in the last 30 days
385 downloads since 2007