| Popis: |
This study assessed two hydrocarbon reservoirs A and B in 'AMESERE' Field within the Miocene Agbada Formation by utilizing quantitative, deterministic and stochastic simulation workflows on some petrophysical parameters (gross pay, net pay, porosity and water saturation) obtained from irregularly distributed 24 well logs that penetrated the reservoirs. This was with a view to modelling the spatial variability and field-wide extrapolated heterogeneity models of the reservoir across the study area. Average unbiased estimation maps constrained by exponential variogram models of the parameters data were produced and used as inputs for Sequential Gaussian Simulation (SGSIM), a modelling algorithm to produce fifty (50) equally probable realizations. These were used to risk the parameters at different probability levels. In reservoir A at P10, P25, P50, P75 and P90, simulated gross pay was between 11.13 and 22.29 m; net pay was between 2.41 and 13.50 m; porosity was between 18.00 and 33.00%; and water saturation was between 14.02 and 74.96% respectively. In reservoir B at P10, P25, P50, P75 and P90, simulated gross pay was between 17.85 and 57.28 m; net pay was between 5.55 and 49.64m; porosity was 22.00 and 33.00%; and water saturation was between 10.57 and 88.77% respectively. These results are consistent with geostatistical modelling because they show different plausible realizations that quantify varying risks in the distribution of the petrophysical data within the reservoirs. |
