Statistical Analysis of Core Porosity of Benin’s Offshore Coastal Sedimentary Basin Reservoir Formations

The reservoir formation porosity is one of the main reservoirs petrophysical properties required for fields characterization. The study aims to verify whether the core porosity of Benin’s offshore petroleum block 1 reservoir formations depends significantly upon the nature of reservoir formations and to determine the porosity ranges, the average porosities and the porosity percentiles (P10, P50 and P90) of these formations. The results have shown that Benin’s Petroleum block 1 reservoir formations core porosities depend significantly on the horizons and the nature of formations. Moreover, the core porosities range from 2.1 to 27.8 percent with averages between 12.31 and 18.95 percent. H9 Albian sand has the highest porosity and H8 Albian sand the lowest one. Abeokuta reservoir formations porosities are respectively 16.95 and 17.77 percent for H6 and H6.5 horizons. They have 50 and 90 percent of chance to be respectively greater than 12 and 5.84 percent no matter the formation. Abeokuta formation core porosity has high chance to be more than 17.3 percent.