Petrophysics and Well Log Correlation of “FTP” Field Offshore Niger Delta

One challenging thing about doing formation evaluation studies in clastic formation like the Niger Delta is accurately identifying and mapping the reservoir sands and their edges. This is also true when studying the offshore Niger Delta. The database comprised borehole logs from four wells. Gamma ray logs were used to map the lithology while thye hydrocarbon bearing reservoirs were identified with a mix of gamma ray and resistivity logs. Well-logged correlation was carried out using similarity in log signatures. Schlumberger software (PETRELTTM) was used for interpretation. The computation of petrophysical parameters such as net-to-gross volume, volume of shale, porosity, permeability, and hydrocarbon saturation was done using standard equations. The general lithology in the area is an alternation of sands and shales. Three reservoirs designated as R1, R2, and R3 extend across all the wells. Reservoir R1 is located at a depth of 8244 m in well 1, 8202 m in well 2, 8167 m in well 3, and 8129 m in well 4. Reservoir R2 is located at a depth of 8843 m in Well 1, 8520 m in Well 2, 8478 m in Well 3, and 8448 m in Well 4. Likewise, reservoir R3 is located at a depth of 9508 m in well 1, 8801 m in well 2, 8758 m in well 3, and 8730 m in well 4. Reservoir R1 has an average net-to-gross sand of 0.98, a volume of shale of 0.15, porosity of 0.34, and permeability of 1010 mD. Reservoir R2 has an average net-to-gross sand of 0.92. The shale volume is 0.19, the porosity is 30%, and the permeability is 838 mD. Reservoir R3 has an average net-to-gross sand of 0.92. The shale volume is 0.01, the porosity is 0.30, and the permeability is 783 mD. The reservoir parameters were also represented statistically using a bar chart. These representations gave insight into the distribution of the reservoir parameters of interest in the study location.