Investigating the effect of salt and acid impurities in supercritical CO2 as relevant to the corrosion of carbon capture and storage pipelines

• Published in: International journal of greenhouse gas control 2013-09, Vol.17, p.534-541
• Main Authors: Sim, S., Cole, I.S., Bocher, F., Corrigan, P., Gamage, R.P., Ukwattage, N., Birbilis, N.
• Format: Article
• Language: English
• Subjects: CCS; CO2; Corrosion; Pipeline; Supercritical
• ISSN: 1750-5836; 1878-0148
• DOI: 10.1016/j.ijggc.2013.06.013

•Corrosion rate of salt impurities showed similar results (weight change).•Corrosion product of each test solution is different.•Compared to aqueous modelling, supercritical CO2 showed increased corrosion rates.•SEM results show little difference in scale and surface morphology of all samples.•Optical profilometry showed an increase in pit density when exposed to HNO3. A series of corrosion exposure tests were performed in a supercritical CO2 environment used to represent the potential conditions for carbon capture and storage (CCS) pipelines. Impurities from various CO2 capture processes are potentially present, which segregate to the aqueous phase, hence combining with any free water present in the pipeline. Herein, salt (NaNO3, Na2SO4, NaCl) and acid (HNO3) impurities were added, along with 10g of water, to an autoclave at 7.6MPa and 50°C (supercritical CO2) for a 7 day steel specimen exposure. The tests conducted in supercritical CO2 were also compared with aqueous tests in atmospheric conditions. Weight loss and optical profilometry revealed that corrosion rates for all samples are significant, along with the potential for localised attack. The corrosion mechanism differs for each solution tested. The work herein contributes to a holistic appraisal of understanding the corrosion of CO2 pipelines.