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A Middle Eastern Cretaceous rudist-bearing carbonate reservoir is chosen for this study. This limestone sequence (about 55 m [180 ft] thick) consists of tight argillaceous mudstones and wackestones at the base, grading upward into a more porous section dominated by bioclastic grainstones and packstones.

Applying sequence-stratigraphic concepts, the reservoir is classified into two main sequences. In addition, the upper zone is further divided into two sequences of smaller accommodation cycles. Each of the latter includes a distinctive reservoir type (i.e., dominated by either barrier or shoal facies). The lower main sequence is considered as one unified nonreservoir cycle in the study area of the field. The three-dimensional seismic and sequence-stratigraphic analyses are used in conjunction with designing a deterministic structural model. A three-layer model is used, each layer representing a stratigraphic sequence previously recognized.

Describing the facies and flow units of carbonate reservoirs for reservoirsimulation purposes is a critical task that needs careful study of both the depositional textures and the diagenetic overprints in a sequence-stratigraphic framework. Eight main depositional facies are recognized for facies-modeling purposes. However, only two of them are high-quality reservoirs, dominated by grain-supported textures.

The reservoir architecture is generated using a combination of grid-and object-based simulation techniques to accurately reproduce the facies-and reservoir-type distributions. Petrophysical parameters porosity and permeability are stochastically simulated within facies bodies using a Gaussian cosimulation algorithm. Well data are used as hard information that must be honored, whereas acoustic impedance information is used to define porosity maps, which are used as conditioning trends in the simulation. These trends are believed to represent the effects of diagenesis.

Statistical analysis of the relationship between acoustic impedance and porosity allowed us to use impedance-derived porosity trends as conditioning data in petrophysical simulation. These porosity trends, adjusted to the range of data values from the wells, are believed to represent the effects of diagenetic activity. Using these trends alters the resultant data distribution compared with the distribution as inferred from well data. This is a consequence of the assumption that these porosity trends do reflect diagenesis and, in addition, does so not only at the wells but in theinterwell areas as well.

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