Direct Imaging of Bubble Ripening in Two-dimensional Porous Media Micromodels

Joewondo, Nerine; Garbin, Valeria; Pini, Ronny

doi:10.2139/ssrn.3820624

Cited by 1 publication

(1 citation statement)

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“…Since they block a portion of the void space and contribute significant fluid–fluid interfacial area, they can have a sizable impact on the hydraulic conductivity (Anton & Hilfer, 1999; Bear, 1996), mass and heat transfer coefficients (Ehlers & Häberle, 2016; Ozgumus & Mobedi, 2015), and chemical reaction rate (Lay et al., 1996; Yortsos & Stubos, 2001) in a porous medium. As a result, the distribution and morphology of a population of bubbles are of significant interest in oil and gas recovery (Gao et al., 2021; Geistlinger et al., 2015; A. Mehmani et al., 2019) and geologic CO 2 storage (Fu et al., 2013; Huppert & Neufeld, 2014; Joewondo et al., 2021; Juanes et al., 2006; Li et al., 2020; Lyu et al., 2021).…”

Section: Introductionmentioning

confidence: 99%

Bubble Coarsening Kinetics in Porous Media

Wang

Liu

et al. 2022

Geophysical Research Letters

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Bubbles in subsurface porous media spontaneously coarsen to reduce free energy. Bubble coarsening dramatically changes surface area and pore occupancy, which affect the hydraulic conductivity, mass and heat transfer coefficients, and chemical reactions. Coarsening kinetics in porous media is thus critical in modeling geologic CO2 sequestration, hydrogen subsurface storage, hydrate reservoir recovery, and other relevant geophysical problems. We show that bubble coarsening kinetics in porous media fundamentally deviates from classical Lifshitz‐Slyozov‐Wagner theory, because porous structure quantizes the space and rescales the mass transfer coefficient. We develop a new coarsening theory that agrees well with numerical simulations. We identify a pseudo‐equilibrium time proportional to the cubic of pore size. In a typical CO2 sequestration scenario, local equilibrium can be achieved in 1s for media consisting of sub‐micron pores, while in decades for media consisting of 1 mm pores. This work provides new insights in modeling complex fluid behaviors in subsurface environment.

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