Relative Permeability Estimation in CO2 Sequestration Application @ Laboratory-Scale

1.Feasible to assume random distribution of CO2-phase at the desired saturation in order to estimate the (steady-state) relative permeability curve?

2.If significant fraction of the injected CO2 gets distributed into smaller pores, dead-end pores and isolated pores due to the presence of dominant capillary pressures in a real field scenario, would it remain feasible to replicate the same @ lab-scale?

3.If the relative permeability strongly depends on the fluid saturation history at the real field scenario, then, at the laboratory-scale, would it remain feasible to take into account the drainage-imbibition hysteresis, i.e., the saturation history associated with the real field scenario?

4.Whether the laboratory-scale investigations really consider the miscibility of the CO2 into oil and brine, even though, the time-scale for the CO2 dissolution remains to be much larger than the displacement process – in CO2 sequestrated EOR application?

5.How will we get rid-off the spurious oscillations encountered near the interface, which leads to an erroneous calculation of average mass flux of each phase? If average mass flux of each phase fails to converge, how will we obtain relative permeability from the velocity field for the respective saturation – even by using models?

Suresh Kumar Govindarajan

Professor (HAG)

https://home.iitm.ac.in/gskumar/

https://iitm.irins.org/profile/61643

20-Aug-2024