This work aims to explore the overflow characteristics of a vertical H₂S‐containing natural gas well. A two‐phase flow model for H₂S‐containing natural gas well combining with a transient temperature prediction model was established to simulate the overflow process of a vertical H₂S‐containing natural gas well. The model was validated by reproducing the field data of Well Longhui #2. The effects of H₂S content, mud displacement, drilling fluid density, geothermal gradient, and reservoir permeability on the overflow characteristics of a vertical H₂S‐containing natural gas well were studied and analyzed in this work. Results indicate that bubble, slug, and churn flows constitute the main flow patterns in the whole overflow process. The higher the H₂S content is, the more obviously the gas void fraction increases. The phase change position of H₂S is closer to the wellhead at lower H₂S content. An increase in mud displacement indicates the decreases in overflow time. As drilling fluid density increases, the release position of H₂S moves up, and the overflow time and shut‐in casing pressure increase. The initial gas void fraction is higher and the gas invasion volume will be larger in gas reservoirs with higher permeability. As the reservoir permeability increases, the shut‐in casing pressure rises while the overflow time declines. With higher geothermal gradient, the wellbore temperature tends to be higher at the same depth, leading to an increase in the H₂S solubility. The gasification starting position is further away from the wellhead at higher geothermal gradient. The results of this work could provide important theoretical basis and technical guidance for drilling engineers to reduce a blowout risk during drilling of H₂S‐containing natural gas well.