Application of Seismic and Well Log Data Integration Workflow for Reservoir Characterization of the “ABU” Field, Niger Delta, Nigeria
Keywords:
Reservoir Characterization, Fault Mapping, Hydrocarbon Potential, Sequence Stratigraphy, Petrophysical AnalysisAbstract
This study applies a data integration workflow to structurally, stratigraphically, and petrophysically characterize the “ABU” Field in the Niger Delta. The analysis focuses on fault mapping, reservoir delineation, and hydrocarbon potential assessment. Using variance attribute techniques, 15 faults were identified—12 synthetic and 3 antithetic—with a major antithetic fault forming a graben structure in the ABU-2 area. These predominantly listric faults are characteristic of Niger Delta growth fault systems and act as key structural traps. The major growth fault trends northeast–southwest, consistent with regional tectonics. Sequence stratigraphy reveals two third-order depositional cycles associated with transgressive marine settings, and three dominant facies: channel sands, upper shoreface sands, and shales. Reservoir mapping delineates three main reservoirs (B, C, and G). Reservoir G, characterized by a well-defined anticlinal closure, exhibits the highest hydrocarbon potential. Petrophysical analysis shows that Reservoir G has a Net-to-Gross ratio ranging from 0.25 to 0.93, porosity between 29% and 33%, and permeability from 153.79 mD to 579.11 mD. Reservoir B demonstrates slightly higher porosity (30% to 33%) and permeability (200.58 mD to 472.83 mD), but higher water saturation reduces its hydrocarbon potential. Reservoir C has lower reservoir quality, with Net-to-Gross values between 0.25 and 0.77, porosity from 28% to 32%, and permeability between 160.45 mD and 432.10 mD, accompanied by higher water saturation. Overall, the ABU Field shows considerable hydrocarbon potential, particularly in Reservoir G. Variations in reservoir quality are largely influenced by growth fault architecture and depositional environments.
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