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The interpreted reservoir top and base were used as bounding surfaces for stratigraphic modelling.
These are drilled within the reservoir top and enjoy minimum leakage probability.
Simulation results show that the most economical method to produce this reservoir was to simultaneously inject water at the reservoir top and gas at the reservoir bottom.
All three codes produced near-identical results with respect to CO2 migration velocity and total upward CO2 flux at the reservoir top.
Faults have wide fractured zones with flow potential only within a 2 5 ft thick brittle layer close to the reservoir top.
In this particular reservoir, production from fractures is possible only by targeting the brittle fracture prone layer near the reservoir top of the vicinity of faults.
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Open image in new window Fig. 4 Derby well 1 showing suite of well logs and mapped reservoir Tops in the study.
Over the years, the concept of lithostratigraphic has been used to delineate reservoir tops in search for hydrocarbon in the oil and gas industries.
The HDI, HDII, and HDIII gas sand reservoir tops have negative reflections (soft kick in blue) which indicates a less consolidated gas sand overlain by consolidated shale typical of the Niger delta petroleum system (Doust and Omatsola 1990).
However, for deeper gas sand charged reservoirs tops HDII and HDIII, overlain by thick transversely isotropic shale formations, the anisotropic synthetic gather matches the real CDP gather than the isotropic synthetic gather.
However, for gas sand charged reservoirs tops HDII and HDIII, overlain by thick transversely isotropic shale beds, the anisotropic synthetic gather matches the real CDP gather than the isotropic synthetic gather.
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