k = 1014.24 \cdot FZI^2 \cdot \frac{\phi^3}{( 1 - \phi )^2} |
where
effective porosity | |
Flow Zone Indicator |
with Flow Zone Indicator having a complex dependance on porosity and shaliness:
FZI(V_{sh},\phi_r) = {\rm w}_1(V_{sh}) \, \phi_r^{m_1} + {\rm w}_2(V_{sh}) \, \phi_r^{m_2} |
for each lithofacies individually.
Usually, the first component dictates Flow Zone Indicator values at low porosities while second component takes over at high porosities.
This allows to cover a wider range of porosity variations comparing to single-component Cozeny-Karman permeability @model.
The dependance of weight coefficients on shaliness can be often approximated as:
{\rm w}_1(V_{sh}) = {\rm w}_{01} \, (1- V_{sh}/V_{sh1})^{g_1} |
{\rm w}_2(V_{sh}) = {\rm w}_{02} \, (1- V_{sh}/V_{sh2})^{g_2} |
where
the highest values of weights for shale-free rock matrix | |
critical values of shaliness at which the corresponding component of Flow Zone Indicator vanishes | |
cementing factors, when low they diminish dependance on shaliness |
This model is very flexible and covers a wide range of practical cases.
When and are small () the Flow Zone Indicator becomes independent on porosity and shaliness and the model degrades to conventional Cozeny-Karman permeability @model with .
Petroleum Industry / Upstream / Subsurface E&P Disciplines / Petrophysics / Absolute permeability / Absolute permeability @model