Studying key processes related to CO<sub>2</sub> underground storage at the pore scale using high pressure micromodels

Morais, Sandy; Cario, Anaïs; Liu, Na; Bernard, Dominique; Lecoutre, Carole; Garrabos, Yves; Ranchou-Peyruse, Anthony; Dupraz, Sébastien; Azaroual, Mohamed; Hartman, Ryan L.; Marre, Samuel

doi:10.1039/d0re00023j

Cited by 23 publications

(16 citation statements)

References 245 publications

(287 reference statements)

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“…With the help of micromodel experiments, CO 2 diffusion and convective mixing into different pore arrangements can be investigated. Morais, et al [40] conducted an extensive review of key processes related to CO 2 underground storage at the pore scale using high-pressure micromodels. In this experimental study, we observed CO 2 convective mixing, using a micromodel apparatus at reservoir representative pressure and temperature conditions (i.e., at 100 bar and 50 • C, respectively), in both a 100% water saturation system and a residual oil-saturated system.…”

Section: Methodsmentioning

confidence: 99%

A Visual Investigation of CO2 Convective Mixing in Water and Oil at the Pore Scale Using a Micromodel Apparatus at Reservoir Conditions

Amarasinghe

Farzaneh

Fjelde

et al. 2021

Gases

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CO2 convective mixing in water has been visualized in Hele-Shaw and PVT cell experiments but not at the pore scale. Furthermore, CO2 convective mixing in a three-phase system (i.e., CO2 in the presence of both water and oil) has not been visually investigated. A vertically placed micromodel setup was used to visualize CO2 convective mixing at 100 bar and 50 °C, representative of reservoir conditions. To the best of our knowledge, for the first time, we have visually investigated CO2 convective mixing in water at the pore scale and also CO2 convective mixing in a multiphase system (water and oil). CO2 mixing in water governed by both diffusion and convection mechanisms was observed. The vertical CO2 transport velocity was calculated to be 0.3 mm/min in both a 100% water saturation system and a residual oil-saturated system. First, CO2 always found the easiest path through the connected pores, and then CO2 was transported into less connected pores and dead-end pores. CO2 transport into dead-end pores was slower than through the preferential path. CO2 transport into water-filled ganglia with trapped oil was observed and was slower than in water.

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Section: Methodsmentioning

confidence: 99%

A Visual Investigation of CO2 Convective Mixing in Water and Oil at the Pore Scale Using a Micromodel Apparatus at Reservoir Conditions

Amarasinghe

Farzaneh

Fjelde

et al. 2021

Gases

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“…For more direct comparisons with geological materials, micromodels can be constructed of minerals, rocks, or other geomaterials (Gerami et al, 2017;Mohammadi & Mahani, 2020;Porter et al, 2015;Y. Song et al, 2012), operated at high pressure and temperature conditions (Morais et al, 2020;Porter et al, 2015), or operated with applied normal stress (Detwiler, 2008). These systems have been used to assess a wide variety of phenomena, including the impact of dissolution and stress (Detwiler, 2008); dissolution/precipitation under multiphase flow conditions (Jiménez-Martínez et al, 2020); turbulent flow and chemical reactions (Lee & Kang, 2020); gravity-driven homogeneous precipitation in a fracture (Jiménez-Martínez et al, 2020), and multiphase flow (Keller et al, 1997).…”

Section: Transparent Analog Systems and Microfluidicsmentioning

confidence: 99%

From Fluid Flow to Coupled Processes in Fractured Rock: Recent Advances and New Frontiers

Viswanathan

Ajo‐Franklin

Birkhölzer

et al. 2022

Reviews of Geophysics

113

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Quantitative predictions of natural and induced phenomena in fractured rock is one of the great challenges in the Earth and Energy Sciences with far‐reaching economic and environmental impacts. Fractures occupy a very small volume of a subsurface formation but often dominate fluid flow, solute transport and mechanical deformation behavior. They play a central role in CO2 sequestration, nuclear waste disposal, hydrogen storage, geothermal energy production, nuclear nonproliferation, and hydrocarbon extraction. These applications require predictions of fracture‐dependent quantities of interest such as CO2 leakage rate, hydrocarbon production, radionuclide plume migration, and seismicity; to be useful, these predictions must account for uncertainty inherent in subsurface systems. Here, we review recent advances in fractured rock research covering field‐ and laboratory‐scale experimentation, numerical simulations, and uncertainty quantification. We discuss how these have greatly improved the fundamental understanding of fractures and one's ability to predict flow and transport in fractured systems. Dedicated field sites provide quantitative measurements of fracture flow that can be used to identify dominant coupled processes and to validate models. Laboratory‐scale experiments fill critical knowledge gaps by providing direct observations and measurements of fracture geometry and flow under controlled conditions that cannot be obtained in the field. Physics‐based simulation of flow and transport provide a bridge in understanding between controlled simple laboratory experiments and the massively complex field‐scale fracture systems. Finally, we review the use of machine learning‐based emulators to rapidly investigate different fracture property scenarios and accelerate physics‐based models by orders of magnitude to enable uncertainty quantification and near real‐time analysis.

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“…Extensively characterized surface modification properties based on the silanol group (−Si–OH), along with chemical resistance and flexibility in design, makes silicon a desirable material for the fabrication of microfluidic devices . Moreover, silicon-based micromodels are better than glass-based micromodels for better quality control and high geometry resolution while still keeping the merits of glass, such as good chemical stability and feasible wettability alteration . Further, silicon can withstand temperatures as high as 1400 °C and high elastic modulus (130–180 GPa) .…”

Section: Micro/nanofluidic Materialsmentioning

confidence: 99%

Fabrications and Applications of Micro/Nanofluidics in Oil and Gas Recovery: A Comprehensive Review

et al. 2022

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Understanding fluid flow characteristics in porous medium, which determines the development of oil and gas oilfields, has been a significant research subject for decades. Although using core samples is still essential, micro/nanofluidics have been attracting increasing attention in oil recovery fields since it offers direct visualization and quantification of fluid flow at the pore level. This work provides the latest techniques and development history of micro/nanofluidics in oil and gas recovery by summarizing and discussing the fabrication methods, materials and corresponding applications. Compared with other reviews of micro/nanofluidics, this comprehensive review is in the perspective of solving specific issues in oil and gas industry, including fluid characterization, multiphase fluid flow, enhanced oil recovery mechanisms, and fluid flow in nano-scale porous media of unconventional reservoirs, by covering most of the representative visible studies using micro/nanomodels. Finally, we present the challenges of applying micro/nanomodels and future research directions based on the work.

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Studying key processes related to CO₂ underground storage at the pore scale using high pressure micromodels

Abstract: Micromodels experimentation for studying and understanding CO2 geological storage mechanisms at the pore scale.

Cited by 23 publications

References 245 publications

A Visual Investigation of CO2 Convective Mixing in Water and Oil at the Pore Scale Using a Micromodel Apparatus at Reservoir Conditions

A Visual Investigation of CO2 Convective Mixing in Water and Oil at the Pore Scale Using a Micromodel Apparatus at Reservoir Conditions

From Fluid Flow to Coupled Processes in Fractured Rock: Recent Advances and New Frontiers

Fabrications and Applications of Micro/Nanofluidics in Oil and Gas Recovery: A Comprehensive Review

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Studying key processes related to CO2 underground storage at the pore scale using high pressure micromodels

Abstract: Micromodels experimentation for studying and understanding CO2 geological storage mechanisms at the pore scale.

Cited by 23 publications

References 245 publications

A Visual Investigation of CO2 Convective Mixing in Water and Oil at the Pore Scale Using a Micromodel Apparatus at Reservoir Conditions

A Visual Investigation of CO2 Convective Mixing in Water and Oil at the Pore Scale Using a Micromodel Apparatus at Reservoir Conditions

From Fluid Flow to Coupled Processes in Fractured Rock: Recent Advances and New Frontiers

Fabrications and Applications of Micro/Nanofluidics in Oil and Gas Recovery: A Comprehensive Review

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Product

Resources

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Studying key processes related to CO₂ underground storage at the pore scale using high pressure micromodels