Evaluation of corrosion of materials for application in geothermal systems in Central Europe

Iberl, Peter; Alt, Nicolas S. A.; Schluecker, Eberhard

doi:10.1002/maco.201407864

Cited by 13 publications

(15 citation statements)

References 30 publications

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“…This result is in agreement with previous studies and confirms the presence of oxygen to be the main cause of corrosion rate increase [9,31,32]. In the geothermal water medium, 30 ppb of oxygen causes up to four times increase of corrosion rate on carbon steel, while the presence of oxygen with concentrations higher than 50 ppb causes serious pitting corrosion [32,33]. Although dissolved oxygen decreases with the increase of temperature, there is a possibility that oxygen traces intrude to a certain depth of a geothermal well and cause corrosion [3,34,35].…”

Section: Resultssupporting

confidence: 92%

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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Section: Resultssupporting

confidence: 92%

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

2019

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“…The development of this technology, however, faces relevant challenges: (i) accessibility (namely, drilling) [13][14][15][16]; (ii) reservoir creation (namely, hydraulic fracturing and triggered seismicity) [17][18][19]; and (iii) long-term durability (namely, materials degradation due to corrosion and scaling) [20][21][22][23]. In this regard, the choice of corrosion-resistant, yet economically affordable materials is crucial to maintain the facilities in service, assuming a plant's lifetime of 30 years [24,25]. This selection is based on aspects that concern the knowledge of physical and chemical properties of deep geothermal fluids and their long-term interaction with metallic components [26].…”

Section: Introductionmentioning

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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“…Microbially induced (mediated) corrosion, MIC [36], and fouling affect geothermal energy projects (as well as other industrial activities); designing and implementing protection requires multiple knowledge perspectives-material science and metallurgy, electrochemistry, biochemistry, and microbiology [37]. Salas et al [38] showed MIC's impact on the deterioration of geothermal power plant structures (e.g., vapor ducts and cooling tower supports), noting bacterial activity at temperatures as high as 140 • C. A MIC problem in the primary surface loop may migrate to the subsurface as corrosion products, and temperature changes impact the reservoir's chemical conditions and change the system's flow properties [39]. Tubular goods may experience general (e.g., steel thinning) or localized corrosion (e.g., pitting) [40].…”

Section: Reservoir Conditionmentioning

confidence: 99%

Well-Doublets: A First-Order Assessment of Geothermal SedHeat Systems

Mahbaz

Yaghoubi

Sarvaramini³

et al. 2021

Applied Sciences

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Renewable and sustainable energy sources can play an important role in meeting the world’s energy needs and also in addressing environmental challenges such as global warming and climate change. Geothermal well-doublet systems can produce both electrical and thermal energy through extracting heat from hot-water aquifers. In this paper, we examine some potential challenges associated with the operation of well-doublet systems, including heat conductivity, chemical, and mechanical issues. In these systems, geomechanics issues such as thermal short-circuiting and induced seismicity arise from temperature and pressure change impacts on the stress state in stiff rocks and fluid flow in fractured rock masses. Coupled chemical processes also can cause fluid channeling or formation and tubular goods plugging (scaling) with precipitates. Mechanical and chemical disequilibrium conditions lead to increased production uncertainties; hence risk, and therefore coupled geo-risk assessments and optimization analyses are needed for comparative commercialization evaluations among different sites. The challenges related to heat transfer processes are also examined. These studies can help better understand the issues that may arise during the operation of geothermal well-doublet systems and improve their effectiveness, subsequently reducing associated costs and risks.

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Evaluation of corrosion of materials for application in geothermal systems in Central Europe

Cited by 13 publications

References 30 publications

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

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

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

Well-Doublets: A First-Order Assessment of Geothermal SedHeat Systems

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