Flow-through Drying during CO<mml:math xmlns:mml="http://www.w3.org/1998/Math/MathML" altimg="si3.svg"><mml:msub><mml:mrow/><mml:mn>2</mml:mn></mml:msub></mml:math>Injection into Brine-filled Natural Fractures: A Tale of Effective Normal Stress

Lima, Marina Grimm; Javanmard, Hoda; Vogler, Daniel; Saar, Martin O.; Kong, Xiang-Zhao

doi:10.1016/j.ijggc.2021.103378

International Journal of Greenhouse Gas Control

2021

DOI: 10.1016/j.ijggc.2021.103378

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Flow-through Drying during CO2Injection into Brine-filled Natural Fractures: A Tale of Effective Normal Stress

Marina Grimm Lima

Hoda Javanmard

Daniel Vogler

et al.

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Cited by 2 publications

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“…Compressed CO 2 is usually injected in a brine saturated reservoir (usually sandstone or limestone) and because the density of the injected CO 2 is lower than that of the in-situ brine, CO 2 migrates upwards until in contact with the caprock; this is referred to as plume effect 5,6 (see Fig. 1) or as formation dry-out 7,8 .…”

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Evaluating CO2 breakthrough in a shaly caprock material: a multi-scale experimental approach

Stavropoulou

Laloui

2022

Sci Rep

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The potential of underground $$\hbox {CO}_2$$ CO 2 storage relies on the sealing efficiency of an overlaying caprock that acts as a geological barrier. Shales are considered as potential caprock formations thanks to their favourable hydro-mechanical properties. In this work the sealing capacity of Opalinus Clay shale to $$\hbox {CO}_2$$ CO 2 injection is studied by means of capillary entry-pressure and volumetric response. The overall objective of this work is to contribute to the safe design of a $$\hbox {CO}_2$$ CO 2 injection strategy by providing a better understanding of the geomechanical response of the caprock material to $$\hbox {CO}_2$$ CO 2 injection and eventual breakthrough at different scales. This is achieved by relating lab-measured hydro-mechanical properties of the studying caprock material (porosity, permeability, volumetric response) to field-related parameters (effective stress, injection pressure). A number of $$\hbox {CO}_2$$ CO 2 breakthrough tests is performed in Opalinus Clay samples under two different scales, meso and micro. At the meso-scale, $$\hbox {CO}_2$$ CO 2 injection is performed in oedometric conditions under different levels of axial effective stress in both gaseous or liquid phase. In parallel, the material’s transport properties in terms of water permeability are assessed before $$\hbox {CO}_2$$ CO 2 injection at each corresponding level of effective stress. The impact of $$\hbox {CO}_2$$ CO 2 phase and open porosity on the material’s $$\hbox {CO}_2$$ CO 2 entry pressure are demonstrated. The correlation between measured entry pressure and absolute permeability is discussed. A second testing campaign at a smaller scale is presented where $$\hbox {CO}_2$$ CO 2 breakthrough is for the first time identified with in-situ X-ray tomography. $$\hbox {CO}_2$$ CO 2 injection is performed under isotropic conditions on an Opalinus Clay micro-sample (micro-scale), and $$\hbox {CO}_2$$ CO 2 breakthrough is identified through quantitative image analysis based on the measured localised volumetric response of the material. This innovative methodology provides important insight into the anisotropic response of this complex material that is indispensable for its representative modelling in the context of safe geological $$\hbox {CO}_2$$ CO 2 storage.

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Evaluating CO2 breakthrough in a shaly caprock material: a multi-scale experimental approach

Stavropoulou

Laloui

2022

Sci Rep

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A review of experimental investigations on salt precipitation during CO2 geological storage

Sun,

Liu,

et al. 2025

Geoenergy Science and Engineering

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Flow-through Drying during CO2Injection into Brine-filled Natural Fractures: A Tale of Effective Normal Stress

Cited by 2 publications

References 76 publications

Evaluating CO2 breakthrough in a shaly caprock material: a multi-scale experimental approach

Evaluating CO2 breakthrough in a shaly caprock material: a multi-scale experimental approach

A review of experimental investigations on salt precipitation during CO2 geological storage

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