Salt crystallization near the injection well of deep saline aquifers for CO2 geological storage may increase engineering operation costs and pose safety risks in the near-wellbore region, and the mechanisms by which salt crystallization affects CO₂-brine two-phase flow remain unclear. To address these issues, the variation patterns of CO₂ injectivity under different salinity conditions in brine-saturated cores were investigated through laboratory CO₂ core displacement experiments. Results demonstrate that non-uniform salt crystallization occurs during the drying process regardless of salinity. In deionized water and low-salinity brine, the drying effect enhances effective gas permeability. However, higher salinity significantly increases residual water saturation, drying rates, and salt accumulation, leading to a marked reduction in gas injectivity. The core displacement process is characterized by three stages, namely displacement, entrainment, and dissolution flooding, with drying occurring during the displacement and entrainment stages after pore capillary water forms. Furthermore, the pore-scale salt crystallization interface involves a shrinkage and expansion process. The influence of crystallization on gas injectivity depends on the competition between solution shrinkage and crystal expansion; higher salinity promotes crystal expansion, causing more severe gas injectivity loss.