Pipeline plays an important role in oil and gas transmission. With the increase of gas field exploitation time, the content of H2S and water in the transmission medium increases, intensifying pipeline corrosion and creating significant safety hazards. Current studies on hydrogen sulfide corrosion predominantly concentrate on the influence of H2S concentration on corrosion rate and corrosion products, whereas research addressing the correlation between variations in hydrogen sulfide content and crack propagation is relatively scarce. Through physicochemical analysis, non-destructive testing, stress evaluation, hydrogen-induced cracking (HIC), and stress corrosion cracking (SSC) experiments, this study explores crack initiation and propagation patterns under different corrosion conditions. The factors influencing crack formation and development were systematically analyzed. The results show that the high sulfur wet gas medium is corrosive, the corrosion rate of the pipeline is large, and the pipeline has the ability to resist HIC. In the existing high sulfur wet gas environment, with the extension of time, pipeline defects will first occur due to stress corrosion. As the hydrogen sulfide content continues to rise, the probability of stress corrosion producing cracks and crack production rate will increase, or even fracture. The larger the defect, the more obvious the crack production and fracture, and the greater the risk of failure of the pipeline at the defect. Through the evaluation study on the safety operation of an in-service high-sulfur wet gas pipeline, it was possible to achieve early warning and timely risk control measures to achieve safe and smooth operation of the pipeline.