Performance Comparison of Novel Chemical Agents in Improving Oil Recovery from Tight Sands Through Spontaneous Imbibition
- Hai Huang (Xi'an Shiyou University, Shaanxi Key Laboratory of Advanced Stimulation Technology for Oil & Gas Reservoirs) | Tayfun Babadagli (University of Alberta) | Xin Chen (University of Alberta) | Huazhou Li (University of Alberta)
- Document ID
- Society of Petroleum Engineers
- SPE International Conference on Oilfield Chemistry, 8-9 April, Galveston, Texas, USA
- Publication Date
- Document Type
- Conference Paper
- 2019. Society of Petroleum Engineers
- 2 Well completion, 2.4 Hydraulic Fracturing, 2.5.2 Fracturing Materials (Fluids, Proppant)
- Tight sands, Spontaneous imbibition, New-Generation Chemicals, Water flooding
- 6 in the last 30 days
- 179 since 2007
- Show more detail
- View rights & permissions
|SPE Member Price:||USD 9.50|
|SPE Non-Member Price:||USD 28.00|
Tight sands are abundant in nanopores leading to a high capillary pressure and normally a low fluid injectivity. As such, spontaneous imbibition might be an effective mechanism for improving oil recovery from tight sands after fracturing. The chemical agents added to the injected water can alter the interfacial properties, which could help further enhance the oil recovery by spontaneous imbibition. This study explores the possibility of using novel chemicals to enhance oil recovery from tight sands via spontaneous imbibition. We experimentally examine the effects of more than ten different chemical agents on spontaneous imbibition, including a cationic surfactant (C12TAB), two anionic surfactants (O242 and O342), an ionic liquid (BMMIM BF4), a high pH solution (NaBO2), and a series of house-made deep eutectic solvents (DES3-7, 9, 11 and 14). Experimental results indicate that the ionic liquid and cationic surfactant used in this study are detrimental to spontaneous imbibition and decrease the oil recovery from tight sands. The high pH NaBO2 solution does not demonstrate significant effect on improving oil recovery, even though it significantly reduces oil-water interfacial tension (IFT). The anionic surfactants (O242 and O342) are effective in enhancing oil recovery from tight sands through oil-water IFT reduction and emulsification effects. The DESs drive the rock surface to be more water-wet and a specific formulation (DES9) leads to much improvement on oil recovery under counter-current imbibition condition. This preliminary study would provide some knowledge about how to optimize the selection of chemicals for improving oil recovery from tight reservoirs.
|File Size||1 MB||Number of Pages||13|
Alvarez, J.O. and Schechter, D.S. 2017. Wettability Alteration and Spontaneous Imbibition in Unconventional Liquid Reservoirs by Surfactant Additives. SPE Res. Eval. Eng. 20(1): 107-117. DOI:10.2118/177057-PA.
Al-Weheibi, I.,Al-Hajri R.,Al-Wahaibi, Y.et al. 2015. Oil Recovery Enhancement in Middle East Heavy Oil Field Using Malonic Acid based Deep Eutectic Solvent. Presented at the SPE Middle East Oil & Gas Show and Conference held in Manama, Bahrain, 8-11 March. DOI:10.2118/172592-MS.
Arihara, N.,Yoneyama, T.,Akita, Y.et al. 1999. Oil Recovery Mechanisms of Alkali-Surfactant-Polymer Flooding. Presented at the 1999 SPE Asia Pacific Oil and Gas Conference and Exhibition held in Jakarta, Indonesia, 20-22 April. DOI:10.2118/54330-MS.
Babadagli, T. 2001a. Dynamics of Capillary Imbibition When Surfactant, Polymer, and Hot Water Are Used as Aqueous Phase for Oil Recovery. J Colloid Interf. Sci. 246: 203-213. DOI:10.1006/jcis.2001.8015.
Babadagli, T. 2001b. Scaling of Co-Current and Counter-Current Capillary Imbibition for Surfactant and Polymer Injection in Naturally Fractured Reservoirs. SPE J. 6(4): 465-478. DOI:10.2118/74702-PA.
Babadagli, T. 2003. Analysis of Oil Recovery by Spontaneous Imbibition of Surfactant Solution. Presented at the SPE International Improved Oil Recovery Conference in Asia Pacific, 20-21 October, Kuala Lumpur, Malaysia. DOI:10.2523/84866-MS.
Babadagli, T.,Sahin, S.,Kalfa, U.et al. 2009. Evaluation of Steam Injection Potential and Improving Ongoing CO2 Injection of the Bati Raman Field, Turkey. J. Pet. Sci. Eng. 68(1-2): 107-117. DOI:10.1016/j.petrol.2009.06.015.
Barnes, J.R.,Dirkzwager, H.,Smit, J.R.et al. 2010. Application of Internal Olefin Sulfonates and Other Surfactants to EOR. Part 1: Structure - Performance Relationships for Selection at Different Reservoir Conditions. Presented at the 2010 SPE Improved Oil Recovery Symposium held in Tulsa, Oklahoma, USA, 24-28 April. DOI:10.2118/129766-MS.
Barnes, J.R.,Smit, J.P.,Smit, J.R.et al. 2008. Development of Surfactants for Chemical Flooding at Difficult Reservoir Conditions. Presented at the 2008 SPE/DOE Improved Oil Recovery Symposium held in Tulsa, Oklahoma, U.S.A., 19-23 April. DOI:10.2118/113313-MS.
Behbahani, H.S.,Donato, G.D.,Blunt, M.J. 2006. Simulation of Counter-Current Imbibition in Water-Wet Fractured Reservoirs. J. Pet. Sci. Eng. 50: 21-39. DOI:10.1016/j.petrol.2005.08.001.
Cao, N.,Mohammed, M.A.,Babadagli, T. 2015. Wettability Alteration of Heavy-Oil/Bitumen Containing Carbonates Using Solvents, High pH Solutions and Nano/Ionic Liquids. Presented at the Offshore Technology Conference Brasil held in Rio de Janeiro, Brazil, 27-29 October. DOI:10.4043/26068-MS.
Dutta, R.,Lee, C.H.,Odumabo, S.et al. 2012. Quantification of Fracturing Fluid Migration due to Spontaneous Imbibition in Fractured Tight Formations. Presented at the Americas Unconventional Resources Conference held in Pittsburgh, Pennsylvania, USA, 5-7 June. DOI:10.2118/154939-MS.
Fischer, H. and Morrow, N.R. 2005. Spontaneous Imbibition with Matched Liquid Viscosities. Presented at the SPE Annual Technical Conference and Exhibition held in Dallas, Texas, U.S.A., 9-12 October. DOI:10.2118/96812-MS.
Ghedan, S.G. and Poettmann, F.H. 1991. Effect of Polymers on the Imbibition Process: A Laboratory Study. SPE Reserv. Eng. 6(1): 84-90. DOI:10.2118/20244-PA.
Hatiboglu, C.U. and Babadagli, T. 2007. Oil Recovery by Counter-Current Spontaneous Imbibition: Effects of Matrix Shape Factor, Gravity, IFT, Oil Viscosity, Wettability, and Rock Types. J. Pet. Sci. Eng. 59: 106-122. DOI:10.1016/j.petrol.2007.03.005.
Hatiboglu, C.U. and Babadagli, T. 2010. Experimental and Visual Analysis of Co- and Counter-current Spontaneous Imbibitions for Different Viscosity Ratios, Interfacial Tensions, and Wettabilities. J. Pet. Sci. Eng. 70: 214-228. DOI:10.1016/j.petrol.2009.11.013.
He, K. and Xu, L. 2014. Unique Mixtures of Anionic/Cationic Surfactants: A New Approach to Enhance Surfactant Performance in Liquids-Rich Shale Reservoirs. SPE Prod. Oper. 33 (2): 363-370. DOI:10.2118/184515-PA.
Karimi, M.,Al-Maamari, R.S.,Ayatollahi, S.et al. 2016. Wettability Alteration and Oil Recovery by Spontaneous Imbibition of Low Salinity Brine into Carbonates: Impact of Mg2+, SO42- and Cationic Surfactant. J. Pet. Sci. Eng. 147: 560-569. DOI:10.1016/j.petrol.2016.09.015.
Krumrine, P.H.,Falcone, J.S.,Campbell, T.C. 1982. Surfactant Flooding 1: The Effect of Alkaline Additives on IFT, Surfactant Adsorption, and Recovery Efficiency. SPE J. 22(4): 503-513. DOI:10.2118/8998-PA.
Krumrine, P.H. and Falcone, J.S. 1983. Surfactant, Polymer, and Alkali Interactions in Chemical Flooding Processes. Presented at the International Symposium on Oilfield and Geothermal Chemistry held in Denver, CO, June 1-3. DOI:10.2118/11778-MS
Lago, S.,Rodriguez, H.,Khoshkbarchi, M.K.et al. 2012. Enhanced Oil Recovery Using the Ionic Liquid Trihexyl(tetradecyl)phosphonium Chloride: Phase Behaviour and Properties. RSC Adv. 2: 9392-9397. DOI:10.1039/c2ra21698a.
Li, X.,Teklu, T.W.,Abass, H.et al. 2016. The Impact of Water Salinity/Surfactant on Spontaneous Imbibition through Capillarity and Osmosis for Unconventional IOR. Presented at the Unconventional Resources Technology Conference held in San Antonio, Texas, USA, 1-3 August. DOI:10.15530/URTEC-2016-2461736.
Mohsenzadeh, A.,Al-Wahaibi, Y.,Al-Hajri, R.et al. 2015. Investigation of Formation Damage by Deep Eutectic Solvents as a New EOR Agents. Presented at the SPE European Formation Damage Conference and Exhibition held in Budapest, Hungary, 3-5 June. DOI:10.2118/174257-MS.
Montes, J.,Blin, N.,Alvarez, A.E.et al. 2018. Novel Anionic Surfactant Formulation for High Temperature Carbonate Reservoirs. Presented at the SPE EOR Conference at Oil and Gas West Asia held in Muscat, Oman, 26-28 March. DOI:10.2118/190353-MS.
Shehata, A.M. and El-Din, H.A.N. 2015. Spontaneous Imbibition Study: Effect of Connate Water Composition on Low-Salinity Waterflooding in Sandstone Reservoirs. Presented at the SPE Western Regional Meeting held in Garden Grove, California, USA, 27-30 April. DOI:10.2118/174063-MS.
Sheng, J.J. 2017. What Type of Surfactants Should be Used to Enhance Spontaneous Imbibition in Shale and Tight Reservoirs? J. Pet. Sci. Eng. 159: 635-643. DOI:10.1016/j.petrol.2017.09.071.
Shuwa, S.M.,Jibril, B.Y.,Al-Wahaibi, Y.M.et al. 2014. Heavy-Oil-Recovery Enhancement with Choline Chloride/Ethylene Glycol-Based Deep Eutectic Solvent. SPE J. 20(1): 79-87. DOI:10.2118/172499-PA.
Spinler, E.A.,Zornes, D.R.,Tobola, D.P.et al. 2000. Enhancement of Oil Recovery Using a Low Concentration of Surfactant to Improve Spontaneous and Forced Imbibition in Chalk. Presented at the 2000 SPE/DOE Improved Oil Recovery Symposium held in Tulsa, Oklahoma, 3-5 April. DOI:10.2118/59290-MS.
Takahashi, S.,Kovscek, A.R. 2010. Spontaneous Countercurrent Imbibition and Forced Displacement Characteristics of Low-Permeability, Siliceous Shale Rocks. J. Pet. Sci. Eng. 71: 47-55. DOI:10.1016/j.petrol.2010.01.003
Wang, G.,Zhao, Z.,Li, K.et al. 2015. Spontaneous Imbibition Laws and the Optimal Formulation of Fracturing Fluid during Hydraulic Fracturing in Ordos Basin. Presented at the 7th International Conference on Fluid Mechanics (ICFM7), Procedia Engineering, 126: 549-553. DOI:10.1016/j.proeng.2015.11.303.
Wang, J.,Liu, H.,Qian, G.et al. 2019. Investigations on Spontaneous Imbibition and the Influencing Factors in Tight Oil Reservoirs. Fuel, 236: 755-768. DOI:10.1016/j.fuel.2018.09.053.
Wang, Y.,Liu, X.,Jiao, T.et al. 2017. Performance Comparison between Internal Olefin Sulfonates and Alpha Olefin Sulfonates. J. Surfact. Deterg. 20: 183-191. DOI: 10.1007/s11743-016-1890-z.
Wei, Y. and Babadagli, T. 2017. Selection of New Generation Chemicals as Steam Additive for Cost Effective Heavy-Oil Recovery Applications. Presented at the SPE Canada Heavy Oil Technical Conference held in Calgary, Alberta, Canada, 15-16 February. DOI:10.2118/184975-MS.
Zhang, J.,Nguyen, Q.P.,Flaaten, A.K.et al. 2009. Mechanisms of Enhanced Natural Imbibition with Novel Chemicals. SPE Res. Eval. Eng. 12(6): 912-920. DOI:10.2118/113453-PA.
Zhang, Q.,Vigier, K.D.O.,Royer, S.et al. 2012. Deep Eutectic Solvents: Syntheses, Properties and Applications. Chem. Soc. Rev. 41: 7108-7146. DOI: 10.1039/c2cs35178a.
Zhou, Z.,Hoffman, B.,Bearinger, D.et al. 2014. Experimental and Numerical Study on Spontaneous Imbibition of Fracturing Fluids in Shale Gas Formation. Presented at the SPE/CSUR Unconventional Resources Conference held in Calgary, Alberta, Canada, 30 September-2 October. DOI:10.2118/171600-MS.