A novel model for reservoir rock tortuosity estimation

Abstract This work is a simple and novel model for determining the rock tortuosity, which leads to estimate the permeability. Previous studies, considering this aim, have been rather sophisticated fundamentally, due to the disruption in recognition the terms, tortuosity factor and tortuosity parameter; the obstacle in evaluating the effective length, through which fluids flow. Tortuosity, is a complex parameter needed to be accurately calculated by experimenting on fluid stream through sedimentary samples; in which the resulted empirical relationship is relatively fictitious. So, the author utilized the poroelasticity approach to create an innovative Archie-like formulation and to prove the parameters in the formula, employing a precise experimental method. The underlying assumption in the formalism is that, the inverse of the sample pore volume is directly proportional to that of the bulk volume. The differentiation of the formula for porosity submitted an equation, relating the volumetric strain with varying porosity values, through where a model for the reservoir tortuosity was acquired. The analysis indicated an inverse relationship between the porosity and tortuosity, as proved. Furthermore, the occlusion influences the pore space for porosity lower than 0.05 significantly and reduces the prediction accuracy of tortuosity. Thus, the outcome of this study is viable to reservoirs, with a porosity window in the range of 0.05–0.29.