Authors: Fidelis O. Wopara; Sunny E. Iyuke
Addresses: School of Chemical and Metallurgical Engineering, University of the Witwatersrand, Johannesburg, P/Bag 3, Wits 2050, South Africa; Department of Petroleum Engineering, Faculty of Engineering, Rivers State University of Science and Technology, Port Harcourt, P.M.B. 5080, Port Harcourt, Nigeria ' School of Chemical and Metallurgical Engineering, University of the Witwatersrand, Johannesburg, P/Bag 3, Wits 2050, South Africa
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]
Keywords: petroleum reservoir; Agbada sandstone; Niger delta; 3D imaging; X-ray micro-tomography; computer modelling; rock properties; fluid transport; pore-network; Lattice Boltzmann.
International Journal of Oil, Gas and Coal Technology, 2018 Vol.17 No.3, pp.284 - 303
Available online: 26 Feb 2018 *Full-text access for editors Access for subscribers Purchase this article Comment on this article