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Reservoir Petrophysics of Bima Field, North-West Java Sea
Petrophysical parameters, such as porosity, mineralogy and type of pore fluid required for reservoir characterisation, are normally derived from well logs and core data. These measurements can be very accurate in the depth direction, but their lateral penetration is very shallow. Surface seismic measurements on the other hand have inherently low vertical resolution but are laterally continuous. Provided that the seismic is property integrated with the well bore information, reservoir petrophysical parameters such as porosity and mineralogy can be mapped accurately from surface seismic. Moreover, the fluid type in the pores can be inferred from calibrated seismic data. This calibration must be statistically consistent and must take into account the errors inherent in both the borehole and the seismic data.
The relationship between seismic and petrophysical properties is addressed with reference to a reservoir evaluation study of the Bima Field involving both carbonate and clastic reservoirs. The relationship are used to produce volumetric maps of effective reservoir porosity.
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