Abstract

This study focuses on constructing a 3D static model of the Wamaj Field, located in the western part of the North Cambay Basin, which has been producing hydrocarbon since 2004 from the K-III and K-IX sands of Middle Eocene Kalol Formation. The primary objective of the study was to visualize reservoir architecture, quantify properties like porosity and fluid saturation, reduce subsurface uncertainties, and optimize well placement and production strategies to maximize hydrocarbon recovery. The methodology adopted in this work included the integration of seismic and well log data to create a structural framework of the area, followed by reservoir characterization using amplitude based attribute analyses and a post-stack seismic inversion study to identify the depositional setup and reservoir distribution. The results of the same were used in conjunction with well data to create a reservoir dispersal map for both the sands. Results revealed that the K-III sand, a lower delta plain deposit, exhibits good reservoir quality with complex meandering channels. In contrast, the KIX sand, deposited in a lower-delta plain to prodelta environment, shows rather poor reservoir quality. Finally, all the data was integrated to construct the static model through three crucial steps: Structural modelling, Property modelling (Facies modelling followed by porosity and saturation modelling) and volume estimation. Results indicated that the 3D static model has effectively captured the reservoir geometry and the spatial distribution of petrophysical properties, thus providing a robust framework for further reservoir management and development.