Inderscience Publishers

Characterisation of water–oil drainage process through a reservoir rock sample by digital core analysis

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Oil–water relative permeability and capillary pressure of a water–wet digital core are computed using the finite–volume/volume of fluid method and mimicking traditional laboratory steady–state experiments carried out on a water saturated sample. Commercial software is used for immiscible multiphase fluid flow simulations, carried out on a low–cost multicore workstation, and the pore–scale data are upscaled to derive relative permeability and capillary pressure curves as function of water saturation. The digital sample is obtained by high resolution X–ray computed tomography scanning. [Received: March 13, 2013; Accepted: June 25, 2013]

Keywords: relative permeability, digital rock, pore–scale simulation, two–phase flow, steady–state, drainage process, water–oil systems, volume of fluid, water–oil drainage, reservoir rock, digital core analysis, capillary pressure, finite volume, multiphase fluid flow, immiscible fluid flow, water saturation

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