Page 94 - Reservoir Formation Damage

Petrophysics-Flow Functions and Parameters 77

it is reasonable to assume that the parameters of Eqs. 4-14, 15 and 16
can be correlated with respect to the wettability index to obtain dynamic
correlations. Figures 4-5 and 4-6 obtained by simulation by McDougall
and Sorbie (1995) demonstrate the effect of wettability on capillary
pressure and relative permeability.
Wang (1988) shows the effect of a wettability alteration on imbibition
relative permeability. Tielong et al. (1996) have demonstrated that the oil
and water relative permeabilities of cores before and after polymer
treatment can be correlated by Eq. 4-12. Tielong et al. (1996) determined
the values of the exponents of Eq. 4-12 before and after polymer treat-
ment and showed that they varied. However, they did not determine the
exponent values at various intervals during polymer treatment. Therefore,
a correlation cannot be derived from their data.
Neasham (1977) studied the affect of the morphology of dispersed clay
on fluid flow properties in sandstone cores. Neasham present the miner-
alogical, petrographical and petrophysical properties of the sandstones
tested. Neasham demonstrates that different sandstones indicate signifi-
cantly different capillary pressure behavior.

References

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