CO2 Sequestration in Saline Formation

Received: June 12, 2013
Revised: September 19, 2013
Accepted: September 19, 2013
Download Citation: RIS|BibTeX|https://doi.org/10.4209/aaqr.2013.06.0195  

Cite this article:
Soong, Y., Howard, B.H., Hedges, S.W., Haljasmaa, I., Warzinski, R.P., Irdi, G. and McLendon, T.R. (2014). CO2 Sequestration in Saline Formation. Aerosol Air Qual. Res. 14: 522-532. https://doi.org/10.4209/aaqr.2013.06.0195

ABSTRACT

Deep saline aquifers are reported to have the largest estimated capacity for CO₂ sequestration. Knowledge of possible geochemically-induced changes to the porosity and permeability of host CO₂ storage sandstone and seal rock will enhance our capability to predict CO₂ storage capacity and long-term reservoir behavior.

An experimental study of the potential interaction of CO₂/brine/rock on saline formations in a static system under CO₂ sequestration conditions was conducted. Chemical interactions in the Mount Simon sandstone environment upon exposure to CO₂ mixed with brine under sequestration conditions were studied. Samples were exposed to the estimated in-situ reaction conditions for six months. The experimental parameters used were two core samples of Mount Simon sandstone; Illinois Basin model brine; temperature of 85°C, pressure of 23.8 MPa (3,500 psig), and CO₂. Micro-CT, CT, XRD, SEM, petrography, and brine, porosity, and permeability analyses were performed before and after the exposure. Preliminary permeability measurements obtained from the sandstone sample showed a significant change after it was exposed to CO₂-saturated brine for six months. This observation suggests that mineral dissolution and mineral precipitation could occur in the host deposit altering its characteristics for CO₂ storage over time.

Keywords: CO2 sequestration; Mount Simon sandstone; Chemical interaction; Permeability; Saline aquifer