RESERVOIR ENGINEERING
1. Oil-water flow; Oil-gas flow; Water-gas flow: Controlled by the same set of parameters? (a) Viscosity contrast between the fluids; (b) IFT between the fluids; (c) pressure drop between the fluid phases; (d) pore-size; (e) pore-shape; (f) displacement history; (g) wettability.
Whether the resultant type of ‘fingering patterns’; or the ‘displacement fronts’ are dictated only by ‘Capillary Number’ and ‘Mobility Ratio’ in all the above three cases?
2. Similar to the linear relationship between the volumetric fluid flow rate and the pressure drop at the macroscopic-scale (Darcy’s law), can we expect the same linear relationship between the above two at the pore-scale as well, in case, if we are provided with the details of 'pore-size distribution' and the 'wetting angle distribution'?
3. Gas being compressible, should we consider ‘coalescence’ also - in addition to ‘trapping’ - while dealing with ‘Oil-gas flow’ and ‘Water-gas flows’ in a petroleum reservoir?
4. Whether the idea of ‘enhanced unstable in fingering’ with the ‘increasing total mobility’ (estimated using end point relative permeabilities) would remain always ‘true’?
5. Whether the relationship between 'relative permeability' and the 'fractional flow function' remains sensitive – in determining the 'stability of the displacement' – only in 'step-pulse displacement fronts'?
6. Feasible to replicate the 'length and growth scales' of real field-scale 'fingers' in the absence of having precise values of 'relative permeabilities' and 'capillary pressure functions'?
7. Feasible to get rid-off 'immiscible fingering' during water-flooding completely?
Is it just a numerical error; or, the actual physics associated with the reservoir?
8. For the cases of miscible fingering related with unstable displacements, do we need to deduce ‘peak total mobility’ associated with the relative permeabilities – upon deducing the precise water saturations in the fingers (estimated from the fractional flow)?
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