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Corrosion Behavior of Gas Storage Well Pipe Strings in Corrosive H2S–CO2 Environment

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Abstract

The influence of temperature, CO2 and H2S partial pressure on the corrosion behavior of J55, N80, and L80 carbon steels was investigated using immersion tests, scanning electron microscopy, x-ray diffraction, and E–pH diagrams. The corrosion rates of J55, N80, and L80 were 0.05–0.65 mm/a under working conditions of 20–40 °C, 0.21–0.63MPa CO2 partial pressure, and 0.5–5kPa H2S partial pressure. The corrosion rate increased with increases in temperature and in CO2 partial pressure. The corrosion rate at 40 °C decreased as PCO2/PH2S increased. The corrosion data at 20 °C were scattered, but the corrosion rate approximately followed an upward trend as the ratio of CO2 to H2S partial pressure (PCO2/PH2S) increased. The primary corrosion product was mackinawite, and the corrosion scale was loose, flocculent, or cracked; thus, the protection offered by the corrosion scale was poor.

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  1. Research Institute of Production Engineering, Petro China Daqing Oilfield Company, Daqing, China

    Wenhai Ma

  2. Heilongjiang Provincial Key Laboratory of Oil and Gas Reservoir Stimulation, Daqing, China

    Wenhai Ma

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  1. Wenhai Ma
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Ma, W. Corrosion Behavior of Gas Storage Well Pipe Strings in Corrosive H2S–CO2 Environment. J Fail. Anal. and Preven. 22, 368–376 (2022). https://doi.org/10.1007/s11668-021-01311-7

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  • DOI: https://doi.org/10.1007/s11668-021-01311-7

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