Carbonate Reservoir Characterization: Part 05
1. Whether, permeability zonation; and, baffles within and between genetic units really have a significant impact on vertical sweep efficiency?
2. To what extent, the small-scale heterogeneities such as sedimentary structures, inter-lamination of various rock types, pore-types and non-carbonate minerals would remain to be sensitive in dictating resulting the oil recovery factor in a carbonate reservoir?
3. How easy would it remain to delineate the zones of dolomitization; and in turn, will we be able to quantitatively interpret the concentrations of non-carbonate minerals?
4. To what extent, the presence of fractures in a carbonate reservoir really aid to drain solution gas-drive reservoirs during primary recovery production owing to the gas coming out of solution; and in turn, expelling the crude oil from the pore space into the well-bore?
5. To what extent, the presence of fractures really become avenues for the injected water to bypass huge volumes of oil contained in the low-permeable rock-matrix of a carbonate reservoir, during conventional water-flooding operations?
6. During the displacement of oil by water, whether, imbibition process (where, the wetting-phase saturation gets increased) do not remain to be effective due to the presence of fractures in a carbonate reservoir; and only, drainage (where, wetting-phase saturation gets decreased) remains to be effective?
7. Whether early water-flooding will be a wise idea (before primary production gets over) in a carbonate reservoir?
8. Do we really require a moderate degree of induced fracturing in order to stimulate wells in a low-permeability carbonate reservoir in order to complete a water-flood in a reasonable time period?
In such cases, would it remain feasible to have a control over the degree of fracture stimulation using pressure fall-off analyses – by not allowing the fluid injection pressures to exceed the parting pressure of the formation; and by having proper restraints and control over fluid injection, which will not induce the generation of excessively long fractures; and thereby preventing an early water breakthrough that leaves the by-passed oil in the pore space?
9. Whether natural water drives remain to be less effective in carbonate reservoirs than in sandstone reservoirs?
10. What will happen, if, during injectivity tests, if the formation gets fracture parted, while obtaining the estimates of permeability capacity term?
Won’t it lead to an erroneously larger values of permeability capacity term? To what extent, step-rate injectivity tests will be able to help us in assessing the formation of new fractures?
Does this approach take into account the spatial distribution of the flow capacity in a carbonate reservoir?
Suresh Kumar Govindarajan
https://home.iitm.ac.in/gskumar/
https://iitm.irins.org/profile/61643
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