Arns, Ji-YounArns, ChristophSheppard, AdrianSok, RobertKnackstedt, MarkPinczewski, Wolf Val2015-12-130920-4105http://hdl.handle.net/1885/86888We examine the calculation of relative permeability and residual saturation using networks derived from tomographic images of Fontainebleau sandstone previously used to successfully calculate single-phase transport properties. In contrast to electrical conductivity and permeability calculations, we find that that computed relative permeabilities and residual saturations for samples of the same sandstone display a high degree of variability. Randomizing pores and throats to remove all correlations almost completely eliminates the variability between samples and produces smooth numerical data sets. We conclude that correlations in rock microstructure, which appear to have little effect on the calculation of single fluid properties, have a major effect on computed relative permeability and residual saturation.Keywords: Tomographic images; Data reduction; Image analysis; Microstructure; Sandstone; Tomography; Mechanical permeability; hydrocarbon reservoir; permeability; sandstone; tomography; hydrocarbon reservoir; permeability; sandstone; tomography Heterogeneity; Permeability; Saturation200310.1016/S0920-4105(03)00066-42015-12-12