Abstract
Large percentage of reservoir has heterogeneous structure e.g. carbonate and shales. The numerical analysis of multi-phase fluid flows using digital rock is a complex and challenging problem especially for rocks exhibiting pores with multiple length scales. Micro-CT imaging focuses on a single scale and there is a tradeoff between enough resolution to capture the most relevant pore types and large enough volume to be statistically representative. Some pore types are left under-resolved in micro-CT images, and ignoring their contribution to flow simulation can lead to large errors, particularly for two-phase flow simulations
This Tech Talk we will demonstrate an extension to our LBM fluid flow solver to account for single-phase and two-phase flow in under-resolved porous regions in addition to resolved pores and presented simulation results for absolute permeability, capillary pressure and relative permeability
Highlights:
- Extend DigitalROCK LBM fluid flow solver of single scale to multi-scale scenario which exists in large percentage of reservoir formation
- Accurately predict flow behavior for complex, multiscale rock types like Carbonates and Shales by modeling unresolved pore structure
- Unique multiphysics and multiscale solutions for rock characterization
Speaker
@GS | Industry Process Expert Specialist - Infrastructure, Energy & Materials Simulation Enablement
Guangyuan Sun is industry process expert specialist for the Energy Industry Processes group within the SIMULIA brand of Dassault Systèmes. His research interests include computational fluid dynamics (CFD), multiphase flow and CO2 geological storage. He holds a Ph.D. in Chemical Engineering from Brigham Young University.
