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Several experiences with the use of titanium heat exchangers in refining processes are summarized. These involve distillation column overhead condensers in atmospheric crude distilling units, fluid catalytic cracking units, delayed coking units, and sour water strippers. The causes of problems are discussed. Needs for additional data are highlighted.
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The process used to develop MR0103 is described, followed by a review of the requirements in the standard accompanied by highlights of the differences between MR0103 and the previous and current versions of MR0175.
The main goal of this work is to investigate the corrosiveness of different petroleum fractions distilled from acidic crude oil “A” at 150 to 370oC (302 to 698oF) and to find effective measures for diminishing the corrosiveness of aggressive fractions.
There has been recent interest in the use of hydrogen flux monitoring at high temperatures to evaluate ‘naphthenic acid’ and sulfidic corrosion in high temperature process streams associated with crude distillation units. In this report, we present flux and corrosion data obtained from samples drawn from a refinery process stream.
This paper discusses common amine sources and amine identification methods, the equipment commonly impacted and the steps which can be taken to address the challenge of amine contamination.
Key guidelines and limitations of an overhead simulation-modeling program. Discussed are: data quality, sampling techniques, and interpretation of results wrt field experience. Examples of simulation-model use in two actual field applications.
Corrosion rates for carbon steel piping circuits in a petroleum refinery HF (hydrofluoric) Alkylation unit were examined. The HF acid process environment was one of three types: liquid HF acid, superheated HF acid vapor, or HF acid dissolved in a hydrocarbon phase.
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.
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.
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.
This paper discusses reactors in hydrocarbon service that experienced numerous cracking problems over a 8-year period, where cracks were confined to the welded zones. The material is TP347 stainless steel, welded with E347-16 consumables.
Corrosion under Insulation (CUI) and External Corrosion continue to be a major issue for Petrochemical facilities. Refineries have been investing in a CUI and External Corrosion inspection program. This paper details the methodology for addressing this damage and lessons learned throughout the implementation.