<p>The Agbeju Field, located within the Niger Delta Basin, is an important hydrocarbon-bearing region requiring a detailed petrophysical evaluation to optimize reservoir characterization and hydrocarbon recovery. This study integrates well log data from five wells to identify hydrocarbon-bearing reservoirs and determine their petrophysical properties, including porosity, permeability, net-to-gross ratio, and fluid saturation. The methodology involved the use of Schlumberger Petrel software for data processing, well log correlation, and reservoir ranking based on key petrophysical parameters. Three major reservoirs, designated as Sand A, Sand B, and Sand C, were identified. Among these, Sand C was ranked as the most promising reservoir due to its highest hydrocarbon saturation (41%), moderate porosity, and favorable net-to-gross ratio. Sand A followed closely with similar porosity values but slightly lower hydrocarbon saturation. Sand B, despite exhibiting the highest permeability and net-to-gross ratio, had the highest water saturation, making it less viable for immediate production. The well log correlation confirmed lateral continuity of the reservoirs, indicating an extensive hydrocarbon-bearing system across Agbeju Field. The results underscore the importance of integrating petrophysical analysis with well log interpretation to improve reservoir evaluation accuracy and hydrocarbon recovery efficiency. This study provides critical insights for field development planning, reservoir management, and hydrocarbon extraction strategies in Agbeju Field. Future studies should incorporate seismic data and core sample analysis to enhance reservoir characterization further. The findings contribute to optimizing hydrocarbon recovery and minimizing exploration risks in the Niger Delta and similar petroleum systems.</p>