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Comparison of the three-phase oil relative permeability models

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Abstract

A comparative study of seven different methods for predicting three-phase oil relative permeabilities in the presence of gas and water phases is presented. Predicted oil relative permeabilities from these correlations have been compared with published three-phase experimental data obtained in Berea sandstone core samples. Some of the correlations under study have been recently developed and have never been tested against the laboratory data.

The comparison shows that the commonly used models such as Stones' often do not give accurate predictions of the experimental data. It is concluded that the recently developed models fit the experimental data as well as or better than the previously developed and widely used three-phase oil relative permeability models.

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Abbreviations

a :

Free parameter

e j :

Exponent of relative permeability curve of phase j

e ow, e og :

Two-phase oil exponent when the other phase is water or gas

G :

Interpolating function

h :

Capillary head

k rj :

Relative permeability of phase j

k 0rj :

Endpoint relative permeability of phase j

k row, k rog :

Two-phase oil relative permeability flowing with water or gas

S j :

Saturation of phase j

S jr :

Residual saturation of phase j

S Lrg :

Total residual liquid satuation to gas during two-phase flow of gas-oil

S orw S org :

Residual oil saturation to flowing water or gas phases

S t :

Total liquid saturation

g:

Gas

o:

Oil

w:

Water

go:

Gas-oil

ow:

Oil-water

gow:

Gas-oil-water

ow:

Oil-water

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Authors and Affiliations

  1. Department of Petroleum Engineering, The University of Texas at Austin, CPE 2, 502, 78712, Austin, TX, USA

    Mojdeh Delshad & Gary A. Pope

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  1. Mojdeh Delshad
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  2. Gary A. Pope
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Delshad, M., Pope, G.A. Comparison of the three-phase oil relative permeability models. Transp Porous Med 4, 59–83 (1989). https://doi.org/10.1007/BF00134742

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  • DOI: https://doi.org/10.1007/BF00134742

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