Deep saline aquifers provide unbeatable capacities for long term CO2
storage, provided CO2
does not leak. Upon CO2
injection the pressure in the aquifer increases and induces stresses in the caprock. If CO2
is injected at the temperature different from the ambient temperature in the aquifer, there could appear thermal stresses also. We study the effect of CO2
injection temperature on the caprock integrity. Using coupled thermo-poromechanical multi-phase simulations , we reveal that thermal expansion of the rock significantly enhances the stresses developing as a result of the fluid pressure buildup. Calculations show that when CO2
is injected at a temperature below the ambient value, the stresses in the caprock above the horizontal injection well become tensile and even exceed the tensile strength after several years of continuous injection . These stresses lead to the caprock fracturing. Once the fractures form, they start to propagate because of the high pressure in the reservoir and may serve as pathways for CO2
leakage. Based on the results of our simulations using the method from  we estimate the rate of fracture propagation. We show that this rate is strongly affected by the value of the permeability in the caprock. Finally, our results show that injection of CO2
at temperature close to the ambient value in the aquifer significantly reduces the risk of caprock fracturing and, therefore, possible leakage.
1. Preisig, M. and Prevost, J.H. Coupled multi-phase thermo-poromechanical effects. Case study: CO2 injection at In Salah, Algeria, International Journal of Greenhouse Gas Control, 5, 1055-1064 (2011).
2. Gor, G. Y. and Prevost, J.H. Effects of thermal stresses on caprock integrity during CO2 storage, International Journal of Greenhouse Gas Control (submitted)
3. Gor, G.Y., Stone, H.A., Prevost, J.H. Fracture propagation driven by fluid outflow from a low-permeability reservoir, Journal of the Mechanics and Physics of Solids (submitted) http://arxiv.org/pdf/1203.4543