A constant porosity of 15% and permeability of 0.01 md was assigned to
the overbank shale deposits. Although the total porosity of the
overbank shales was considered to be 15%, the effective porosity was
considered to be 0%. Within the channel sands, porosity was assigned
with sequential Gaussian simulation (SGS). The SGS algorithm
constructs a stochastic porosity model constrained to a histogram of
porosity, a model of spatial correlation, and well data. In this
case, realistic input statistics were chosen on the basis of published
North Sea reservoir examples. The histogram of porosity is shown on
Figure . The third panel of Figure
shows
a cross section through the porosity model.
Finally, permeability was related to porosity through a scatterplot.
Figures and
give the histograms and
porosity-permeability scatterplot.