Inscrição na biblioteca: Guest
Portal Digital Begell Biblioteca digital da Begell eBooks Diários Referências e Anais Coleções de pesquisa
Journal of Porous Media
Fator do impacto: 1.49 FI de cinco anos: 1.159 SJR: 0.43 SNIP: 0.671 CiteScore™: 1.58

ISSN Imprimir: 1091-028X
ISSN On-line: 1934-0508

Volume 23, 2020 Volume 22, 2019 Volume 21, 2018 Volume 20, 2017 Volume 19, 2016 Volume 18, 2015 Volume 17, 2014 Volume 16, 2013 Volume 15, 2012 Volume 14, 2011 Volume 13, 2010 Volume 12, 2009 Volume 11, 2008 Volume 10, 2007 Volume 9, 2006 Volume 8, 2005 Volume 7, 2004 Volume 6, 2003 Volume 5, 2002 Volume 4, 2001 Volume 3, 2000 Volume 2, 1999 Volume 1, 1998

Journal of Porous Media

DOI: 10.1615/JPorMedia.v14.i12.30
pages 1077-1086


B. Markicevic
Department of Mechanical Engineering, Kettering University, Flint, Michigan 48504, USA
Ned Djilali
Institute for Integrated Energy Systems and Department of Mechanical Engineering, University of Victoria, PO Box 1700, Victoria, BC V8W 2Y2, Canada


We present a formulation to predict simultaneously the porous medium (single-phase) permeability, and the multiphase flow permeability of a non-wetting liquid in the limit of slow flow. The formulation is based on a new set of mixing rules in which weighting coefficients are obtained from the capillary pressure in the breakthrough point. These weights are calculated by mixing the harmonic average capillary pressure of the actual heterogeneous sample and the capillary pressure of a corresponding homogeneous medium. The porous medium (single phase) and the phase permeability are, on the other hand, found using two length scales: the first determined from the capillary pressure in the breakthrough point and the second calculated again using the homogeneous sample. This formulation is successfully validated for a slow drainage using capillary network simulations based on the invasion percolation mechanism with phase trapping. In the numerical simulations, both network heterogeneity and network size are varied. The simulations reveal that with increasing medium heterogeneity, the porous medium permeability (single phase) decreases, whereas for multiphase flow, the mobile phase permeability and the capillary pressure increase. For a sufficiently large domain (network) size, all three parameters are independent of domain size. The analytical mixing rules capture all of these dependencies, and very good agreement between analytical and numerical results is found.