Reservoir Heterogeneity
If the pore structure remains to be no more ‘isotropic’ and thereby possibly leading to ‘asymmetric stresses’ in a sandstone reservoir, can we expect a corresponding change in the direction of the respective fluid gradients of water, oil and gas?
And, to what extent, such preferential flow pathways would affect the saturation distributions of water, oil and gas - spatially as well as temporally?
Feasible to capture such ‘permeability anisotropy’ – in the absence of having details on pore-size; pore-shape; pore-connectivity; and shape and orientation of structural planes (if any)?
Would it remain to be practically feasible - in order to characterize ‘permeability anisotropy’ - that remains as a ‘tensor quantity’ – in a sandstone reservoir – with ease?
Under what circumstances, the effects of stresses remain to be dominant and sensitive – in addition to having control over the intrinsic properties of a sandstone reservoir – towards characterizing ‘permeability anisotropy’?
Is there a way to link the ‘axial stress’ / ‘shear stress’ (along the flow direction) and the ‘confining pressure’ / ‘normal stress’ (perpendicular to the flow direction) to the ‘hydrostatic pressure’ during reservoir depletion - at a given depth?
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