Ultralow-Interfacial-Tension Foam Injection Strategy Investigation in High Temperature Ultra-High Salinity Fractured Carbonate Reservoirs
- Pengfei Dong (Rice University) | Maura Puerto (Rice University) | Kun Ma (Total) | Khalid Mateen (Total) | Guangwei Ren (Total) | Gilles Bourdarot (Total) | Danielle Morel (Total) | Sibani Lisa Biswal (Rice University) | George Hirasaki (Rice University)
- Document ID
- Society of Petroleum Engineers
- SPE Improved Oil Recovery Conference, 14-18 April, Tulsa, Oklahoma, USA
- Publication Date
- Document Type
- Conference Paper
- 2018. Society of Petroleum Engineers
- 2.5.2 Fracturing Materials (Fluids, Proppant), 1.10 Drilling Equipment, 1.10 Drilling Equipment, 5 Reservoir Desciption & Dynamics, 5.4 Improved and Enhanced Recovery, 2.4 Hydraulic Fracturing, 5.2 Reservoir Fluid Dynamics, 2 Well completion, 1.6 Drilling Operations, 1.6.9 Coring, Fishing, 5.7.2 Recovery Factors, 5.4 Improved and Enhanced Recovery, 5.8 Unconventional and Complex Reservoirs, 5.7 Reserves Evaluation, 5.2 Reservoir Fluid Dynamics, 5.5.2 Core Analysis, 5.4.1 Waterflooding, 5.8.7 Carbonate Reservoir
- Foam, Ultrahigh Salinity, Salinity Gradient, Fractured Carbonate, Ultralow-Interfacial-Tension
- 3 in the last 30 days
- 241 since 2007
- Show more detail
- View rights & permissions
|SPE Member Price:||USD 8.50|
|SPE Non-Member Price:||USD 25.00|
Oil recovery in many carbonate reservoirs is challenging due to unfavorable conditions such as oil-wet surface wettability, high reservoir heterogeneity and high brine salinity. We present the feasibility and injection strategy investigation of ultralow-interfacial-tension (ultralow-IFT) foam in a high temperature (above 80°C), ultra-high formation salinity (above 23% TDS) fractured carbonate reservoir.
Because a salinity gradient is generated between injection sea water (4.2% TDS) and formation brine (23% TDS), a frontal-dilution map was created to simulate frontal displacement processes and thereafter used to optimize surfactant formulations. IFT measurements and bulk foam tests were also conducted to study the salinity gradient effect to ultralow-IFT foam performance. Ultralow-IFT foam injection strategies were investigated through a series of core flood experiments in both homogenous and fractured core systems with initial two-phase saturation. The representative fractured system included a well-defined fracture by splitting core sample lengthwise and controllable initial oil/brine saturation in the matrix by closing the fracture with a rubber sheet at high confining pressure.
The surfactant formulation showed ultra-low IFT (10-2-10-3 mN/m magnitude) at the displacement front and good foamability at under-optimum conditions. Both ultralow-IFT and foamability properties were found to be sensitive to the salinity gradient. Ultralow-IFT foam flooding achieved over 60% incremental oil recovery compared to water flooding in oil-wet fractured systems due to the selective diversion of ultralow-IFT foam. This effect resulted in crossflow near foam front, with surfactant solution (or weak foam) primarily diverted from the fracture into the matrix before the foam front, and oil/high-salinity brine flowed back to the fracture ahead of the front. The crossflow of oil/high-salinity brine from the matrix to the fracture was found to make it challenging for foam propagation in the fractured system by forming Winsor II condition near foam front and hence killing the existing foam.
Results in this work demonstrated the feasibility of ultralow-IFT foam in high temperature, ultra-high salinity fractured carbonate reservoirs and investigated the injection strategy to enhance the low-IFT foam performance. The ultralow-IFT formulation helped mobilize the residual oil for better displacement efficiency. The selective diversion of foam makes it a good candidate as a mobility control agent in fractured system for better sweep efficiency.
|File Size||2 MB||Number of Pages||27|
Conn, Charles A., Kun Ma, George J. Hirasaki, and Sibani Lisa Biswal. 2014. "Visualizing Oil Displacement with Foam in a Microfluidic Device with Permeability Contrast." Lab on a Chip 14 (20):3968–77. https://doi.org/10.1039/C4LC00620H.
Cottin, Christophe, Danielle Christine Morel, David Levitt, Philippe Robert Cordelier, and Gary Arnold Pope. 2012. "(Alkali) Surfactant Gas Injection: Attractive Laboratory Results under the Harsh Salinity and Temperature Conditions of Middle East Carbonates." In. Society of Petroleum Engineers. https://doi.org/10.2118/161727-MS.
Cui, Leyu, Kun Ma, Maura Puerto, Ahmed A. Abdala, Ivan Tanakov, Lucas J. Lu, Yunshen Chen, . 2016. "Mobility of Ethomeen C12 and Carbon Dioxide (CO2) Foam at High Temperature/High Salinity and in Carbonate Cores." SPE Journal 21 (04):1,151–1,163. https://doi.org/10.2118/179726-PA.
Dong, Pengfei, Maura Puerto, Kun Ma, Khalid Mateen, Guangwei Ren, Gilles Bourdarot, Danielle Morel, Maurice Bourrel, Sibani Lisa Biswal, and George Hirasaki. 2017. "Low-Interfacial-Tension Foaming System for Enhanced Oil Recovery in Highly Heterogeneous/Fractured Carbonate Reservoirs." In. Society of Petroleum Engineers. https://doi.org/10.2118/184569-MS.
Farajzadeh, R., M. Lotfollahi, A. A. Eftekhari, W. R. Rossen, and G. J. H. Hirasaki. 2015. "Effect of Permeability on Implicit-Texture Foam Model Parameters and the Limiting Capillary Pressure." Energy & Fuels, April. https://doi.org/10.1021/acs.energyfuels.5b00248.
Guo, Hua, Pacelli L. J. Zitha, Rien Faber, and Marten Buijse. 2012. "A Novel Alkaline/Surfactant/Foam Enhanced Oil Recovery Process." SPE Journal 17 (04):1,186–1,195. https://doi.org/10.2118/145043-PA.
Gupta, R., and K. K. Mohanty. 2011. "Wettability Alteration Mechanism for Oil Recovery from Fractured Carbonate Rocks." Transport in Porous Media 87 (2):635–52. https://doi.org/10.1007/s11242-010-9706-5.
Healy, R.N., R.L. Reed, and D.G. Stenmark. 1976. "Multiphase Microemulsion Systems." Society of Petroleum Engineers Journal 16 (03):147–60. https://doi.org/10.2118/5565-PA.
Hirasaki, G. J., H. R. van Domselaar, and R. C. Nelson. 1983. "Evaluation of the Salinity Gradient Concept in Surfactant Flooding." Society of Petroleum Engineers Journal 23 (03):486–500. https://doi.org/10.2118/8825-PA.
Hirasaki, George J. 1981. "Application of the Theory of Multicomponent, Multiphase Displacement to Three-Component, Two-Phase Surfactant Flooding." Society of Petroleum Engineers Journal 21 (02):191–204. https://doi.org/10.2118/8373-PA.
Jian, Guoqing, Maura Puerto, Anna Wehowsky, Clarence Miller, George J. Hirasaki, and Sibani L. Biswal. 2018. "Characterizing Adsorption of Associating Surfactants on Carbonates Surfaces." Journal of Colloid and Interface Science 513 (March):684–92. https://doi.org/10.1016/j.jcis.2017.11.041.
Jong, Stephen, Nhut M. Nguyen, Calvin M. Eberle, Long X. Nghiem, and Quoc P. Nguyen. 2016. "Low Tension Gas Flooding as a Novel EOR Method: An Experimental and Theoretical Investigation." In. Society of Petroleum Engineers. https://doi.org/10.2118/179559-MS.
Li, Robert F., George Hirasaki, Clarence A. Miller, and Shehadeh K. Masalmeh. 2012. "Wettability Alteration and Foam Mobility Control in a Layered, 2D Heterogeneous Sandpack." SPE Journal 17 (04):1,207–1,220. https://doi.org/10.2118/141462-PA.
Li, Robert Feng, Wei Yan, Shunhua Liu, George Hirasaki, and Clarence A. Miller. 2010. "Foam Mobility Control for Surfactant Enhanced Oil Recovery." SPE Journal 15 (04):928–42. https://doi.org/10.2118/113910-PA.
Liu, Shunhua, Danhua Zhang, Wei Yan, Maura Puerto, George J. Hirasaki, and Clarence A. Miller. 2008. "Favorable Attributes of Alkaline-Surfactant-Polymer Flooding." SPE Journal 13 (01):5–16. https://doi.org/10.2118/99744-PA.
Lu, Jun, Ali Goudarzi, Peila Chen, Do Hoon Kim, Christopher Britton, Mojdeh Delshad, Kishore K. Mohanty, Upali Peter Weerasooriya, and Gary Arnold Pope. 2012. "Surfactant Enhanced Oil Recovery from Naturally Fractured Reservoirs." In. https://doi.org/10.2118/159979-MS.
Lu, Jun, Ali Goudarzi, Peila Chen, Do Hoon Kim, Mojdeh Delshad, Kishore K. Mohanty, Kamy Sepehrnoori, Upali P. Weerasooriya, and Gary A. Pope. 2014. "Enhanced Oil Recovery from High-Temperature, High-Salinity Naturally Fractured Carbonate Reservoirs by Surfactant Flood." Journal of Petroleum Science and Engineering 124 (December):122–31. https://doi.org/10.1016/j.petrol.2014.10.016.
Ma, Kun, Rachel Liontas, Charles A. Conn, George J. Hirasaki, and Sibani Lisa Biswal. 2012. "Visualization of Improved Sweep with Foam in Heterogeneous Porous Media Using Microfluidics." Soft Matter 8 (41):10669–75. https://doi.org/10.1039/C2SM25833A.
Nelson, R. C., and G. A. Pope. 1978. "Phase Relationships in Chemical Flooding." Society of Petroleum Engineers Journal 18 (05):325–38. https://doi.org/10.2118/6773-PA.
Puerto, Maura, George J. Hirasaki, Clarence A. Miller, and Julian R. Barnes. 2012. "Surfactant Systems for EOR in High-Temperature, High-Salinity Environments." SPE Journal 17 (01):11–19. https://doi.org/10.2118/129675-PA.
Puerto, Maura, José Luis López Salinas, Clarence A. Miller, and George Hirasaki. 2015. Ultra-Low-Tension Compositions and Their Use in Enhanced Oil Recovery. 20,150,267,104, issued September 2015. http://www.freepatentsonline.com/y2015/0267104.html.
Song, Jin, Yongchao Zeng, Le Wang, Xindi Duan, Maura Puerto, Walter G. Chapman, Sibani L. Biswal, and George J. Hirasaki. 2017. "Surface Complexation Modeling of Calcite Zeta Potential Measurements in Brines with Mixed Potential Determining Ions (Ca2+, CO32-, Mg2+, SO42-) for Characterizing Carbonate Wettability." Journal of Colloid and Interface Science 506 (November):169–79. https://doi.org/10.1016/j.jcis.2017.06.096.
Xiao, Siyang, Yongchao Zeng, Eric D. Vavra, Peng He, Maura Puerto, George J. Hirasaki, and Sibani L. Biswal. 2017. "Destabilization, Propagation, and Generation of Surfactant-Stabilized Foam during Crude Oil Displacement in Heterogeneous Model Porous Media." Langmuir, October. https://doi.org/10.1021/acs.langmuir.7b02766.
Xu, Ke, Peixi Zhu, Chun Huh, and Matthew T. Balhoff. 2015. "Microfluidic Investigation of Nanoparticles' Role in Mobilizing Trapped Oil Droplets in Porous Media." Langmuir 31 (51):13673–79. https://doi.org/10.1021/acs.langmuir.5b03733.
Yan, Wei, Clarence A. Miller, and George J. Hirasaki. 2006. "Foam Sweep in Fractures for Enhanced Oil Recovery." Colloids and Surfaces A: Physicochemical and Engineering Aspects 282–283 (July):348–59. https://doi.org/10.1016/j.colsurfa.2006.02.067.
Yu, Jianjia, Cheng An, Di Mo, Ning Liu, and Robert L. Lee. 2012. "Foam Mobility Control for Nanoparticle-Stabilized Supercritical CO2 Foam." In. Society of Petroleum Engineers. https://doi.org/10.2118/153336-MS.