Physical and chemical alterations in engineered cementitious composite under geologic CO2 storage conditions

Adeoye, Jubilee T.; Beversluis, Cameron; Murphy, Alessandra; Li, Victor C.; Ellis, Brian R.

doi:10.1016/j.ijggc.2019.01.025

Cited by 11 publications

(1 citation statement)

References 47 publications

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“…In contrast, the reaction solution and solid phases in a batch reactor are in a closed system with evolving chemical compositions. Batch systems that focus on diffusion gradients and the resulting mineral alteration in a rock matrix are used to investigate important mineral replacement reactions, such as those found in wellbore cement alteration, − CO 2 mineralization during geologic sequestration, , and shale matrix alteration reported in recent studies. ,,, Reactive transport models with evolving fluid–rock interfaces can be addressed using pore scale models, but these models tend to be computationally expensive, and thus, an intermediate-scale and computationally efficient continuum approach provides an alternative. Although models for the batch reactive transport systems at continuum-scale exist, the efficiency of these models can be improved in dealing with fluid–solid interfaces to minimize numerical artifacts, − especially if the rock has low porosity.…”

Section: Introductionmentioning

confidence: 99%

Reactive Transport Modeling of Shale–Fluid Interactions after Imbibition of Fracturing Fluids

Jew

Brown

et al. 2020

Energy Fuels

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Injection of hydraulic fracturing fluid (HFF) into shale formations for unconventional oil/gas production results in chemical reactions in the shale matrix. Our recent experimental study determined the depths to which different types of reactions between the shale matrix and the HFF extended. In the present study, we built continuum-scale reactive transport models to understand the coupling of chemical reactions and the transport of aqueous species in these shale–HFF systems. Calibration of the model with our previous experimental results reveals that it takes hours to months for the shale matrix to completely neutralize the imbibed acids, depending primarily upon the carbonate content of the shale. Both the HFF pH and pore pH affect the location of barite precipitation, resulting in unique barite precipitation profiles extending millimeters into calcite-rich Eagle Ford shale but only tens of micrometers into low-carbonate Marcellus shale. In addition, dissolved oxygen and extracted bitumen are key to reproducing the experimental observation of Fe(III) (oxyhydr)oxide formation in the shale matrix as a result of pyrite dissolution in the shales. A comparison between the modeling results of porosity in the present study to experimentally measured permeabilities in our previous study suggests that chemical reactions occurring at a greater depth than the observable reaction zone might have impacted permeability. Our model serves as a benchmark for efficiently modeling water–rock interactions in similar systems where bulk rock samples react with a solution in batch reactors. Important reactive transport processes were ascertained via modeling, which allows for quantitative prediction of shale–HFF interactions in shale matrices given the shale and HFF compositions.

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