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2, 136–149 (1997)īauer, D., Youssef, S., Fleury, M., Bekri, S., Rosember, E., Vizika, O.: Improving the estimations of petrophysical transport behavior of carbonate rocks using a dual pore network approach combined with computed microtomography. 43, 577–586 (2003)īakke, S., Øren, P.E.: 3D pore-scale modeling of sandstones and flow simulations in the pore networks. E 94, 043113 (2016)Īrns, C., Sakellariou, A., Senden, T., Senden, T., Sheppard, A., Knackstedt, M.: Petrophysical properties derived from X-ray CT images. 30, 139–165 (1998)Īrmstrong, R.T., Mcclure, J.E., Berrill, M.A., Rücker, M., Schlüter, S., Berg, S.: Beyond Darcy’s law: the role phase topology and ganglion dynamics for two-fluid flow. 122, 49–59 (2018)Īnderson, D.M., McFadden, G.B., Wheeler, A.A.: Diffuse-interface methods in fluid mechanics. Springer, Berlin (2007)Īlpak, F.O., Berg, S., Zacharoudiou, I.: Prediction of fluid topology and relative permeability in imbibition in sandstone rock by direct numerical simulation. (eds.) Geometric Modelling, Numerical Simulation and Optimization, pp. A very encouraging agreement between computed and measured properties is found.Īarnes, J.E., Kippe, V., Lie, K.A., Rustad, A.B.: Modelling of multiscale structures in flow simulations for petroleum reservoirs.
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Waterflood relative permeability is calculated in a blind test and compared with high-quality experimental data. Experimentally measured mercury–air primary drainage and oil–water imbibition capillary pressure curves (after ageing to restore wettability) are used to anchor the multiscale pore network model. The multiscale digital rock workflow is applied to two heterogeneous rock samples: a mixed wet thinly laminated reservoir sandstone and an oil wet reservoir carbonate.
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These properties are derived from high-resolution rock-type models constructed from backscatter SEM images and/or high-resolution micro-CT images of sub-samples. Similar to conventional continuum models, each Darcy pore is populated with single and multiphase flow properties. Resolved pores are treated in a conventional pore network manner while unresolved network elements are treated as a continuum Darcy-type porous medium. The resulting 3D rock-type map and the porosity map are combined and transformed into a multiscale pore network model. The unresolved porosity regions are classified into different porosity classes or rock types. A dry/wet micro-CT imaging sequence is used to spatially map the porosity and the connectivity of resolved and unresolved porous regions. We introduce a generalized multiscale imaging and pore-scale modelling workflow to derive transport properties of complex rocks having broad pore size distributions. The scale-transgressive effects of heterogeneity must therefore be accounted for through a multiscale digital rock workflow. This poses a significant challenge for digital rock analysis since a single resolution image and associated simulation model cannot capture all the relevant length scales in sufficient detail due to limitations in computer memory and speed. Complex depositional and diagenetic processes have a strong control on the pore structures, leading to systems with a wide range of pore sizes covering many orders of magnitude in length scales. Many properties of complex porous media such as reservoir rocks are strongly affected by heterogeneity at different scales.