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The sand deposits show aggradational signatures and are braided point bar sands.
Shoreface barrier bar sands have been observed and interpreted in the logs (Fig. 10) and core photographs.
These wells have relatively lower pressure regimes (~ 3700 psia) and facies associations of shelfal mudstone and barrier bar sands.
Barrier bar sands are interpreted as thickly bedded sandstone, low-angle laminations possibly representing remnant hummocky cross-stratifications (HCS) as seen in the cores (R).
Of the shallow marine (SM) facies, shoreface sands comprise about 21% and offshore bar sands comprise 8% of the total facies modeled in the reservoir.
Depo-facies modeling also shows that within marginal marine (MM) environment, tidal channel fill, point bar and mouth bar sands occupy 28% of cells within the facies model and tidal flats (sand flat/mixed flat/mudflat) constitute 10% of cells, whereas estuarine channel sand dominates with 26% of cells on the modeled reservoir.
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The spatial vector based program Ihssim is developed to characterize the inclined heterogeneity strata (IHS) inside the point bar sand at third level architecture study stage.
Thus, lens clusters are interpreted as discrete growth elements of the mouth bar sand lobes, and lenses as individual bedforms making up these growth elements.
Due to some great differences between the beach sand and the bar sand, the oil reservoirs of demonstration zone are divided into 2 sand groups, 8 small layers, and 17 sand bodies in total.
Within this environmental setting amalgamated lens clusters are interpreted as small, discrete mouth bar sand lobes, whose offset, imbricate stacking pattern reflects channel spacing and bifurcation, the rate of channel shifting, or shallow depths and lack of accommodation space.
One considers the reservoir bodies (fluvial belts) as homogeneous stacked point bar sand bodies (1st order heterogeneity, Model B), while the second type contains also flow barriers (shale oxbow lakes; 2nd order heterogeneity, Model A).
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