Abstract. In this case study, we present the implementation of a finite element method (FEM)-based numerical porescale model that is able to track and quantify the propagating fluid-fluid interfacial area on highly complex microcomputed tomography (µ-CT)-obtained geometries. Special focus is drawn to the relationship between reservoir-specific capillary pressure (p c ), wetting phase saturation (S w ) and interfacial area (a wn ). The basis of this approach is highresolution µ-CT images representing the geometrical characteristics of a georeservoir sample. The successfully validated 2-phase flow model is based on the Navier-Stokes equations, including the surface tension force, in order to consider capillary effects for the computation of flow and the phase-field method for the emulation of a sharp fluid-fluid interface.In combination with specialized software packages, a complex high-resolution modelling domain can be obtained. A numerical workflow based on representative elementary volume (REV)-scale pore-size distributions is introduced. This workflow aims at the successive modification of model and model set-up for simulating, such as a type of 2-phase problem on asymmetric µ-CT-based model domains. The geometrical complexity is gradually increased, starting from idealized pore geometries until complex µ-CT-based pore network domains, whereas all domains represent geostatistics of the REV-scale core sample pore-size distribution. Finally, the model can be applied to a complex µ-CT-based model domain and the p c -S w -a wn relationship can be computed.