Journal
GEOPHYSICAL RESEARCH LETTERS
Volume 41, Issue 2, Pages 399-406Publisher
AMER GEOPHYSICAL UNION
DOI: 10.1002/2013GL058534
Keywords
Porosity; Permeability; Carbonates; CCS; Dissolution
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Funding
- EPSRC [EP/I010971/1]
- EPSRC [EP/K021869/1, EP/I010971/1] Funding Source: UKRI
- Engineering and Physical Sciences Research Council [EP/I010971/1, EP/K021869/1] Funding Source: researchfish
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Reservoir injectivity and storage capacity are the main constraints for geologic CO2 sequestration, subject to safety and economic considerations. Brine acidification following CO2 dissolution leads to fluid-rock interactions that alter porosity and permeability, thereby affecting reservoir storage capacity and injectivity. Thus, we determined how efficiently CO2-enriched brines could dissolve calcite in sandstone cores and how this affects the petrophysical properties. During computerized tomography monitored flow-through reactor experiments, calcite dissolved at a rate largely determined by the rate of acid supply, even at high flow velocities which would be typical near an injection well. The porosity increase was accompanied by a significant increase in rock permeability, larger than that predicted using classical porosity-permeability models. This chemically driven petrophysical change might be optimized using injection parameters to maximize injectivity and storage. Key Points CO2-saturated brine is effective at dissolving calcite from sandstone Dissolution of isolated calcite grains markedly increases permeability
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