Hydroprocessing

Hydroprocessing, including hydrotreating and hydrocracking, accounts for nearly half of a refinery’s capacity. The main difference between them is feed conversion: hydrocracking converts up to 90%, while hydrotreating operates at 0.5–5% to preserve valuable feedstocks like gasoline. Hydroprocessing units face several corrosion risks. High-temperature H₂S/H₂ corrosion affects areas such as feed pre-heaters, reactor effluent systems, and recycle hydrogen streams. Before hydrogen injection, sulfidation can occur. Sour and acidic crude feedstocks increase the risk of naphthenic acid corrosion (NAC), while ammonium chloride and bisulfide corrosion are common in fractionation sections. Chlorides from recycled hydrogen and ammonia/H₂S in post-process streams contribute to these issues. Effective material selection, feed treatment, and corrosion monitoring are crucial for ensuring unit reliability.
#Corrosion Monitoring in Hydroprocessing; #NH₄HS Corrosion; #Sulfidation; #NAP Acid Corrosion; #NH₄Cl Corrosion .