Fundamental Reservoir Units
While the storage capacity of a reservoir remains determined by the ‘reservoir porosity’ (texture); and the ‘transmissive capacity’ (the ease with which the fluids move through the reservoir) remains dependent on the ‘reservoir permeability’, and on top of it,
if “the distribution of reservoir fluids (water, oil and gas) within the reservoir rock formations, as well as their respective migratory behavior within the reservoir strata remains dependent on the ‘areal distribution’ and ‘volumetric configurations’ of the reservoir formation”, then, do we still require at least one more ‘fundamental reservoir unit’, on top of having ‘porosity’ and ‘permeability’?
Even among two (existing) fundamental reservoir units, to what extent, could we manage to characterize the momentum conservation of a ‘heterogeneous’ petroleum reservoir using Darcian approach - in the absence of having an explicit porosity?
If so, what exactly, we, physically mean by
(a) having an explicit porosity in mass conservation equation; while
(b) not having an explicit porosity in momentum conservation equation?
Feasible to take into account - explicitly - the physiographic and geological factors involved in determining the type and distribution of various sediments associated with a sandstone reservoir?
If not, would it remain feasible to associate ‘porosity’ and ‘permeability’ with ‘regional changes’ (large scale differences between successive formations) and ‘local changes’ (minor irregularity within a single stratum)?
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