At the same time filter change-outs increase. The filters are plugging with iron hydroxide and iron carbonate. Another DEA user reports the solution clarified upon caustic addition -- it appeared less black.
Here also, the caustic raised the pH and increased the. The reason caustic doesnt appear to help is that it doesnt affect the concentration of HSS anions which are the cause of the corrosion rate acceleration.
The increased corrosion rate destroys equipment faster leading to frequent downtime and repairs. Caustic addition looks like a cheap and easy way to deal with HSS problems in amine systems. However, plant experience shows that caustic addition does little to improve system performance in the long run.
Apparent improvements have counterbalancing negatives which end up making caustic bad for an amine system overall. More effective corrosion control, better overall amine performance, and more complete amine restoration are attained by removing HSS from a contaminated amine system and managing the HSS at low levels thereafter. Mecum, S. Litschewski, M. Cummings, A. Pauley, C. The Authors. His work has led to publications and patents relating to kinetics, thermodynamics, analytical methods, lubricants, sterilants, ion exchange, corrosion, alkanolamines and heat stable salts.
Shade M. He has over 27 years experience in providing services to the oil and gas industry and has held various technical and management positions in Dow Chemical, Dowell Schlumberger, and Schlumberger.
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Search inside document. MPR Services, Inc. In some cases corrosion rates are increased by caustic 1,2 addition, which may lead to additional operating problems. Subsequent removal of HSS and sodium by a patented ion exchange service immediately reduced 2 the corrosion rate.
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In some cases, the solubility of light hydrocarbons and inert gases may be taken into account. Until recently, however, the process effect of organic and inorganic acids that enter amine solutions when tail gas from Claus sulphur plants is treated, or which are almost universally encountered in oil refining operations, has been ignored. A few are acids, both organic and inorganic, that occur in treating solvents at a total concentration that does not typically exceed ten to fifteen thousand parts per million by weight, and is often very much lower than this.
Apart from being blamed for corrosion problems, HSSs can have a profound effect on process performance. Ignoring them or misunderstanding their chemistry can lead to very bad processing decisions, to recommendations to make expensive equipment changes that, in fact, make the process worse than ever, and to continuing to surround a number of modern proprietary solvents with an undeserved mystique.
They can be both friend and foe — how to view them and deal with them in a given circumstance depends on understanding the chemistry, vapour liquid equilibrium constraints, and the mass transfer rate processes taking place in absorption and regeneration columns.
Outside the laboratory, clean solvents exist in many plants for only a short time immediately following initial system charging and startup. In real processes, solutions are always contaminated to some degree.
The work reported here attempts to provide a scientific understanding of HSS chemistry and the effect of these components on the process. Heat Stable Salt Process Chemistry Over time, solvents accumulate contaminants primarily from the gases being treated or through the use of makeup agents water and amine that are not completely pure.
Contaminants of interest here are frequently the anions of organic and inorganic acids, also called heat stable salts HSSs. Anions commonly found in amine solutions include thiosulphate, oxalate, sulphite, sulphate, glycolate, propionate, acetate, thiocyanate, formate, and chloride, which usually enter the solution as a result of absorption from the gases or liquids being treated.
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