An insight into core flooding experiment via NMR imaging and numerical simulation. (15th June 2022)

• Record Type: Journal Article
• Authors: Siavashi, Javad; Najafi, Arman; Sharifi, Mohammad; Fahimpour, Jalal; Shabani, Mehdi; Liu, Bo; Liu, Kouqi; Yan, Jun; Ostadhassan, Mehdi
• Is Part Of: Fuel. Volume 318(2022)
• Publication Date: 2022-06-15
• Subjects: Multiphase flow -- Relative permeability curve -- Water flooding -- Nuclear Magnetic Resonance (NMR) -- Magnetic Resonance Imaging (MRI) -- Numerical simulation; Fuel -- Periodicals; Coal -- Periodicals; Coal; Fuel; Periodicals; 662.6
• DOI: 10.1016/j.fuel.2022.123589
• Languages: English
• ISSNs: 0016-2361

Abstract

Highlights: Traditional core flooding experiment was combined with NMR based imaging technique to delineate pre breakthrough multiphase fluid flow processes. Theoretical methods, FDM and FEM were employed to reproduce experimental data such as: oil displacement efficiency, saturation maps, and saturation profiles. Combination of NMRI and FDM-FEM approaches enabled us to generate an appropriate relative permeability curve for the sample for future field scale reservoir simulations. Abstract: Traditional core flooding experiments can only be used post breakthrough while what happens in the core prior to this time is vital to understand multiphase flow phenomenon for more successful EOR operations. We can overcome this obstacle through a visualized fluid displacement scheme. This can ultimately provide us with a reliable relative permeability curve that can lead to a more accurate reservoir simulation outcome in the field scale. In this study, NMR imaging is employed in a water flood experiment in conjunction with two separate numerical two-phase flow simulation methods (FDM and FEM), to reproduce experimental data. Using the Brooks-Corey equation, random pore size distribution indices (λ) are selected to generate relative permeability curves. Moreover, simulations are performed with FDM, and oil displacement efficiency, saturation maps, and saturation profiles are generated and compared to the experimental results. Next, FEM was employed in COMSOL for further validation and FDM results were found in agreement with the experiments. This way, an appropriate relative permeability curve was generated and assigned to the sample. Results suggest that λ of 0.2 generated the best numerical results with an MSE value of 0.009 in oil displacement efficiency curves, comparable to the experiments. Collectively, integration of imaging techniques with routine experimental fluid displacement procedures presented a detailed insight into complicated nature of multiphase flow phenomena in geomaterials.