Models with different geological heterogeneity and fluid mobility ratios are considered. We apply the method to two-dimensional synthetic models of multiple realizations for uncertainty quantification. The procedure is designed to maintain close correspondence between the cumulative distribution functions for the numerically computed and statistically estimated two-phase flow functions. For the majority of blocks, these functions are estimated statistically based on single-phase velocity information (attributes), determined when the upscaled single-phase parameters are calculated. This approach allows us to numerically compute the upscaled two-phase flow functions for only a small portion of the coarse blocks. For this purpose, flow-based upscaling calculations are combined with a statistical estimation procedure (cluster analysis). ![]() ![]() In this work we develop and test a new approach, ensemble level upscaling, for efficiently generating upscaled two-phase flow parameters (e.g., upscaled relative permeabilities) for multiple geological realizations. Most existing upscaling procedures aim to reproduce fine-scale results for a particular geological model (realization). Abstract Upscaling is often needed in reservoir simulation to coarsen highly detailed geological descriptions.
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