The 3-D distribution of property data is a powerful tool for understanding the spatial distribution based on hard well data and trends. The primary goals for building a 3-D reservoir model is to maximize the value of data by incorporating all available information into a quantitative, digital representation, handling large amounts of data, providing consistent analysis in 3-D, giving direct numerical input to flow simulation and pore-volume calculation, testing and visualizing multiple geological interpretations, and assessing uncertainties.

Integration is required to build a realistic 3-D reservoir geological model, including geophysics, geology, core, wireline logs and production data, and the reservoir engineering model. It imperative to minimize the uncertainties associated with volume estimations coming from a limited number of drilled wells in the field, reservoir geometry and geological structures, inconsistency of petrophysical properties, and water contact location.

In the present study, only one well is drilled in a relatively large area, leading to complications and consistent population of facies and petrophysical properties controlled by well data that assumes the homogeneity of the entire area. The uncertainties in defining original hydrocarbons in place, recoverable reserves, reservoir flow, and communications between reservoir layers become too high to optimize field performance and future development plans. Advanced modeling scenarios are performed based on the possibility of facies changes across the field area, seismic-depth conversion tolerance, field geometry, and structure. A perfect 3-D static reservoir model resulted, which matched identically to the dynamic reservoir engineering model and production history.

This paper explores a new methodology for 3-D reservoir modeling for fields with a limited number of drilled wells for the better understanding of field volumetrics and dynamic behavior and improving the decision on how, and where, to develop the field to drill more wells.

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