Reservoir Simulation
1. To what extent, the pore-scale modeling methods remain useful in predicting ‘the macroscopic properties’ of reservoir rock/fluid properties - towards describing the multi-phase flow behavior of petroleum reservoir fluids – at the expense of formulating the governing equations @ pore-scale – using either DNS (computationally costly Direct Numerical Simulation – addressing limited pore volumes) or PNM (computationally efficient Pore Network Modelling – addressing pore-size, pore-shape, pore-throat and connectivity correlations) of NSE (Navier Stokes Equation) – aided with a detailed description of pore space morphology?
2. Feasible to generate a three-dimensional complex network of a pore geometry with a wide range of grain size distribution (that varies over several orders of magnitude) using advanced micro-computed tomography imaging technique – in order to translate the complex pore networks associated with varied length-scales to a single multi-scale pore network?
3. To what extent, IMPES scheme would remain efficient for a three-phase fluid reservoir with strong heterogeneities?
OR
Simultaneous Solution would remain to be a better approach in order to handle strongly coupled non-linear PDEs simultaneously and implicitly – while maintaining their stability & accuracy with the luxury of using a relatively larger time step?
OR
Sequential methods remain to be more meaningful – as we deal with multiple chemical components (compositional)?
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