3D earth modeling is a key issue for Reservoir Characterization. Fluid flow simulations based on a reliable model of reservoir heterogeneities will provide better prediction of hydrocarbon production. Moreover the uncertainty on the reservoir structure, the rock properties and the contacts may be assessed by means of simulations that preserve the geological features of the reservoir. This paper deals with a geostatistical workflow of a 3D reservoir modeling applied to real data of a siltstone reservoir. The first key issue is the optimal use of the available data: the wells with information on markers of key horizons, lithofacies and porosity and an acoustic impedance cube that brings relevant information for constraining the porosity model and facies proportions. The second point is related to the comparison of different geostatistical methods. The main steps of the workflow are: - Surfaces simulations delimiting the top and bottom of the reservoir, using the information from wells. - Facies simulations (Sequential Indicator Simulation, Truncated Plurigaussian Simulation). It requires the building of a flat stratigraphic grid (Flattening) within which variograms calculations and simulations are performed. After the flattening, the 3D vertical proportions curves (VPC) are computed. A 2D proportion constrained by a seismic attribute is used to constrain the 3D VPC. These proportions are used for the facies simulation. - 3D porosity simulations are achieved independently for each facies, then a cookie cutting procedure constrained by the facies simulations provide the final porosity simulations. - Finally, simulations are transferred from the stratigraphic space to the real space. Several types of simulations are used (Surfaces simulations, SIS, TPGS, 2D porosity simulations, 3D porosity simulations, contact). To evaluate the different available models, volumetric calculations based on simulations of the different parameters provide stochastic distributions of volumes.


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