We investigate the consequences of formation dry-out due to the injection of under-saturated supercritical acid gas/CO₂ into a Middle Eastern dolomite formation for enhanced oil recovery (EOR) and acid gas (AG)/CO₂ disposal purposes. We perform core flood experiments and numerical simulations with the aim to highlight two aspects. Firstly, the risk assessment of injectivity loss associated with the precipitation of salt in the vicinity of an injection well for the respective EOR operation. Secondly, the rock matrix of the formation differs substantially from the simple sandstone of a previous study. The comparison of both rock types gives insight in the qualitatively different impact of salt precipitation on permeability/injectivity in a multi-porosity and a single porosity system, respectively.