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Corrosion of CO 2 transport and injection pipeline steels due to the condensation effects caused by SO 2 and NO 2 impurities
Author(s) -
Yevtushenko O.,
Bettge D.,
Bäßler R.,
Bohraus S.
Publication year - 2015
Publication title -
materials and corrosion
Language(s) - English
Resource type - Journals
SCImago Journal Rank - 0.487
H-Index - 55
eISSN - 1521-4176
pISSN - 0947-5117
DOI - 10.1002/maco.201307368
Subject(s) - corrosion , condensation , impurity , alloy , pipeline transport , materials science , carbon capture and storage (timeline) , pipeline (software) , carbon steel , electrochemistry , metallurgy , carbon fibers , chemical engineering , environmental science , chemistry , environmental engineering , composite material , electrode , organic chemistry , meteorology , geology , physics , computer science , programming language , oceanography , composite number , engineering , climate change
Condensates from the gas stream in simulated CO 2 transport pipelines have been identified during the experiments in the laboratory. Because of their acidic origin the corrosion resistance of pipeline steels used for CCS (carbon capture and storage) technology might be limited. Over the last years it has become clear that the amount of water and acid building constituents in the CO 2 stream has to be controlled very well. In this work, condensates formed in experiments using gaseous CO 2 containing high amounts of water, NO 2 and SO 2 were analyzed, replicated, and used for extensive electrochemical experiments. These highly acidic condensates were enriched with CO 2 and then applied to characteristic steels planned to use in the CCS transport chain. Even high alloy steels are susceptible to localized corrosion under these conditions. The results implicate that condensation of aggressive acid droplets has to be avoided or the locations where condensation takes place have to be controlled extensively.