Recent advances in spontaneous imbibition with different boundary conditions
Abstract view|583|times PDF download|250|times
Abstract
Spontaneous imbibition plays an important role in many practical processes, such as oil recovery, hydrology, and environmental engineering. The development in spontaneous imbibition goes fast in the past few years. In this paper, we focus on boundary conditions of spontaneous imbibition, which has important effects on spontaneous imbibition rate and efficiency. We introduce the fundamental physical mechanism of spontaneous imbibition with different boundary conditions by capillary model. Then, the studies of spontaneous imbibition in core scale are reviewed. The feature of spontaneous imbibition with different boundary conditions is discussed and the relative permeability for co- and counter-current imbibition is analyzed. The scaling of imbibition data with different boundary condition is also discussed by combination of experimental and numerical methods. At last, the analytical model of spontaneous imbibition is discussed.
Cited as: Meng, Q., Cai, J. Recent advances in spontaneous imbibition with different boundary conditions. Capillarity, 2018, 1(3): 19-26, doi: 10.26804/capi.2018.03.01
Keywords
Full Text:
PDFReferences
Abbasi, J., Sarafrazi, S., Riazi M., et al. Improvements in scaling of counter-current imbibition recovery curves using a shape factor including permeability anisotropy. J. Geophys. Eng. 2018, 15(1): 135-141.
Alyafei, N., Blunt, M.J. Estimation of relative permeability and capillary pressure from mass imbibition experiments. Adv. Water Resour. 2018, 115: 88-94.
Andersen, P., Brattekas, B., NΦdland O., et al. Darcy- Scale simulation of Boundary-Condition effects during Capillary-Dominated flow in high-permeability systems. SPE Reserv. Eval. Eng. 2019a, 22(2): 673-691.
Andersen, P., Qiao Y., Standnes, D.C., et al. Cocurrent spontaneous imbibition in porous media with the dynamics of viscous coupling and capillary backpressure. SPE J. 2019b, 24(1): 158-177.
Ashraf, S., Visavale, G., Phirani, J. Spontaneous imbibition in randomly arranged interacting capillaries. Chem. Eng. Sci. 2018, 192: 218-234.
Bourblaux, B.J. Experimental study of cocurrent and counter- current flows in natural porous media. SPE Reserv. Eng. 1990, 5(3): 361-368.
Cai, J., Perfect, E., Cheng, C., et al. Generalized modeling of spontaneous imbibition based on Hagen–Poiseuille flow in tortuous capillaries with variably shaped apertures. Langmuir 2014, 30(18): 5142-5151.
Cai, J., Yu, B. A discussion of the effect of tortuosity on the capillary imbibition in porous media. Transp. Porous. Med. 2011, 89(2): 251-263.
Cheng, Z., Wang, Q., Ning, Z., et al. Experimental investi- gation of countercurrent spontaneous imbibition in tight sandstone using nuclear magnetic resonance. Energ. Fuel. 2018, 32(6): 6507-6517.
Dong, M., Dullien, F.A.L., Dai, L., et al. Immiscible displacement in the interacting capillary bundle model part i. development of interacting capillary bundle model. Transp. Porous. Med. 2005, 59(1): 1-18.
Dong, M., Dullien, F.A.L., Dai, L., et al. Immiscible displace- ment in the interacting capillary bundle model part ii. applications of model and comparison of interacting and non-interacting capillary bundle models. Transp. Porous. Med. 2006, 63(2): 289-304.
Dong, M., Dullien, F.A.L., Zhou, J. Characterization of waterflood saturation profile histories by the ‘Complete’ capillary number. Transp. Porous. Med. 1998, 31(2): 213- 237.
Fischer, H.M. Modeling the effect of viscosity ratio on spontaneous imbibition. SPE Res. eval. 2008, 11(3): 577- 589.
Foley, A.Y., Nooruddin, H.A., Blunt, M.J. The impact of capillary backpressure on spontaneous counter-current imbibition in porous media. Adv. Water Resour. 2017, 107: 405-420.
Gao, Z., Hu, Q. Wettability of Mississippian Barnett Shale samples at different depths: Investigations from directional spontaneous imbibition. AAPG Bull. 2016, 100(1): 101-114.
Ghosh, T., Raja Sekhar, G.P., Deb, D. Mathematical modeling of co-current spontaneous imbibition in heterogeneous porous medium. Eur. J. Mech. B-Fluid. 2019, 76: 81-97.
Hamidpour, E., Mirzaei-Paiaman, A., Masihi, M., et al. Experimental study of some important factors on nonwetting phase recovery by cocurrent spontaneous imbibition. J. Nat. Gas Sci. Eng. 2015, 27: 1213-1228.
Harimi, B., Masihi, M., Mirzaei-Paiaman, A., et al. Experi- mental study of dynamic imbibition during water flooding of naturally fractured reservoirs. J. Petrol. Sci. Eng. 2019, 174: 1-13.
Haugen, ˚A., Fernφ, M.A., Mason, G., et al. Capillary pressure and relative permeability estimated from a single spontaneous imbibition test. J. Petrol. Sci. Eng. 2014, 115: 66-77.
Haugen, ˚A., Fernφ, M.A., Mason, G., et al. The Effect of Viscosity on Relative Permeabilities Derived from Spontaneous Imbibition Tests. Transp. Porous. Med. 2015, 106(2): 383-404.
Hu, Q., Ewing, R.P., Dultz, S. Low pore connectivity in natural rock. J. Contam. Hydrol. 2012, 133: 76-83.
Javaheri, A., Habibi, A., Dehghanpour, H., et al. Imbibition oil recovery from tight rocks with dual-wettability behavior. J. Petrol. Sci. Eng. 2018, 167: 180-191.
Jing, W., Huiqing, L., Genbao, Q., et al. Investigations on spontaneous imbibition and the influencing factors in tight oil reservoirs. Fuel 2019, 236: 755-768.
Khan, A.S., Siddiqui, A.R., Abd, A.S., et al. Guidelines for numerically modeling co- and counter-current spontaneous imbibition. Transp. Porous. Med. 2018, 124(3): 743-766.
Lai, F., Li, Z., Wei, Q., et al. Experimental investigation of spontaneous imbibition in a tight reservoir with nuclear magnetic resonance testing. Energ. Fuel. 2016, 30(11): 8932-8940.
Li, C., Shen, Y., Ge, H., et al. Spontaneous imbibition in fractal tortuous micro-nano pores considering dynamic contact angle and slip effect: phase portrait analysis and analytical solutions. Sci. Rep. 2018, 8(1): 3919.
Li, Y., Li, H., Cai, J., et al. The dynamic effect in capillary pressure during the displacement process in ultra-low permeability sandstone reservoirs. Capillarity 2018, 1(2): 11-18.
Li, Y., Morrow, N.R., Ruth, D. Similarity solution for linear counter-current spontaneous imbibition. J. Petrol. Sci. Eng. 2003, 39(3-4): 309-326.
Lyu, C., Ning, Z., Chen, M., et al. Experimental study of boundary condition effects on spontaneous imbibition in tight sandstones. Fuel 2019, 235: 374-383.
Ma, S., Morrow, N.R., Zhang, X. Generalized scaling of spontaneous imbibition data for strongly water-wet systems. J. Petrol. Sci. Eng. 1997, 38(6): 390.
Mason, G., Fernφ, M.A., Haugen, ˚A., et al. Spontaneous counter-current imbibition outwards from a hemi- spherical depression. J. Petrol. Sci. Eng. 2012, 90: 131- 138.
Mason, G., Fischer, H., Morrow, N.R., et al. Correlation for the effect of fluid viscosities on counter-current spontaneous imbibition. J. Petrol. Sci. Eng. 2010, 72(1-2): 195-205.
Meng, Q. Study on the Characteristics and Influence Factors of Spontaneous Imbibition in the Fractured Reservoirs. China University of Petroleum, Beijing, 2017.
Meng, Q., Cai, J., Wang, J. Scaling of countercurrent imbibition in 2d matrix blocks with different boundary conditions. SPE J. 2019a, 24: 1179-1191.
Meng, Q., Cai, Z., Cai, J., et al. Oil recovery by spontaneous imbibition from partially water-covered matrix blocks with different boundary conditions. J. Petrol. Sci. Eng. 2019b, 172: 454-464.
Meng, Q., Liu, H., Wang, J. Entrapment of the non-wetting phase during co-current spontaneous imbibition. Energ. Fuel. 2015, 29(2): 686-694.
Meng, Q., Liu, H., Wang, J. A critical review on fundamental mechanisms of spontaneous imbibition and the impact of boundary condition, fluid viscosity and wettability. Adv. Geo-Energ. Res. 2017a, 1(1): 1-17.
Meng, Q., Liu, H., Wang, J. Effect of viscosity on oil production by cocurrent and countercurrent imbibition from cores with two ends open. SPE Reserv. Eval. Eng. 2017b, 20(2): 251-259.
Mirzaei-Paiaman, A., Kord, S., Hamidpour, E., et al. Scaling one- and multi-dimensional co-current spontaneous imbibition processes in fractured reservoirs. Fuel 2017, 196: 458-472.
Mirzaei-Paiaman, A., Masihi, M. Scaling of recovery by cocurrent spontaneous imbibition in fractured petroleum reservoirs. Energ. Technol. 2014, 2(2): 166-175.
Nooruddin, H.A., Blunt, M.J. Analytical and numerical investigations of spontaneous imbibition in porous media. Water Resour. Res. 2016, 52: 7284-7310.
Pooladi-Darvish, M., Firoozabadi, A. Cocurrent and counter- current imbibition in a water-wet matrix block. SPE J. 2000, 5(1): 3-11.
Rangel-German, E.R., Kovscek, A.R. Time-dependent matrix- fracture shape factors for partially and completely immersed fractures. J. Petrol. Sci. Eng. 2006a, 54(3- 4): 149-163.
Rangel-German, E.R., Kovscek, A.R. A micromodel investi- gation of two-phase matrix-fracture transfer mechanisms. Water Resour. Res. 2006b, 42: W03401.
Schmid, K.S., Geiger, S., Sorbie, K.S. Semianalytical solutions for cocurrent and countercurrent imbibition and dispersion of solutes in immiscible two-phase flow. Water Resour. Res. 2011, 47(2): W255.
Standnes, D.C. Experimental study of the impact of boundary conditions on oil recovery by co-current and counter- current spontaneous imbibition. Energ. Fuel. 2004, 18(1): 271-282.
Teklu, TW., Abass, H.H., Hanashmooni, R., et al. Experi- mental investigation of acid imbibition on matrix and fractured carbonate rich shales. J. Nat. Gas Sci. Eng. 2017, 45: 706-725.
Unsal, E., Mason, G., Morrow, N.R., et al. Co-current and counter-current imbibition in independent tubes of non- axisymmetric geometry. J. Colloid Interf. Sci. 2007a, 306(1): 105-117.
Unsal, E., Mason, G., Morrow, N.R., et al. Bubble snap- off and capillary-back pressure during counter-current spontaneous imbibition into model pores. Langmuir 2009, 25(6): 3387-3395.
Unsal, E., Mason, G., Ruth, D.W., et al. Co- and counter- current spontaneous imbibition into groups of capillary tubes with lateral connections permitting cross-flow. J. Colloid Interf. Sci. 2007b, 315(1): 200-209.
Wang, F., Zhao, J. A mathematical model for co-current spontaneous water imbibition into oil-saturated tight sandstone: Upscaling from pore-scale to core-scale with fractal approach. J. Petrol. Sci. Eng. 2019, 178: 376-388.
Wang, J., Dong, M. Trapping of the non-wetting phase in an interacting triangular tube bundle model. Chem. Eng. Sci. 2011, 66(3): 250-259.
Washburn. The dynamics of capillary flow. Phys. Review. 1921, 17(3): 273-283.
Xu, G., Shi, Y., Jiang, Y., et al. Characteristics and influencing factors for forced imbibition in tight sandstone based on low-field nuclear magnetic resonance measurements. Energ. Fuel. 2018, 32(8): 8230-8240.
Yang, L., Wang, S., Cai, J., et al. Main controlling factors of fracturing fluid imbibition in shale fracture network. Capillarity 2018, 1(1): 1-10.
You, Q., Wang, H., Zhang, Y., et al. Experimental study on spontaneous imbibition of recycled fracturing flow- back fluid to enhance oil recovery in low permeability sandstone reservoirs. J. Petrol. Sci. Eng. 2018, 166: 375- 380.
Zhang, S., Pu, H., Zhao, J.X. Experimental and numerical studies of spontaneous imbibition with different boundary conditions: case studies of middle bakken and berea cores. Energ. Fuel. 2019, 33: 5135-5146.
Zhang, X., Morrow, N.R., Ma, S. Experimental verification of a modified scaling group for spontaneous imbibition. SPE Res. Eng. 1996, 11(4): 280-285.
Refbacks
- There are currently no refbacks.
Copyright (c) 2018 The Author(s)
This work is licensed under a Creative Commons Attribution-NonCommercial-NoDerivatives 4.0 International License.