Presentation on theme: "Pore-to-Field Upscaling of Immiscible Two-Phase Flow Hasan Nooruddin Martin Blunt Jan 2015."— Presentation transcript:
Pore-to-Field Upscaling of Immiscible Two-Phase Flow Hasan Nooruddin Martin Blunt Jan 2015
Outline What is upscaling? Why to scale-up multiphase flow properties? Upscaling methods – brief background How are we going to upscale multiphase flow?
What is upscaling? Upscaling is a process to determine effective multiphase flow properties on larger scales while capturing small-scale heterogeneity. (Rhodes et al. 2008)
Introduction Relative PermeabilityCapillary Pressure Field-scale reservoir simulation study always suffer from a shortage of SCAL data. Pore-network modelling provides a practical tool to generate large datasets of physically-consistent multiphase flow properties relatively quickly. We need to scale-up this information to a field-scale reservoir simulation gridblock. to include other heterogeneities found at larger scales. to address the impact of fluid forces acting at larger scales (e.g., impact of global boundary conditions)
Why do we need to upscale pore-scale multiphase flow ? If it is not the REV: We need to include other heterogeneities at larger scales. Assuming REV: We need to address the impact of fluid forces acting at larger scales (e.g., impact of global boundary conditions)
Steady-state method Computationally cheaper than dynamic methods Key issue is to find the saturation distribution CL: constant capillary pressure VL: constant fractional flow CL+VL: simulate until steady-state is reached – similar to dynamic method Apply sequence of single-phase simulations Repeat the process at different average saturations
Unsteady-state method Require running the fine-gridded model – Computationally demanding Account for numerical dispersion Case dependent – have to be reproduced for different flood rates and directions. Might generate unphysical relative permeability curves (non-monotone flux)
Our approach mm scale cm scale m scale Facies-model scale Multistage approach starting from an accurate representation at the pore level. Pore-network model: capillary-controlled displacement – valid for most conditions at pore level. good starting point – does not depend on BC. Incorporate pore-, core-, intermediate-, and large-scale heterogeneities, as required. Including the right balance of forces at each stage. Represent physics and geology.
Our approach We need to develop a simulator: Incompressible, two-phase flow simulator Includes viscous, capillary and gravitational forces Unstructured – to effectively capture heterogeneities at all upscaling stages (Rhodes et al. 2008)