Carbonate Reservoir Characterization: Part 11
1. Whether the combination of low viscosity and high API gravity values – would really emphasize the down-structure oil migration in a carbonate reservoir during gravity drainage?
2. Whether the ultimate oil recovery in a carbonate reservoir would depend on the balance between the capillary and gravity forces – during a gravity drainage? How exactly gravity forces will be able to overcome the capillary resistance to the entrance of water into the fractures?
Whether the capillary and gravity forces control the static and dynamic equilibrium of each individual low-permeable rock-matrix block, if the high-permeable fractures remain to act as capillary discontinuities?
Feasible to have a precise measurements of capillary pressure curve, particularly, in the very low-pressure change – associated with the field performance predictions for highly fractured carbonate reservoirs?
3. How exactly the oil recovery gets influenced due to the presence of the following diagenetic processes in a carbonate reservoir?
(a) dolomitization;
(b) cementation;
(c) massive dissolution; and
(d) grain enhancement.
4. How exactly to have a control over the spatial and temporal distribution of porosity and permeability of a carbonate reservoir, if it is characterized by intermediate porosity (which displays, openings, fissures, dissolution caverns and other openings induced by dissolution and fracturing, in addition to the intergranular openings) as against intergranular porosity (where, carbonate rocks remain composed of calcareous fragments, whose, size, shape and packing determine the pore space geometry)?
5. To what extent, the following data deduced from a pressure transient analysis will remain to be meaningful in a carbonate reservoir?
(a) formation conductivity (kh);
(b) skin factor;
(c) average formation pressure; and
(d) formation storage capacity.
6. By what means, the values of flow-rate and pressure – deduced from the following pressure transient and flow tests remain to be different for a carbonate reservoir from that of a sandstone reservoir?
(a) pressure drawdown;
(b) pressure build-up;
(c) variable flow rate test;
(d) injection test;
(e) fall off test;
(g) constant pressure test;
(h) deliverability test;
(i) vertical testing;
(j) drill stem testing;
(k) repeat formation test;
(l) step rate test;
(m) interference test; and
(n) pulse testing.
Whether the porosity and permeability of the reservoir would remain to be a constant? Whether gravity forces would remain to be negligible?
Whether pressure gradients would remain to be small at all locations within a carbonate reservoir?
Suresh Kumar Govindarajan
https://home.iitm.ac.in/gskumar/
https://iitm.irins.org/profile/61643
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