SummaryIn this paper, we apply mode decomposition and interpolatory projection methods to speed up simulations of two-phase flows in heterogeneous porous media. We propose intrusive and nonintrusive model-reduction approaches that enable a significant reduction in the size of the subsurface flow problem while capturing the behavior of the fully resolved solutions. In one approach, we use the dynamic mode decomposition. This approach does not require any modification of the reservoir simulation code but rather postprocesses a set of global snapshots to identify the dynamically relevant structures associated with the flow behavior. In the second approach, we project the governing equations of the velocity and the pressure fields on the subspace spanned by their properorthogonal-decomposition modes. Furthermore, we use the discrete empirical interpolation method to approximate the mobilityrelated term in the global-system assembly and then reduce the online computational cost and make it independent of the fine grid. To show the effectiveness and usefulness of the aforementioned approaches, we consider the SPE-10 benchmark permeability field, and present a numerical example in two-phase flow. One can efficiently use the proposed model-reduction methods in the context of uncertainty quantification and production optimization.
IntroductionHigh-fidelity reservoir-simulation models are shown to yield better predictions in optimization problems and in planning for new reservoir developments. However, the computational time of such large-scale models becomes the bottleneck of fast turnarounds in the decision-making process and the assimilation of real-time data into reservoir models (namely, the closed-loop reservoir management) to improve the accuracy of such models (Gildin and Lopez 2011). Even in the case of unconventional reservoirs, numerical reservoir simulation was used with several modifications with the current models, particularly in the nature of the flow. To this end, natural fractures and pore-space networks were incorporated in the simulation process to account for flow in the fractures and matrix (Moridis et al. 2010;Yan et al. 2013;Alfi et al. 2014).Despite the great advances in reservoir-modeling tools and the advent of high-performance computing, high-fidelity physicsbased numerical simulation still remains a challenging step in understanding the physics of the reservoir because of the largescale nature of the discretization of the underlying partial-differential equations. Computationally intensive simulations, such as in the case of history matching (Afra et al. 2014), optimization, and uncertainty quantification (Doren et al. 2006), become impractical to be performed in a timely manner if real-time data need to be assimilated into the model (Jansen et al. 2009;Gildin and Lopez 2011).The importance of obtaining a simpler model that can represent the physics of the full system is paramount to speed up the work flows that require several (from dozens to thousands) calls of the forward model. This is usu...