This work discusses an integrated characterization of a shallow-marine carbonate oil reservoir of the Cenomanian age, taking advantage of high-quality 3D seismic data. 3D seismic attribute and AVO inversion analysis were applied and revealed field-wide reservoir heterogeneity. The most noticeably, 3D slices of seismic attribute visualized gigantic channel-shaped signatures that traverse across the field, with their widths and thicknesses reaching upto 3km and over 100m, respectively. In the 3D sdata, the "channels" appeared to be erosional and the channel-fill sediments are less porous and more argillaceous than the surroundings, often accompanied by underlying porous property. A well suggested the channel-fill sediments to be low-porosity karst-related breccia and the underlying interval is productive in the well test. Integration of these seismic and well observations led to a unified interpretation that the channels are formed by Turonian erosional incision and the channel-fills are likely to be muddy/tight sediments. Due to the tight property, the channels were considered as possible cause of reservoir compartmentalization identified from well data. Throughout this work, 3D seismic was utilized as the key driver of the integrated evaluation and was confirmed to successfully reveal critical carbonate reservoir characteristics.


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