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Using supercritical CO2 (sCO2) as a working fluid is being explored for a number of power generation technologies including fossil, nuclear, geothermal, concentrating solar power (CSP) and waste heat recovery1-7. The various sCO2 cycles are attractive because of the low critical point (31°C/73.8 bar) and the reduced work of compression compared to an ideal gas. While CO2 is sometimes described as inert, there is a long history of component degradation in subcritical and supercritical CO2 and a particular concern about internal carburization8-16.
Direct-fired supercritical CO2 (sCO2) power cycles are being commercialized to revolutionize the use of fossil fuels as a low-emission power source. However, the cycle will increase O2 and H2O in the sCO2 and the implications of these additions have not been fully studied, particularly for lower cost steels that are needed in the lower temperature segments of the plant. Representative 9 and 12%Cr ferriticmartensitic (FM) steels and conventional and advanced austenitic steels were evaluated at 450-650°C in sCO2 with 1%O2 and 0.1%H2O at 300 bar to determine their maximum use temperatures. Compared to research grade (low impurity) sCO2 in indirect-fired cycles, the mass gains and scale thickness were not significantly changed for FM steels: both formed thick duplex Fe-rich scales with and without impurities. For austenitic steels, higher mass gains were observed at all temperatures with increased Fe-rich oxide nodule formation. After 1000 h at 650°C, the measured bulk C content was high for all of the steels with the addition of impurities suggesting a lower maximum operating temperature for steels. The impact of the environment on the post-exposure room temperature tensile properties was also evaluated and compared to 1000 h Ar anneals.
Geothermal Energy is currently engineered as an “always on” baseload supply, due to the limited flexibility to throttle the well without scaling and fatigue issues, and it is engineered for maximal efficiency at this output level. Scaling is a major problem in geothermal plants, particularly in cases where the geothermal fluid composition and plant operation make it difficult to control scaling. In such areas, particularly where scale inhibitors cannot be employed, the formation of scales can make the process less efficient and in extreme cases can lead to unexpected shutdown.
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In oil refineries, one corrosion issue occurs each week worldwide that leads to a severe incident such as sudden leakages, e.g., resulting from pipe ruptures.[1] These facts emphasize the need for corrosion control in refineries. Corrosion monitoring is one important approach to utilize and can maximize equipment integrity and productivity.
Corrosion is one of the major issues in oil and gas production, as well as geothermal energy due to the aggressive environments, such as high temperatures and pressures.1, 2 Material selection for downhole tubing is therefore paramount importance to ensure well integrity. Thus, the selected materials must be corrosion resistant, cost-effective, reliable, and have the required strength for such arduous conditions.