Prediction of flow and transport properties in porous media
by Fidelis O. Wopara; Sunny E. Iyuke
International Journal of Oil, Gas and Coal Technology (IJOGCT), Vol. 17, No. 3, 2018

Abstract: The understanding of fluid flow dynamics at the pore-scale is essential for a realistic description of the structure of rock samples and for prediction of flow and transport properties in a porous medium. In this work, we use 3-D X-ray images of the rock microstructure of the Agbada sandstone reservoir in the Niger delta of Nigeria as the basis for prediction of fluid flow properties in the reservoir. Porosity, absolute permeability and relative permeability were obtained by simulating single-phase fluid flow using ImageJ software and the Lattice Boltzmann method respectively. The results were compared with laboratory measured values on the same plug samples; good agreement was observed between the two sets of values. Laboratory measured porosity was 28.7%, while average pore network value was 33.9%. On the other hand, the permeability studies showed average of 1,718 and 1,736 mD for experiment and pore network, respectively, across the samples. [Received: December 29, 2015; Accepted: November 11, 2016]

Online publication date: Thu, 01-Mar-2018

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