| dc.description.abstract | A comprehensive understanding of reservoir characteristics is essential for support- ing effective hydrocarbon exploration and production strategies. This study aims to predict the spatial distribution of key petrophysical parameters porosity, permeabil- ity, and shale volume in the Hugin Formation, Volve Field, North Sea Basin. The analysis was conducted using simultaneous seismic inversion to generate elastic parameter distributions, which were then applied to predict reservoir property dis- tributions through a Multiattribute method based on stepwise regression. The results show that Zone 1 and Zone 2 have low shale content, high porosity, and permeabil- ity high, indicating good fluid storage capacity and pore connectivity that support fluid flow, making them prime targets for hydrocarbon migration and production. Conversely, although Zone 3 exhibits low shale content, its lower porosity and per- meability significantly constrain its reservoir potential. The integrated analysis of shale volume, porosity, and permeability maps substantiates that Zones 1 and 2 rep- resent the most prospective sectors for field development and provide a robust basis for formulating more efficient and targeted exploitation strategies. | en_US |
