Viscous coupling in two-phase flow in porous media and its effect on relative permeabilities

1993 ◽  
Vol 11 (3) ◽  
pp. 201-218 ◽  
Author(s):  
R. Ehrlich
Keyword(s):  
Porous Media ◽  
Two Phase Flow ◽  
Flow In Porous Media ◽  
Phase Flow ◽  
Relative Permeabilities ◽  
Viscous Coupling ◽  
Two Phase

A lattice Boltzmann study of viscous coupling effects in immiscible two-phase flow in porous media

2007 ◽  
Vol 300 (1-2) ◽  
pp. 35-49 ◽  
Author(s):  
Andreas G. Yiotis ◽  
John Psihogios ◽  
Michael E. Kainourgiakis ◽  
Aggelos Papaioannou ◽  
Athanassios K. Stubos
Keyword(s):  
Porous Media ◽  
Lattice Boltzmann ◽  
Two Phase Flow ◽  
Flow In Porous Media ◽  
Phase Flow ◽  
Viscous Coupling ◽  
Coupling Effects ◽  
Two Phase

scholarly journals Steady-State Two-Phase Flow in Porous Media: Laboratory Validation of Flow-Dependent Relative Permeability Scaling

2020 ◽  
Vol 146 ◽  
pp. 03002
Author(s):  
Marios S. Valavanides ◽  
Matthieu Mascle ◽  
Souhail Youssef ◽  
Olga Vizika
Keyword(s):  
Porous Media ◽  
Steady State ◽  
Relative Permeability ◽  
Flow Rate ◽  
Two Phase Flow ◽  
Flow In Porous Media ◽  
Phase Flow ◽  
Relative Permeabilities ◽  
Two Phase ◽  
Local Flow

The phenomenology of steady-state two-phase flow in porous media is recorded in SCAL relative permeability diagrams. Conventionally, relative permeabilities are considered to be functions of saturation. Yet, this has been put into challenge by theoretical, numerical and laboratory studies that have revealed a significant dependency on the flow rates. These studies suggest that relative permeability models should include the functional dependence on flow intensities. Just recently a general form of dependence has been inferred, based on extensive simulations with the DeProF model for steady-state two-phase flows in pore networks. The simulations revealed a systematic dependence of the relative permeabilities on the local flow rate intensities that can be described analytically by a universal scaling functional form of the actual independent variables of the process, namely, the capillary number, Ca, and the flow rate ratio, r. In this work, we present the preliminary results of a systematic laboratory study using a high throughput core-flood experimentation setup, whereby SCAL measurements have been taken on a sandstone core across different flow conditions -spanning 6 orders of magnitude on Ca and r. The scope is to provide a preliminary proof-of-concept, to assess the applicability of the model and validate its specificity. The proposed scaling opens new possibilities in improving SCAL protocols and other important applications, e.g. field scale simulators.

Simulating Two-Phase Flow In Porous Media With Anisotropic Relative Permeabilities

2011 ◽  
Author(s):  
Eirik Keilegavlen ◽  
Jan M. Nordbotten ◽  
Annette Stephansen
Keyword(s):  
Porous Media ◽  
Two Phase Flow ◽  
Flow In Porous Media ◽  
Phase Flow ◽  
Relative Permeabilities ◽  
Two Phase
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