CO2 Sequestration
If the reservoir heterogeneity results from a geological unit having multiple layers of geological stratification (within the given depth of the reservoir) leading to a huge variation in local pore-geometry and porosity of the aquifer/reservoir, can we still approximate the pressure within the buoyant CO2 plume to remain to be nearly hydrostatic, just because we have the huge variations in permeability between permeable reservoir unit and the nearly impermeable cap-rock (at least in the absence of CO2 leakage)?
With significant CO2 leakage, whether, hydrostatic assumption remains to be too simplified?
Suresh Kumar Govindarajan
Professor (HAG) IIT-Madras
https://home.iitm.ac.in/gskumar/
https://iitm.irins.org/profile/61643
26-July-2024
My opinion is that as long as the reservoir pressure at the wellbore remains below hydrostatic, the pressure in the plume area should be less. Increases in the plume area should result a corresponding increase at the wellbore as it indicates CO2 can't be dissipated fast enough and the injection rate is too high. However, I think the bigger variable will always be the unknown local faulting within the predicted area of the plume that has the potential to be activated, either resulting in an earthquake and/or a leak path developing. We have seen the unanticipated activation of faults and resulting seismicity effects in multiple areas having significant saltwater injection activities. And that that despite significant geological and modeling studies of those areas prior to initiating the disposal activities.
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