Effect of Different H2S and CO2 Concentrations on Corrosion of Mild Steel at Elevated Temperatures (120-160 °C) (C2026-00019)
Wednesday, March 18, 2026
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Zhuldyz Zhigulina, Bruce Brown, David Young, Marc Singer, Srdjan Nesic
Both H2S and CO2, ubiquitous in hydrocarbon production and processing, can severely compromise asset integrity. While both are corrosive, H2S-containing environments tend to be more aggressive, causing faster and more severe corrosion than CO2—especially in high-temperature oil and gas systems. Research on H2S corrosion at elevated temperatures has been limited, leading to an incomplete understanding of the mechanisms behind observed phenomena. As a result, corrosion in the presence of H2S remains a key concern for the oil and gas industry. This experimental work aimed to examine the effects of varying CO2 and H2S concentrations and the impact of high temperatures. Data for autoclave experiments conducted at pHinitial5.0, 0.00385-0.0385 M [H2S]aq (1.6-20% H2S), 0.009-0.093 M [CO2]aq contrasting corrosion product layers at 120 and 160 ℃ are reported. The corrosion specimens were machined from X65 steel. Experimental results demonstrate that corrosion rates at 120 and 160 °C and different concentrations of CO2 and H2S were essentially the same, within error, with a combination of various iron sulfides (pyrrhotite, mackinawite, pyrite, troilite) and magnetite found as corrosion products. Also, localized corrosion appeared on samples in select cases.
