A qualitative inverse relation between the first 12 months of production and curvature lineaments was documented. This study is focused on a field of Northern Malay basin, which is associated with a fluvial-deltaic environment. Generating AVO attributes are one solution to give an accurate result in facies and fluid characterization. Statistical relations were established between P-wave velocity and porosity measured from cores, between P-wave impedance and producing zones, and between initial production rates and seismic “fracture lineaments.” The strong quantitative correlation between thick-bedded chert lithofacies and seismic impedance was used to map the reservoir. Amplitude versus offset (AVO) analysis integration to well log analysis is considered one of the advanced techniques to improve the understanding of facies and fluid analysis. Volumetric calculations of reflector curvature and seismic inversion of acoustic impedance were combined to infer distribution of lithofacies and fractures and to predict porosity. The Fluid substitution method is the most commonly used technique using the application of Gassmann’s equation. Also, laboratry measurements show excellent linear correlation between P-wave impedance and porosity. Laboratory core data show that Gassmann's fluid-substitution equation works well for microporous tripolitic chert. The relations among porosity, velocity, and impedance were explored and also reactions among production, impedance, and lineaments observed in 3D attribute volumes. In this case study the objective was to use cores, petrophysical logs, rock physics, and seismic attributes to characterize porosity and field-scale fractures. These reservoirs are characterized by microporosity they are heterogeneous and compartmented, which results in recovery of less than 30% of the oil in place. About the same amount of mobile petroleum remains in place. Although we often describe Gassmanns connections/relations to foretell saturated rock coefficient from dry-rock coefficient, the most common problem is to predict/foretell saturated rock modulus of one fluid that is replaced with another Adam et al., 2006, Abe et al., 2018b.The exchange/substitution could be when any of the fluid is replaced i.e. In west Texas, fractured-chert reservoirs of Devonian age have produced more than 700 million barrels of oil.

Hampson russell fluid substitution