Corrosion in geothermal environment Part 2: Metals and alloys

Nogara, James; Zarrouk, Sadiq J.

doi:10.1016/j.rser.2017.06.091

Cited by 62 publications

(43 citation statements)

References 50 publications

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“…Figure 1, the fluid circulates in a cycle through wells, pipelines, downhole pumps, and heat exchangers. These components are subject to premature deterioration, since they are mostly made of metals and alloys that are exposed to brines at high temperatures [39]. Therefore, deep geothermal energy is not free of technical problems, being that corrosion is a major hazard for the reliable and long-term operation of geothermal power plants [40].…”

Section: Corrosion In Binary Geothermal Power Plantsmentioning

confidence: 99%

Corrosion Behaviour of L80 Steel Grade in Geothermal Power Plants in Switzerland

Vitaller

Angst

Elsener

2019

Metals

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In Switzerland, deep geothermal energy can give a promising contribution to the future energy scenario. However, the expertise in operational issues of deep geothermal power plants is limited, and technical challenges, such as corrosion, are a determining factor for their reliable and long-term operation. In this work, two representative fluids of optimal geothermal conditions in Switzerland were studied. The corrosiveness of the solutions was assessed using two experimental setups that allow investigating the range of temperatures and pressures that apply to the reservoir and power plant conditions. The corrosion behaviour of API L80 steel was analyzed by means of electrochemical measurements (at 100 and 200 • C) and of gravimetric tests (at 100 • C). After the tests, the morphologies and composition of the corrosion products were obtained by scanning electron microscopy (SEM) coupled with energy dispersive X-Ray (EDX) and X-Ray diffraction (XRD). Results show that corrosion rates are significantly high at 100 • C in environments with a chloride concentration of around 600 mg/L and pH around 7. The corrosion products deposited on the metal surface mainly consist of magnetite and/or hematite that might potentially form a protective layer. This study gives a first insight of the potential corrosiveness of geothermal fluids in Switzerland.

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Section: Corrosion In Binary Geothermal Power Plantsmentioning

confidence: 99%

Corrosion Behaviour of L80 Steel Grade in Geothermal Power Plants in Switzerland

Vitaller

Angst

Elsener

2019

Metals

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“…Here, one of the major challenges is the corrosive nature of the geothermal fluid due to its composition based on different ionic species and gases under a wide range of temperatures [3,4,5]. Consequently, the infrastructure of geothermal powerplants may undergo corrosion and scaling when exposed to the geothermal fluid [6,7,8,9]. Therefore, it is necessary to assess the risks encountered during the operation and maintenance of geothermal powerplants to ensure its safety and structural integrity.…”

Section: Introductionmentioning

confidence: 99%

Corrosion of Carbon Steel in Artificial Geothermal Brine: Influence of Carbon Dioxide at 70 °C and 150 °C

2019

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This study focuses on the corrosion mechanism of carbon steel exposed to an artificial geothermal brine influenced by carbon dioxide (CO2) gas. The tested brine simulates a geothermal source in Sibayak, Indonesia, containing 1500 mg/L of Cl−, 20 mg/L of SO42−, and 15 mg/L of HCO3− with pH 4. To reveal the temperature effect on the corrosion behavior of carbon steel, exposure and electrochemical tests were carried out at 70 °C and 150 °C. Surface analysis of corroded specimens showed localized corrosion at both temperatures, despite the formation of corrosion products on the surface. After 7 days at 150 °C, SEM images showed the formation of an adherent, dense, and crystalline FeCO3 layer. Whereas at 70 °C, the corrosion products consisted of chukanovite (Fe2(OH)2CO3) and siderite (FeCO3), which are less dense and less protective than that at 150 °C. Control experiments under Ar-environment were used to investigate the corrosive effect of CO2. Free corrosion potential (Ecorr) and electrochemical impedance spectroscopy (EIS) confirm that at both temperatures, the corrosive effect of CO2 was more significant compared to that measured in the Ar-containing solution. In terms of temperature effect, carbon steel remained active at 70 °C, while at 150 °C, it became passive due to the FeCO3 formation. These results suggest that carbon steel is more susceptible to corrosion at the near ground surface of a geothermal well, whereas at a deeper well with a higher temperature, there is a possible risk of scaling (FeCO3 layer). A longer exposure test at 150 °C with a stagnant solution for 28 days, however, showed the unstable FeCO3 layer and therefore a deeper localized corrosion compared to that of seven-day exposed specimens.

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“…In this study, martensitic steel X20Cr13 was used as a substrate because it is the most affordable Cr-containing steel, often applied as tubing material in both oil and gas, and geothermal environments [40]. Due to their ability to form a passive layer, martensitic 13Cr steels have slightly better corrosion resistance than carbon steel [41]. However, several studies also showed that these steels might be suffering from pitting corrosion.…”

Section: Al 2 O 3 Coatings On X20cr13 Steels For Geothermal Applicationmentioning

confidence: 99%

Study of Al2O3 Sol-Gel Coatings on X20Cr13 in Artificial North German Basin Geothermal Water at 150 °C

et al. 2021

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Al2O3 has been widely used as a coating in industrial applications due to its excellent chemical and thermal resistance. Considering high temperatures and aggressive mediums exist in geothermal systems, Al2O3 can be a potential coating candidate to protect steels in geothermal applications. In this study, γ-Al2O3 was used as a coating on martensitic steels by applying AlOOH sol followed by a heat treatment at 600 °C. To evaluate the coating application process, one-, two-, and three-layer coatings were tested in the artificial North German Basin (NGB), containing 166 g/L Cl−, at 150 °C and 1 MPa for 168 h. To reveal the stability of the Al2O3 coating in NGB solution, three-layer coatings were used in exposure tests for 24, 168, 672, and 1296 h, followed by surface and cross-section characterization. SEM images show that the Al2O3 coating was stable up to 1296 h of exposure, where the outer layer mostly transformed into boehmite AlOOH with needle-like crystals dominating the surface. Closer analysis of cross-sections showed that the interface between each layer was affected in long-term exposure tests, which caused local delamination after 168 h of exposure. In separate experiments, electrochemical impedance spectroscopy (EIS) was performed at 150 °C to evaluate the changes of coatings within the first 24 h. Results showed that the most significant decrease in the impedance is within 6 h, which can be associated with the electrolyte penetration through the coating, followed by the formation of AlOOH. Here, results of both short-term EIS measurements (up to 24 h) and long-term exposure tests (up to 1296 h) are discussed.

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Corrosion in geothermal environment Part 2: Metals and alloys

Cited by 62 publications

References 50 publications

Corrosion Behaviour of L80 Steel Grade in Geothermal Power Plants in Switzerland

Corrosion Behaviour of L80 Steel Grade in Geothermal Power Plants in Switzerland

Corrosion of Carbon Steel in Artificial Geothermal Brine: Influence of Carbon Dioxide at 70 °C and 150 °C

Study of Al2O3 Sol-Gel Coatings on X20Cr13 in Artificial North German Basin Geothermal Water at 150 °C

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