Asian Journal of Geological Research

The Niger Delta Basin is a major petroleum-producing sedimentary basin characterised by continental, deltaic, shallow-marine and deep-marine deposits. This review examines the relationships between sedimentary facies, depositional evolution and petroleum exploration by synthesising published geological, stratigraphic, sedimentological and reservoir studies. Emphasis is placed on the Akata, Agbada and Benin formations; fluvial, distributary-channel, tidal, delta-front, shoreface, prodelta and deep-water facies; and the influence of sediment supply, subsidence, relative sea-level change and synsedimentary deformation. The reviewed literature indicates that depositional conditions varied across the basin and through geological time, producing laterally variable sandstone and shale distributions. Progradational, aggradational and retrogradational stacking patterns influenced facies relationships, while growth faults, rollover structures and shale-related deformation affected accommodation, reservoir geometry and compartmentalisation. Sand-rich channel, mouth-bar, shoreface and submarine deposits can form reservoirs, whereas fine-grained marine and deltaic intervals may act as seals or source rocks where suitable conditions exist. Reservoir quality is also modified by compaction, cementation, dissolution and clay content. Comparisons of basin-scale syntheses with field-scale studies demonstrate the importance of integrating core observations, well logs, seismic interpretation and sequence stratigraphy. Three-dimensional geological modelling, geostatistical techniques and machine learning offer supplementary approaches but require geological calibration. The review concludes that integrated facies and structural interpretation provides a stronger basis for predicting reservoir distribution and assessing exploration uncertainty.