Carbonate Reservoir Characterization: Part 10
1. Whether the potential energy sources that remain available in a carbonate reservoir, in order to mobilize oil and gas to the wellbore including
(a) gravitational energy of oil acting over the vertical distance of the productive column;
(b) energy of compression of the free gas in the gas cap or within the oil-producing zone;
(c) energy of compression of the solution-gas dissolved in the oil or the water;
(d) energy of compression of oil and water in the producing-zone of the reservoir;
(e) energy of capillary pressure effects; and
(f) energy of the compression of the rock itself; – remain to be significantly different – from that of a sandstone reservoir?
How about the relative influence of each energy source on a carbonate reservoir behavior towards producing hydrocarbon?
How exactly, the ratio of reservoir oil viscosity to reservoir gas viscosity, solution GOR, formation volume factor, interstitial water saturation, and oil/gas permeability relationships – control the performance of a carbonate reservoir?
2. How exactly will be the evolution of dissolved gas in a carbonate oil reservoir – as the reservoir pressure declines during production – during solution gas drive? Where exactly the free gas phase formed would remain (in the fracture or matrix) – within the oil producing zone?
What will happen, if the reservoir is associated with water zones, where, the pressure becomes significant as the pressure declines? Does reservoir pressure depend primarily on cumulative oil recovery in solution gas drive carbonate reservoirs?
What will happen, if oil production rate significantly influences the producing GOR? Can we reduce the production rate in a carbonate reservoir in order to enhance the ultimate oil recovery significantly?
Would it remain feasible for a carbonate reservoir in order to exhibit significant gravity drainage or water influx, or, to form a secondary gas cap that would essentially make ultimate recovery to remain to be very sensitive to production rate?
3. How exactly, the gas-cap-drive carbonate reservoirs respond to oil production rates? Whether the presence of velocity term in the recovery equation would make the carbonate reservoir to remain to be more rate sensitive?
Feasible to prevent gas coning in a carbonate reservoir (even, if it is produced @ low rates), when the wells producing from intervals remain to be closer to the gas gap?
4. Can a carbonate reservoir act as a complete water-drive system, where, essentially, all the fluid withdrawals remain replaced by intruding water? What will happen in a carbonate reservoir, if reservoir withdrawal rates remain greatly to be in excess of the rate of water influx?
Suresh Kumar Govindarajan
https://home.iitm.ac.in/gskumar/
https://iitm.irins.org/profile/61643
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