Density-induced CO2 dissolution - approaches to test a new hypothesis on a process relevant for epigenetic karstification

<p><strong>Density-induced CO<sub>2</sub> dissolution - approaches to test a new hypothesis on a process relevant for epigenetic karstification   </strong></p><p>A process which has not yet been discussed as relevant for epigenetic karstification in phreatic zones has been hypothesized in a publication by Scherzer et al. (2017). It refers to an enhanced CO<sub>2</sub> transport into the phreatic zone by density-induced convective dissolution. The phenomenon is well-known also in CO<sub>2</sub> geologic sequestration and is denoted there typically as solubility trapping. Scherzer et al. (2017) denote this process in caves as nerochytic speleogenesis (from nerochytic = sink in Greek), assuming it has relevance for epigenetic karstification under certain circumstances. This could be relevant in particular in caves where CO<sub>2</sub> concentrations are highly elevated and show strong seasonal fluctuations.</p><p>Thomas et al. (2015) have introduced a method to visualize fingering patterns of CO<sub>2</sub> convective dissolution in water with a pH-sensitive color indicator. We have used this approach to produce a set of experimental data in a laboratory flume of dimensions 60 cm x 40 cm x 1 cm. Our aim is to validate a numerical model that we implemented in the simulator DuMu<sup>x </sup>(www.dumux.org), which can later on be used for future studies as the basis for investigating the relevance of nerochytic speleogenesis for karstification.</p><p>We have applied atmospheres with varying concentrations of carbon dioxid as boundary conditions at the top of the flume and observed the onset times and fingering patterns, in particular we focused on the velocity of the fingers.</p><p>The Navier-Stokes model with water density dependent on CO<sub>2</sub> concentration is run in 2D, 3D and pseudo 3D, the latter referring to a 2D approach with a drag term in the momentum balance to account for wall friction at the front and the back plate. Without calibration or fitting of parameters, the results of the comparison between experiment and simulation show reasonable agreement both with respect to the onset of convective fingering and the number of fingers occurring.</p><p>References:</p><p>H. Scherzer, H. Class, K. Weishaupt, T. Sauerborn, O. Trötschler: Nerochytische Speläogenese: Konvektiver Vertikaltransport von gelöstem CO<sub>2</sub> - ein Antrieb für Verkarstung in der phreatischen Zone im Bedeckten Karst, Laichinger Höhlenfreund 52:29-35, ISSN 0344 6832, 2017.<br> </p><p>C. Thomas, L. Lemaigre, A. Zalts, A. D'Onofrio, A. De Wit: Experimental study of CO<sub>2</sub> convective dissolution: the effect of color indicators, International Journal of Greenhouse Gas Control 42:525-533,2015.</p>

Monitoring the fate of injected CO2 using geodetic techniques

Geodetic methods comprise one class of geophysical data that are sensitive to changes in effective pressure within operating reservoirs, albeit indirectly through induced deformation. Geodetic observations, which have observation intervals that vary from seconds to days, weeks, or months, generally provide more frequent sampling compared to existing geophysical methodologies (such as seismic time-lapse monitoring), which typically invoke repeat times of months to years. These differences in sampling intervals are primarily due to the extensive effort, and hence cost, of conducting geophysical field operations, which often precludes executing a large number of surveys. Satellite-based interferometric synthetic aperture radar (InSAR) is cost effective and used in many applications, including monitoring the injection of carbon dioxide (CO2) for both long-term storage and enhanced oil production. An application to the geologic sequestration of CO2 in Algeria revealed northwest migration along a fault/fracture zone intersected by the injection well. A study in a Texas field demonstrated that enhanced oil recovery utilizing CO2 leads to observable surface deformation that may be used to characterize the sequestered CO2 and to estimate the pressure changes within the reservoir induced by injection and production.