This study presents petrophysical analysis of the Sokor-1 Formation, Termit Basin, Southeastern Niger, using well log data from six wells to assess reservoir quality and hydrocarbon potential. Five sand groups (E-1 to E-5) were analyzed for net-to-gross ratio (NTG), shale volume (Vsh), porosity (Φ), permeability (K), and hydrocarbon saturation (Sh). The results indicate clear variations in reservoir properties across sand groups and wells. E-1 exhibits the highest reservoir quality, with high porosity (27–33%), low to moderate shale content (10–19%), high permeability (up to 208 mD), and high hydrocarbon saturation (up to 56%), reflecting well-developed fluvial channel sandstones. E-2 and E-3 show moderate and heterogeneous reservoir characteristics, with NTG and permeability strongly influenced by shale content and depositional heterogeneity. E-4 contains very clean sandstones with moderate connectivity, while E-5 shows consistent reservoir properties across wells, with good NTG, porosity, and hydrocarbon saturation. These variations highlight the influence that could have depositional facies and diagenetic processes on reservoir storage and fluid flow in the Sokor-1 Formation. The study demonstrates that integrated petrophysical analysis provides a reliable framework for assessing hydrocarbon potential and guiding exploration in heterogeneous sand-dominated systems.