Corrosion-mechanical properties and susceptibility to hydrogenation of pipe steel in the presence of carbon oxide and hydrogen sulphide in environment

Keywords

pipe steels, carbon dioxide, hydrogen sulfide, corrosion, hydrogenation, mecha­nical properties, microstructure.

Cite as

Khoma M. S., Pokhmurskii V. I., Chuchman M. R., Vasyliv Kh. B., Ivashkiv V. R., and Ratska N. B. Corrosion-mechanical properties and susceptibility to hydrogenation of pipe steel in the presence of carbon oxide and hydrogen sulphide in environment. Physicochemical Mechanics of Materials. 2023. 59(2), 80-87.

https://doi.org/10.15407/pcmm2023.02.080

Abstract

The effect of different concentrations of CO₂ and H₂S in a chloride-acetate solution on the corrosion-mechanical properties of 17Г1С-У steel is studied. In a solution saturated with CO₂, the corrosion rate of steel is lower than in the presence of H₂S, but increases over time due to the absence of protective carbonate films on the surface, plasticity para­meters are 2–2.7 times lower than in air, due to ulcerated surface damage. The corrosion rate and hydrogenation of steel is determined primarily by the hydrogen sulfide concen­tration in the environment. At a concentration of 100 mg/dm³, dense films of the troilite-mackinavite composition are formed, which inhibit corrosion. At higher concentrations, the corrosion rate increases due to the sulfides transformation and the formation of surface layers with defects. With an increase in the H₂S concentration from 100 mg/dm³, the strength characteristics of steel decrease in three, and plasticity by 3–5 times.

References

1. P. Sui, J. Sun, Y. Hua, H. Liu, M. Zhou, Y. Zhang, J. Liu, and Y. Wang, “Effect of temperature and pressure on corrosion behavior of X65 carbon steel in water-saturated CO2 transport environments mixed with H2S,” Int. J. of Greenhouse Gas Control, 73, 60-69 (2018). https://doi.org/10.1016/j.ijggc.2018.04.003
2. C. Ren, D. Liu, Z. Bai, and T. Li, “Corrosion behavior of oil sulfide in simulant solution with hydrogen sulfide and carbon dioxide,” Mater. Chemistry and Physics, 93, Iss. 2-3, 305-309 (2005). https://doi.org/10.1016/j.matchemphys.2005.03.010
3. X. H. Zhao, Y. Feng, S. Tang, and J. Zhang, “Electrochemical corrosion behavior of 15Cr-6Ni-2Mo stainless steel with/without stress under the coexistence of CO2 and H2S,” Int. J. Electrochem. Sci., 13, Is. 7, 6296-6309 (2018). https://doi.org/10.20964/2018.07.59
4. M. Khoma, V. Vynar, M. Chuchman, and C. Vasyliv, “Corrosion-mechanical failure of pipe steels in hydrogen sulfide environments,” in: Degradation Assessment and Failure Prevention of Pipeline Systems, Springer, Cham (2021), pp. 231-239. https://doi.org/10.1007/978-3-030-58073-5_18
5. M. S. Khoma, S. A. Korniy, V. A. Vynar, B. M. Datsko, Yu. Ya. Maksishko, O. V. Dykha, and R. L. Bukliv, “Influence of hydrogen sulfide on the carbon-dioxide corrosion and the mechanical characteristics of high-strength pipe steel,” Mater. Sci., 57, No. 6, 805-812 (2022). https://doi.org/10.1007/s11003-022-00610-0
6. M. M. Ivaniuta (Ed.), Atlas of Oil and Gas Deposits of Ukraine: in 6 volumes [in Ukrainian], Tsentr Yevropy, Lviv (1998). ISBN 966-7022-04-8.
7. C. Plennevaux, J. Kittel, M. Frégonèse, B. Normand, F. Ropital, F. Grosjean, and T. Cassagne, “Contribution of CO2 on hydrogen evolution and hydrogen permeation in low alloy steels exposed to H2S environment,” Electrochem. Communic., 26, Is. 1, 17-20 (2013). https://doi.org/10.1016/j.elecom.2012.10.010
8. G. A. Zhang, Y. Zeng, X. P. Guo, F. Jiang, D. Y. Shi, and Z. Y. Chen, “Electrochemical corrosion behavior of carbon steel under dynamic high pressure H2S/CO2 environment,” Corros. Sci., 65, 37-47 (2012). https://doi.org/10.1016/j.corsci.2012.08.007
9. W. Sun, S. Nesic, and S. Papavinasam, “Kinetics of iron sulfide and mixed iron sulfide/carbonate scale precipitation in CO2/H2S corrosion,” NACE – Int. Corrosion Conference Series, 06644\1-06644\26 (2006). https://doi.org/10.5006/C2006-06644
10. X. Wen, P. Bai, B. Luo, S. Zheng, and C. Chen, “Review of recent progress in the study of corrosion products of steels in a hydrogen sulphide environment,” Corros. Sci., 139, 124-140 (2018). https://doi.org/10.1016/j.corsci.2018.05.002
11. NACE Standard SP0110-2010, Wet Gas Internal Corrosion Direct Assessment Methodology for Pipelines, NACE, Houston, TX (2010).
12. M. Khoma, V. Vynar, C. Vasyliv, M. Chuchman, B. Datsko, V. Ivashkiv, and O. Dykha, “Tribo-corrosion of 17Mn1Si steel in chloride-acetate environments at the different concentrations of hydrogen sulfide,” J. of Bio- and Tribo-Corrosion, 8, Is. 2, art. no. 53 (2022). https://doi.org/10.1007/s40735-022-00655-3
13. M. S. Khoma, V. R. Ivashkiv, N. B. Ratska, B. M. Datsko, and M. R. Chuchman, “Corrosion-electrochemical properties of 17G1SU steel in chloride-acetate solutions with different concentrations of hydrogen sulfide,” Mater. Sci., 56, No. 4, 544-549 (2021). https://doi.org/10.1007/s11003-021-00462-0
14. M. S. Khoma, S. A. Holovei, V. R. Ivashkiv, and Kh. B. Vasyliv, “Effect of sulfides on the hydrogen overvoltage and hydrogenation of U8 steel in chloride-hydrogen-sulfide media,” Mater. Sci., 53, No. 6, 761-768 (2018). https://doi.org/10.1007/s11003-018-0133-z
15. S. K. Dwivedi, and M. Vishwakarma, “Hydrogen embrittlement in different materials: A review,” Int. J. of Hydrogen Energy, 43, Is. 46, 21603-21616 (2018). https://doi.org/10.1016/j.ijhydene.2018.09.201