Microfluidic experiments and numerical simulation methods of pore-scale multiphase flow

Jianchao Cai, Jianlin Zhao, Junjie Zhong, Bate Bate

Abstract view|83|times       PDF download|44|times

Abstract


Multiphase flow is a common scenario in industrial and environmental applications. Especially at microscopic scale, accurately describing flow processes is challenging due to fluid-fluid, fluid-solid, and solid-solid interactions. Pore-scale microfluidics and numerical simulation methods considering complex topology are increasingly being applied to study multiphase flow phenomena. This work focuses the recent applications of microfluidic experiments and new numerical simulations in complex flows for enhanced oil recovery. Two types of coupling algorithms are provided to integrate the advantages of pore network model and direct numerical simulation methods. For fines migration, the computational fluid dynamics-discrete element method is proposed to describe the coupling process between fluid and solid particles. Pore-scale microfluidic experiments and simulation methods deals with complex flow processes at micro/nano scales, providing effective solutions for complex industrial processes.

Document Type: Perspective

Cited as: Cai, J., Zhao, J., Zhong, J., Bate, B. Microfluidic experiments and numerical simulation methods of pore-scale multiphase flow. Capillarity, 2024, 12(1): 1-5. https://doi.org/10.46690/capi.2024.07.01


Keywords


Microfluidics, pore network model, numerical simulation, multiphase flow, pore-scale modeling

Full Text:

PDF

References


Abolhasani, M., Günther, A., Kumacheva, E. Microfluidic studies of carbon dioxide. Angewandte Chemie International Edition, 2014, 53(31): 7992-8002.

Ayaz, M., Toussaint, R., Schäfer, G., et al. Gravitational and finite-size effects on pressure saturation curves during drainage. Water Resources Research, 2020, 56(10): e2019WR026279.

Bao, B., Riordon, J., Mostowfi, F., et al. Microfluidic and nanofluidic phase behaviour characterization for industrial CO2, oil and gas. Lab on a Chip, 2017, 17(16): 2740-2759.

Bate, B., Chen, C., Liu, P., et al. The migration and deposition behaviors of montmorillonite and kaolinite particles in a two-dimensional micromodel. Materials, 2022, 15(3): 855.

Cai, J., Wood, D. A., Hajibeygi, H., et al. Multiscale and multiphysics influences on fluids in unconventional reservoirs: Modeling and simulation. Advances in Geo-Energy Research, 2022, 6(2): 91-94.

Celia, M. A., Bachu, S., Nordbotten, J. M., et al. Status of CO2 storage in deep saline aquifers with emphasis on modeling approaches and practical simulations. Water Resources Research, 2015, 51(9): 6846-6892.

Chen, K., Liu, P., Wang, W., et al. Effects of capillary and viscous forces on two-phase fluid displacement in the microfluidic model. Energy & Fuels, 2023, 37(22): 17263-17276.

Chen, L., He, A., Zhao, J., et al. Pore-scale modeling of complex transport phenomena in porous media. Progress in Energy and Combustion Science, 2022a, 88: 100968.

Chen, R., Chen, Y., Xu, W., et al. The influence of the hypergravity field during bubble ripening in porous media. Geophysical Research Letters, 2022b, 49(10): e2021GL097005.

Del Giudice, F. Simultaneous measurement of rheological properties in a microfluidic rheometer. Physics of Fluids, 2020, 32(5): 52001.

Gaol, C., Wegner, J., Ganzer, L., et al. Investigation of porescale mechanisms of microbial enhanced oil recovery meor using microfluidics application. Paper SPE 195553 Presented at SPE Europec featured at 81st EAGE Conference and Exhibition, London, England, 3-6 June, 2019.

Gaol, C. L., Wegner, J., Ganzer, L. Real structure micromodels based on reservoir rocks for enhanced oil recovery (eor) applications. Lab on a Chip, 2020, 20(12): 2197-2208.

Huppert, H. E., Neufeld, J. A. The fluid mechanics of carbon dioxide sequestration. Annual Review of Fluid Mechanics, 2014, 46: 255-272.

Jung, J. W., Jang, J., Santamarina, J. C., et al. Gas production from hydrate-bearing sediments: The role of fine particles. Energy & Fuels, 2012, 26(1): 480-487.

Krevor, S., Blunt, M. J., Benson, S. M., et al. Capillary trapping for geologic carbon dioxide storage-from pore scale physics to field scale implications. International Journal of Greenhouse Gas Control, 2015, 40: 221-237.

Lifton, V. A. Microfluidics: An enabling screening technology for enhanced oil recovery (EOR). Lab on a Chip, 2016, 16(10): 1777-1796.

Liu, J., Zhang, Y., Wei, M., et al. Fabrications and applications of micro/nanofluidics in oil and gas recovery: A comprehensive review. Energy & Fuels, 2022, 36(17): 9904-9931.

Liu, P., Nie, S., Wang, W., et al. Cfd-dem study on transport and retention behaviors of nzvi-clay colloids in porous media. Journal of Hazardous Materials, 2024, 465: 133048.

Liu, P., Sun, M., Chen, Z., et al. Influencing factors on fines deposition in porous media by cfd-dem simulation. Acta Geotechnica, 2023, 18: 4539-4563.

Liu, Q., Zhao, B., Santamarina, J. C. Particle migration and clogging in porous media: A convergent flow microfluidics study. Journal of Geophysical Research: Solid Earth, 2019a, 124(9): 9495-9504.

Liu, Y., Zhang, Y., Lan, S., et al. Migration experiment and numerical simulation of modified nanoscale zero-valent iron (nzvi) in porous media. Journal of Hydrology, 2019b, 579: 124193.

Mehmani, Y., Tchelepi, H. A. Multiscale formulation of two-phase flow at the pore scale. Journal of Computational Physics, 2019, 389: 164-188.

Miao, X., Gerke, K. M., Sizonenko, T. O. A new way to parameterize hydraulic conductances of pore elements: A step towards creating pore-networks without pore shape simplifications. Advances in Water Resources, 2017, 105: 162-172.

Nguyen, P., Fadaei, H., Sinton, D. Pore-scale assessment of nanoparticle-stabilized CO2 foam for enhanced oil recovery. Energy & Fuels, 2014, 28(10): 6221-6227.

Othman, F., Yu, M., Kamali, F., et al. Fines migration during supercritical CO2 injection in sandstone. Journal of Natural Gas Science and Engineering, 2018, 56: 344-357.

Rabbani, A., Babaei, M. Hybrid pore-network and lattice-boltzmann permeability modelling accelerated by ma chine learning. Advances in Water Resources, 2019, 126: 116-128.

Sholokhova, Y., Kim, D., Lindquist, W. B. Network flow modeling via lattice-boltzmann based channel conductance. Advances in Water Resources, 2009, 32(2): 205-212.

Sun, J., Li, Z., Furtado, F., et al. A microfluidic study of transient flow states in permeable media using fluorescent particle image velocimetry. Capillarity, 2021, 4(4): 76-86.

Van Marcke, P., Verleye, B., Carmeliet, J., et al. An improved pore network model for the computation of the saturated permeability of porous rock. Transport in Porous Media, 2010, 85: 451-476.

Vincent-Dospital, T., Moura, M., Toussaint, R., et al. Stable and unstable capillary fingering in porous media with a gradient in grain size. Communications Physics, 2022, 5(1): 306.

Xu, D., Bai, B., Wu, H., et al. Mechanisms of imbibition enhanced oil recovery in low permeability reservoirs: Effect of ift reduction and wettability alteration. Fuel, 2019, 244: 110-119.

Xu, Z., Pillai, K. M. Analyzing slow drying in a porous medium placed adjacent to laminar airflow using a pore-network model. Numerical Heat Transfer, Part A: Applications, 2016, 70(11): 1213-1231.

Xu, Z., Pillai, K. M. A pore-network study on the factors influencing the isothermal drying of single-and dual-scale porous media. Drying Technology, 2021, 39(10): 1294-1313.

Zhao, B., MacMinn, C. W., Primkulov, B. K., et al. Comprehensive comparison of pore-scale models for multiphase flow in porous media. Proceedings of the National Academy of Sciences of the United States of America, 2019, 116(28): 13799-13806.

Zhao, J., Liu, Y., Qin, F., et al. Pore-scale fluid flow simulation coupling lattice boltzmann method and pore network model. Capillarity, 2023, 7(3): 41-46.

Zhao, J., Qin, F., Derome, D., et al. Simulation of quasi-static drainage displacement in porous media on pore-scale: Coupling lattice boltzmann method and pore network model. Journal of Hydrology, 2020a, 588: 125080.

Zhao, J., Qin, F., Derome, D., et al. Improved pore network models to simulate single-phase flow in porous media by coupling with lattice boltzmann method. Advances in Water Resources, 2020b, 145: 103738.

Zhao, J., Qin, F., Kang, Q., et al. Pore-scale simulation of drying in porous media using a hybrid lattice boltzmann: Pore network model. Drying Technology, 2022, 40(4): 719-734.

Zhong, J., Abedini, A., Xu, L., et al. Nanomodel visualization of fluid injections in tight formations. Nanoscale, 2018, 10(46): 21994-22002.

Zhong, J., Alibakhshi, M. A., Xie, Q., et al. Exploring anomalous fluid behavior at the nanoscale: Direct visualization and quantification via nanofluidic devices. Accounts of Chemical Research, 2020, 53(2): 347-357.


Refbacks

  • There are currently no refbacks.


Copyright (c) 2024 The Author(s)

Creative Commons License
This work is licensed under a Creative Commons Attribution-NonCommercial-NoDerivatives 4.0 International License.

Copyright ©2018. All Rights Reserved