Well based modeling and seismic data analysis were used to investigate the potential of Amplitude Variation with Angle<br>(AVA) for fluid discrimination in a high porosity carbonate reservoir in a producing UAE oil field. Gassmann fluid<br>substitution was used to model well log data, which included compressional and shear sonic logs and density logs to produce<br>synthetic well logs representing the reservoir at 100% fluid saturations of brine, oil and gas at reservoir pressure and<br>temperature conditions. The average VP/VS ratio for brine saturated reservoir (~2.0) was observed to be higher than both the<br>oil (~1.7) and gas (~1.6) saturated reservoir cases.


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