Reservoir characterization using seismic and well data, freeman field, Niger delta

This report details the workflow for the Reservoir Freeman field, encompassing 3D seismic interpretation and the development of a 3D static model through the comprehensive integration of available data. This includes 3D seismic data, well logs, deviation data, core samples, checkshot data, and production records. The study underscores the area's petroleum potential and presents petrophysical results from four wells to enhance reservoir characterization. Seismic interpretation identified five horizons and nineteen faults, mainly antithetic and basinward-dipping. The structural framework and time maps indicate a central structural high, suggestive of hydrocarbon accumulation zones. Petrophysical analysis delineated four key hydrocarbon reservoirs (A, B, C, and D) with average thicknesses of 27.14m, 22.00m, 18.07m, and 18.15m, respectively. Reservoir porosities ranged from 0.25 to 0.35, highlighting favourable storage capacity. Permeabilities between 1993.99mD and 3640.88mD indicate well-connected pore networks. Hydrocarbon saturation (SH) varied from 0.64 to 0.76, with movable hydrocarbon indices suggesting primarily movable oil. Volumetric analysis yielded STOOIP estimates of 38,118.36 bbl/acre (A), 36,319.85 bbl/acre (B), 25,379.47 bbl/acre (C), and 18,023.39 bbl/acre (D). These findings emphasize the potential of the Reservoir Freeman field for hydrocarbon development.