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This paper helps answer some questions by surveying numerous units processing high naphthenic acid-containing feeds, e.g. feeds with high total acid number (TAN). The survey lists the unit temperatures, TAN’s, flow schemes, materials and corrosion history.
Questions of when, where and why hydroprocessing units within oil refineries can see naphthenic acid corrosion are often raised, and to date, there has been little, if any published data to answer these questions. This has resulted in a variety of different metallurgies being chosen, some of which compromise on other desired properties and/or cause costly requalification of fabricators’ procedures. This paper helps answer some questions by surveying numerous units processing high naphthenic acid-containing feeds, e.g. feeds with high total acid number (TAN). The survey lists the unit temperatures, TAN’s, flow schemes, materials and corrosion history. A beneficial effect of hydrogen was shown, as no corrosion has occurred on 300 series SS materials downstream of the hydrogen injection point. Theories for why the hydrogen is beneficial are presented and attempts to prove/disprove various theories by reviewing the chemical reaction dynamics of the corrosion reactions were made. However, the necessary constants were not readily available, and hence, no theory was conclusive enough to explain the benefit. Regardless, the experiential data seems strong enough to use as a basis for setting inspection strategies and selecting new materials.
Key Words: Naphthenic acid, hydroprocessing units, materials selection, hydrogen
The corrosivity of four mercaptans and selected crude oil fractions were measured in lab tests. Conclusion: Mercaptan corrosion can contribute significantly to the total sulfur related corrosion in the temperature range 235–300°C, which agrees with observations of elevated temperature corrosion in refinery distillation equipment.
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The purpose of this paper will be to: (a) review published literature to characterize and classify speciation related to the types of impurities encountered in opportunity crudes; and (b) describe and categorize published case studies of corrosion in crude unit overhead operations.
As a result of a Carbonate Stress Corrosion Cracking (CSCC) event at one refinery an investigation was made into the cause and mitigation of CSCC. This paper outlines the information obtained and the development of tools that could be utilized by other refinery fluidized catalytic cracker units (FCCU's) to better assess risk of CSCC.