Investigation of Modified Water Chemistry for Improved Oil Recovery: Application of DLVO Theory and Surface Complexation Model
- Alireza Sanaei (The University of Texas at Austin) | Shayan Tavassoli (The University of Texas at Austin) | Kamy Sepehrnoori (The University of Texas at Austin)
- Document ID
- Society of Petroleum Engineers
- SPE Western Regional Meeting, 22-26 April, Garden Grove, California, USA
- Publication Date
- Document Type
- Conference Paper
- 2018. Society of Petroleum Engineers
- 5.2 Reservoir Fluid Dynamics, 5.4 Improved and Enhanced Recovery, 5.2 Reservoir Fluid Dynamics, 5 Reservoir Desciption & Dynamics, 5.4 Improved and Enhanced Recovery, 5.5.2 Core Analysis, 5.4.1 Waterflooding
- Low Salinity Waterflooding, DLVO theory, Wettability alteration, Surface complexation, Zeta-potential
- 2 in the last 30 days
- 240 since 2007
- Show more detail
- View rights & permissions
|SPE Member Price:||USD 9.50|
|SPE Non-Member Price:||USD 28.00|
It is widely accepted that oil recovery during waterflooding can be improved by modifying the composition of the injected brine. A typical approach is diluting the formation water to a specific lower salinity. However, recent experimental studies report the adverse effect of formation water dilution on oil recovery for specific oil/brine/rock systems. The adverse effect depends on the interactions within the system and is more pronounced in carbonates. In this study, we investigated the effect of water composition on the performance of low salinity water injection by considering the complex interplay interaction of oil, brine, and rock system.
We used a coupled in-house compositional simulator and geochemical (IPhreeqc) framework for this study. Using this simulator we were able to capture true physics of the modified salinity waterflooding process. First, employing PHREEQC, we developed a surface complexation model for oil and rock surfaces to calculate the zeta-potential at these two surfaces. Second, we considered a water film between oil and rock and used DLVO theory to calculate the attractive/repulsive forces between oil and rock surfaces. Furthermore, we used the augmented Young-Laplace equation to calculate the resulting contact angle of the system. Then, we defined an interpolating parameter as a function of the calculated contact angle to predict wettability alteration. Finally, the geochemistry model was implemented in UTCOMP-IPhreeqc to investigate the effect of modified salinity water injection on wettability alteration and enhanced oil recovery. In order to validate our approach, the results of our simulations were compared with a recently published coreflood experiment.
Our results show that in carbonates, the charge of the oil/brine and rock/brine surfaces is a determining factor for the success of modified salinity waterflooding. Our contact angle calculations using DLVO theory and the augmented Young-Laplace equation accurately estimated the dynamic trend of contact angle during low salinity flood. Moreover, our zeta potential calculations based on surface complexation model reproduced the experimental data of oil/brine and brine/calcite zeta potential measurements. Modeling wettability alteration as a function of contact angle was sufficient to predict the low salinity effect in carbonates. Similar approach can be used to model low salinity effect in sandstones. We believe this is the first study that a comprehensive compositional reactive transport simulator is used to assess modified salinity waterflooding as a function of contact angle, employing DLVO theory and surface complexation model.
|File Size||1 MB||Number of Pages||27|
Al-Attar, H. H.,Mahmoud, M. Y.,Zekri, A. Y.,Almehaideb, R., and Ghannam, M. 2013b. Low-Salinity Flooding in a Selected Carbonate Reservoir: Experimental Approach. Journal of Petroleum Exploration and Production Technology, 3(2), 139149. doi: 10.1007/s13202-013-0052-3.
Al-Shalabi, E., Seperhrnoori, K. and Pope, G. 2015. Geochemical Interpretation of Low-Salinity Water Injection in Carbonate Oil Reservoirs. SPE J. 20 (6): 1212–1226. SPE-169101-PA. http://dx.doi.org/10.2118/169101-PA.
Alameri, W., Teklu, T. W.,Graves, R. M.. 2014. Wettability Alteration during Low-Salinity Waterflooding in Carbonate Reservoir Cores. Paper SPE-171529 presented at SPE Asia Pacific Oil & Gas Conference and Exhibition, Adelaide, Australia, 14-16 October. http://dx.doi.org/10.2118/171529-MS.
Austad, T., Shariatpanahi, S. F.,Strand, S., Black, C. J. J., and Webb, K. J. 2011. Conditions for a Low-Salinity Enhanced Oil Recovery (EOR) Effect in Carbonate Oil Reservoirs. Energy & fuels, 26(1), 569–575. doi: 10.1021/ef201435g.
Derjaguin B. and Landau L. 1993. Theory of the Stability of Strongly Charged Lyophobic Sols and of the Adhesion of Strongly Charged Particles in Solutions of Electrolytes, Progress in Surface Science 43(1-4): 30–59. https://doi.org/10.1016/0079-6816(93)90013-L.
Fathi, S. J.,Austad, T. and Strand, S. 2012. Water-Based Enhanced Oil Recovery (EOR) by "Smart water" in Carbonate Reservoirs. Presented at the SPE EOR Conference at Oil and Gas West Asia, Muscat, Oman, 16-18 April. SPE-154570-MS. http://dx.doi.org/10.2118/154570-MS.
Gupta, R., Smith, P. G.,Hu, L.. 2011. Enhanced Waterflood for Middle East Carbonate Cores - Impact of Injection Water Composition. Paper SPE-142668 presented at the SPE Middle East Oil and Gas Show and Conference, Manama, Bahrain, 25-28 September. http://dx.doi.org/10.2118/142668-MS.
Hiorth, A., Cathles, L. M., and Madland, M. V. 2010. The Impact of Pore Water Chemistry on Carbonate Surface Charge and Oil Wettability. Transport in porous media. 85(1), 1–21. doi: 10.1007/s11242-010-9543-6.
Jackson M.D., Vinogradov J.,Hamon G., and Chamerois M. 2016a. Evidence, Mechanisms and Improved Understanding of Controlled Salinity Waterflooding Part 1: Sandstones. Fuel 185: 772–793. https://doi.org/10.1016/j.fuel.2016.07.075.
Nasralla, R. A.,Sergienko, E., Masalmeh, S. K., van der Linde, H. A.,Brussee, N. J.,Mahani, H., … and Alqarshubi, I. 2014. Demonstrating the Potential of Low-Salinity Waterflood to Improve Oil Recovery in Carbonate Reservoirs by Qualitative Coreflood. Paper SPE-172010 presented in Abu Dhabi International Petroleum Exhibition and Conference.
Nasralla, R. A.,Snippe, J. R. and Farajzadeh, R. 2015. Coupled Geochemical-Reservoir Model to Understand the Interaction between Low Salinity Brines and Carbonate Rock. Paper SPE-174661 presented at the SPE Enhanced Oil Recovery Conference, Kuala Lumpur, 11-13 August. http://dx.doi.org/10.2118/174661-MS.
Romanuka, J., Hofman, J., Ligthelm, D. J.,Suijkerbuijk, B., Marcelis, F., Oedai, S., … Austad, T. 2012. Low Salinity EOR in Carbonates. Paper SPE-153869 presented at the SPE Improved Oil Recovery Symposium. Tulsa, Oklahoma, USA. 14-18 April. doi:10.2118/153869-MS.
Tagavifar, M., Jang, S. H.,Sharma, H., Wang, D., Chang, L. Y.,Mohanty, K., and Pope, G. A. 2018. Effect of pH on Adsorption of Anionic Surfactants on Limestone: Experimental Study and Surface Complexation Modeling. Colloids and Surfaces A: Physicochemical and Engineering Aspects, 538, 549–558, doi:10.1016/j.colsurfa.2017.11.050.
Vo, L.T.,Gupta, R., Hehmeyer, O.J., 2012, January 1. Ion Chromatography Analysis of Advanced Ion Management Carbonate Coreflood Experiments. Paper SPE-161821 presented at the Abu Dhabi International Petroleum Conference and Exhibition. https://doi.org/10.2118/161821-MS.
Yousef, A. A.,Al-Saleh, S., Al-Kaabi, A. U., and Al-Jawfi, M. S. 2010. Laboratory Investigation of Novel Oil Recovery Method for Carbonate Reservoirs. Paper SPE-137634 presented at the Canadian Unconventional Resources and International Petroleum Conference. Calgary, Alberta, Canada. 19-21 October. doi:10.2118/137634-MS.
Zhang, P. and Austad, T. 2006. Wettability and Oil Recovery from Carbonates: Effects of Temperature and Potential Determining Ions. Colloid. Surface. A 279 (1-3): 179–187. http://dx.doi.org/10.1016/j.colsurfa.2006.01.009.
Zhang, P., Tweheyo, M. T., and Austad, T. 2007. Wettability Alteration and Improved Oil Recovery by Spontaneous Imbibition of Seawater into Chalk: Impact of the Potential Determining Ions Ca2+, Mg2+, and SO42-. Colloids and Surfaces A: Physicochemical and Engineering Aspects, 301(1), 199–208. doi: 10.1016/j.colsurfa.2006.12.058.