Porosity-Permeability Regimes in Reservoirs for Hydrocarbon Prospectivity in Nembe Creek Field, Niger Delta

Porosity and permeability regimes in hydrocarbon-bearing reservoirs of Nembe Creek Field, Niger Delta were delineated by digitizing and correlating gamma ray, resistivity, and density logs from three wells: Nembe 01, Nembe 02 and Nembe 03 respectively. Results obtained from the analyses of these composite logs reveal eight potential hydrocarbon-bearing reservoirs. These reservoir sands were observed to have very good to excellent average porosities ranging from 29 to 45%. Permeability values were excellent within these reservoirs and range from 2200 to 5789mD. Hydrocarbon saturation was observed to be high in all the reservoir sands, ranging from 64 to 81% with corresponding water saturation from 36 to19%. The regimes observed indicate that porosity and permeability increase with depth. Cross-plots indicate increase in porosity and permeability with depth and a linear increase of permeability with porosity. Petrophysicists and reservoir analysts will find these results very beneficial for better understanding of the reservoir properties, fluid distribution and in quantifying the hydrocarbon prospectivity of this Field which is observed to be very high.