Vanadium-Containing Oil Ash Corrosion of Boilers Under Oxidizing and Syngas Atmospheres

Montero, X.; Galetz, Mathias C.

doi:10.1007/s11085-015-9527-6

Cited by 13 publications

(2 citation statements)

References 33 publications

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“…The application of these statistics to hot corrosion metal losses are also illustrated in ISO standards . More recently, this statistical approach to corrosion degradation has been used in a range of environments, for example, .…”

Section: Methodsmentioning

confidence: 99%

“…The application of these statistics to hot corrosion metal losses are also illustrated in ISO standards [22,26,27]. More recently, this statistical approach to corrosion degradation has been used in a range of environments, for example, [28,29]. Post-exposure, samples were imaged by a scanning electron microscope (SEM) equipped with energy dispersive X-ray spectroscopy (EDX) to study the microstructural evolution.…”

Section: Image Analysis Techniquementioning

confidence: 99%

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Modeling gas turbine materials’ hot corrosion degradation in combustion environments from H₂‐rich syngas

Sumner

Potter

Simms

et al. 2016

Materials & Corrosion

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Components of gas turbines (such as blades, vanes, combustor cans) exposed to combustion environments at high temperature are susceptible to hot corrosion attack. To successfully plan maintenance and to determine whether to operate in novel combustion modes (e.g., in integrated gasification combined cycles that incorporate pre‐combustion carbon capture) predictions of hot corrosion component life must be made. In this paper, hot corrosion datasets relating to two alloys, MarM 509 (a cobalt‐based superalloy), and Rene 80 (a nickel‐based superalloy) form the basis of hot corrosion predictive lifetime models. The model framework is based on the two stages of incubation and propagation, with the transitions from incubation to propagation around the samples being based on Weibull statistics. The impact of a range of temperatures (including 700 and 900 °C), gas compositions (simulating the combustion of natural gas, H2‐rich syngas, or partially cleaned syngas), and deposit chemistries/fluxes have been assessed. Predictions have been made including the expected damage spread for a range of different exposure conditions.

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Section: Methodsmentioning

confidence: 99%

Section: Image Analysis Techniquementioning

confidence: 99%

Modeling gas turbine materials’ hot corrosion degradation in combustion environments from H₂‐rich syngas

Sumner

Potter

Simms

et al. 2016

Materials & Corrosion

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Fireside Corrosion of Chromium- and Aluminum-Coated Ferritic–Martensitic Steels

et al. 2016

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Coatings for Boiler Components Exposed to Vanadium-Containing Oil Ash in Oxidizing Atmosphere

Montero

Galetz

2017

Oxid Met

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Vanadium-Containing Oil Ash Corrosion of Boilers Under Oxidizing and Syngas Atmospheres

Cited by 13 publications

References 33 publications

Modeling gas turbine materials’ hot corrosion degradation in combustion environments from H₂‐rich syngas

Modeling gas turbine materials’ hot corrosion degradation in combustion environments from H₂‐rich syngas

Fireside Corrosion of Chromium- and Aluminum-Coated Ferritic–Martensitic Steels

Coatings for Boiler Components Exposed to Vanadium-Containing Oil Ash in Oxidizing Atmosphere

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Vanadium-Containing Oil Ash Corrosion of Boilers Under Oxidizing and Syngas Atmospheres

Cited by 13 publications

References 33 publications

Modeling gas turbine materials’ hot corrosion degradation in combustion environments from H2‐rich syngas

Modeling gas turbine materials’ hot corrosion degradation in combustion environments from H2‐rich syngas

Fireside Corrosion of Chromium- and Aluminum-Coated Ferritic–Martensitic Steels

Coatings for Boiler Components Exposed to Vanadium-Containing Oil Ash in Oxidizing Atmosphere

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Product

Resources

About

Modeling gas turbine materials’ hot corrosion degradation in combustion environments from H₂‐rich syngas

Modeling gas turbine materials’ hot corrosion degradation in combustion environments from H₂‐rich syngas