The evolution and characterisation of the corrosion scales formed on 3Cr steel in CO2-containing conditions relevant to geothermal energy production

Hua, Yong; Yue, Xiaoqi; Liu, Huifeng; Zhang, Xiaochen; Wen, Zezhou; Wang, Yongxing; Zhang, Tao; Zhang, Lei; Sun, Jianbo; Neville, Anne

doi:10.1016/j.corsci.2021.109342

Cited by 24 publications

(10 citation statements)

References 19 publications

(30 reference statements)

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“…(1) Temperature Table1 reaveled that the actual operating temperature(68.9°C) was far more than the design value(26°C). Some research findings [14][15][16][17] showed that in a certain temperatue range, the corrosion rate of carbon steel in CO 2 +water environment would increased with the rising of temperature, usually from room temperature to 90°C, and the increasing extent depend on temperature interval, when reaching a certain temperature(usually at 60°C), the corrosion rate will increase significantly. So the high actual operating temperature definitly has big influence on the accerlation of the corrosion process.…”

Section: Inner Wall Corrosion Causementioning

confidence: 99%

Corrosion Cause Analysis of a Surface Pipeline Flange

Li²,

Wang

et al. 2023

J. Phys.: Conf. Ser.

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Corrosion was found on the inner wall and sealing groove end face of a surface pipeline flange in an oilfield in western China after one year’s service. Corrosion causes were investigated by physical and chemical property tests, metallographic examination, scanning electron microscope, scanning electron microscopy(SEM) inspection, energy disperse spectroscopy(EDS) analysis and X-ray diffraction(XRD) analysis. The results showed that the chemical composition and mechanical properties of the flange were all in accordance with the corresponding parameter requirements, and the corrosion phenomenon was mainly attributed to CO2 corrosion. High temperature and high medium flow rate also had a big influence on the acceleration of the corrosion process. Corrosion of the sealing groove end face was attributed to galvanic corrosion, the corrosion potential difference between the flange and gasket was the main reason for the galvanic corrosion.

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Section: Inner Wall Corrosion Causementioning

confidence: 99%

Corrosion Cause Analysis of a Surface Pipeline Flange

Li²,

Wang

et al. 2023

J. Phys.: Conf. Ser.

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“…[36] HTHP weight loss measurements generally last for several days (test duration lasting between the time the temperature is reached and the start of cooling [74] ), although shorter-term experiments were reported as well. [75,76] After dipping, the samples are taken out, cleaned to remove corrosion products, and weighed to calculate the corrosion rate. The samples may be held using a polytetrafluoroethylene (PTFE) cord or a glass holder, [63] or just mounted on a PTFE bar with minimal contact to avoid crevice corrosion.…”

Section: Hthp Weight Loss Measurements-experimental Protocolmentioning

confidence: 99%

“…Interestingly, they were also able to evaluate the localized corrosion rate by performing profilometry measurements on the sample's deepest pits. [76] It is also possible to perform electrochemical measurements at low temperature after HTHP exposure of the material: EIS measurements were reported on coated steels after exposure of 570 h at 130°C and 3-4 MPa. [79] However, it is preferable to directly conduct the electrochemical measurements during HTHP exposure.…”

Section: Hthp Weight Loss Measurements-experimental Protocolmentioning

confidence: 99%

“…Through XPS and SEM analysis, Poulain et al [78] were able to identify a mixture of calcium carbonate and iron carbonate as corrosion products on carbon steel surface after 500 h in Upper Rhine Graben type brines saturated in carbon dioxide at 200°C, 20 MPa. Neville's group [74,76] recently found using various characterization techniques that the deposit on 13Cr stainless steel is dependent on both partial pressure of carbon dioxide and exposure time after immersion in brine containing carbon dioxide at 200°C. During the first hours before iron carbonate formation, amorphous chromium hydroxide is dominant for high carbon dioxide pressure, while nanocrystalline chromite is detected for lower pressures.…”

Section: Hthp Weight Loss Measurements-experimental Protocolmentioning

confidence: 99%

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Monitoring and mitigating corrosion in geothermal systems

Schott

Liautaud

2022

Materials & Corrosion

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In terms of current needs for renewable resources, geothermal energy is one of the future solutions for heat and electricity generation. However, geothermal plants are exposed to very aggressive media (high-temperature [HT], salt-rich fluid, etc.), leading to extensive corrosion of the metallic parts. Should the corrosion inhibitors work at HT, their injection would be mandatory to ensure the reasonable lifetime of geothermal plants. The first part of this review concerns the degradations observed in geothermal plants, which depend on the site properties and the methods for evaluating the corrosion intensity of such systems. Autoclave experiments, although rarely used for geothermal applications, maybe the most appropriate to measure the representative corrosion rate, that is, under use temperature and pressure conditions. In the second part, clues to evaluate the performance and mechanism of corrosion inhibitors are mentioned, and molecules already used to protect steel are reported. However, this review also highlights the lack of data on HT inhibitors, especially for geothermal applications, where the efficiency of a given molecule is strongly related to the real medium. Thus, the protection of new geothermal plants where HT is reached requires the search for products that are stable and efficient under such conditions.Using the heat derived from the Earth's core, geothermal energy constitutes a renewable solution for future energy. It is already widely used worldwide, especially in Europe with several sites in Iceland and in the Dogger aquifer, Paris basin. Additional sites were recently identified, for example, in Upper Rhine Graben, where the composition of the media and use temperatures may differ from the already established plants.However, due to the aggressiveness of geothermal fluids, one major issue is the reduced lifetime of geothermal plants. Indeed, the steel tubes of such | © 2022 Wiley-VCH GmbH.

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“…A high FeCO 3 supersaturation is a necessary condition for the sufficient deposition on steel surface. When S > S c (critical supersaturation), a large amount of the crystal will nucleate, and therefore the higher S c will lead to the higher nucleation rate of FeCO 3 [15,43].…”

Section: Influence Of Silty Sand On the Structure Of Corrosion Filmmentioning

confidence: 99%

Effects of silty sand and pH on the formation of corrosion film and corrosion behaviour of low-Cr steel in the CO₂ environment

Zhao

Liu

Chen

et al. 2022

Corrosion Engineering, Science and Technology

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The effects of silty sand and pH on the corrosion characteristics of 1Cr steel were investigated. The results revealed that silty sand changed the nucleation behaviour of FeCO 3 crystal from homogeneous nucleation to heterogeneous nucleation through increasing the critical supersaturation of FeCO 3 . The compactness and protection of corrosion film were improved by silty sand. The amorphous FeCO 3 content decreased as the pH increased in the CO 2 environment with silty sand, while the Cr(OH) 3 content increased. The critical pH for the good corrosion resistance of 1Cr steel was 4.5. The amorphous FeCO 3 dominated the protective properties of corrosion film when the pH was lower than the critical pH, whereas the Cr(OH) 3 was predominant when the pH was higher than the critical pH. Therefore, the corrosion resistance of 1Cr steel was reduced and then enhanced with increasing pH under silty sand condition.

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The evolution and characterisation of the corrosion scales formed on 3Cr steel in CO2-containing conditions relevant to geothermal energy production

Cited by 24 publications

References 19 publications

Corrosion Cause Analysis of a Surface Pipeline Flange

Corrosion Cause Analysis of a Surface Pipeline Flange

Monitoring and mitigating corrosion in geothermal systems

Effects of silty sand and pH on the formation of corrosion film and corrosion behaviour of low-Cr steel in the CO₂ environment

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The evolution and characterisation of the corrosion scales formed on 3Cr steel in CO2-containing conditions relevant to geothermal energy production

Cited by 24 publications

References 19 publications

Corrosion Cause Analysis of a Surface Pipeline Flange

Corrosion Cause Analysis of a Surface Pipeline Flange

Monitoring and mitigating corrosion in geothermal systems

Effects of silty sand and pH on the formation of corrosion film and corrosion behaviour of low-Cr steel in the CO2 environment

Contact Info

Product

Resources

About

Effects of silty sand and pH on the formation of corrosion film and corrosion behaviour of low-Cr steel in the CO₂ environment