Porosity prediction using 3D seismic genetic inversion at F3 Block, offshore Netherlands

Seismic and well information have been incorporated with a genetic inversion workflow using supervised neural network in the F3 block, offshore Netherlands view to properly predicting porosity distribution within selected reservoirs. This would provide spatial of field. Petrophysical parameters were estimated for identified reservoirs (FS4, FS8, XYZ ABC) across four wells (F02-01, F03-02, F03-04 F03-06) ranging from 780 1500 ms. Acoustic impedance (AI) cubes weregenerated network. Thereafter, acoustic maps extracted The results reflect that region varies 2000 6000 kPa.s/m, indicating unconsolidated less compacted formation study area. Porosity 0.25 0.40, which reflects very good excellent values plot (F02-01) predicted reveals relatively correlation coefficient 68%. hydrocarbon regions block are Upper Jurassic – Lower Cretaceous strata found below interval available this study. underscores algorithm has proven effective