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Journal articles on the topic 'Superheater corrosion'

Author: Grafiati

Published: 4 June 2021

Last updated: 15 February 2022

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1

SHARP, W. B. A. (SANDY), W. J. JIM FREDERICK, JAMES R. KEISER, and DOUGLAS L. SINGBEIL. "Could biomass-fueled boilers be operated at higher steam temperatures? Part 3: Initial analysis of costs and benefits." August 2014 13, no. 8 (2014): 65–78. http://dx.doi.org/10.32964/tj13.8.65.

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The efficiencies of biomass-fueled power plants are much lower than those of coal-fueled plants because they restrict their exit steam temperatures to inhibit fireside corrosion of superheater tubes. However, restricting the temperature of a given mass of steam produced by a biomass boiler decreases the amount of power that can be generated from this steam in the turbine generator. This paper examines the relationship between the temperature of superheated steam produced by a boiler and the quantity of power that it can generate. The thermodynamic basis for this relationship is presented, and

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2

Lehmusto, Juho, Patrik Yrjas, and Mikko Hupa. "The Effect of Pretreatment on the Corrosion Resistance of Superheater Materials." Solid State Phenomena 227 (January 2015): 309–12. http://dx.doi.org/10.4028/www.scientific.net/ssp.227.309.

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In order to improve the power production efficiency of biomass-fired boilers, power plants must be operated at higher steam temperatures than nowadays. One of the main factors hindering the rise of the steam temperatures is the corrosive nature of the flue gases and fly ash towards the superheaters. In this study, the high-temperature corrosion resistance of three commercial superheater steels exposed to potassium chloride was compared. The focus was on the effect of pre-oxidation on the protective properties of different steels, whereupon various variables were used during the pre-oxidation.

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3

KUMAR, KUNAL, VILJAMI MAAKALA, and VILLE VUORINEN. "Integrated study of flue gas flow and superheating process in a recovery boiler using computational fluid dynamics and 1D-process modeling." June 2020 19, no. 6 (2020): 303–16. http://dx.doi.org/10.32964/tj19.6.303.

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Superheaters are the last heat exchangers on the steam side in recovery boilers. They are typically made of expensive materials due to the high steam temperature and risks associated with ash-induced corrosion. Therefore, detailed knowledge about the steam properties and material temperature distribution is essential for improving the energy efficiency, cost efficiency, and safety of recovery boilers. In this work, for the first time, a comprehensive one-dimensional (1D) process model (1D-PM) for a superheated steam cycle is developed and linked with a full-scale three-dimensional (3D) computa

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4

Felkowski, Łukasz, and Jakub Mędrala. "Analysis of superheater tubes failure." E3S Web of Conferences 82 (2019): 01002. http://dx.doi.org/10.1051/e3sconf/20198201002.

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Failures of boiler pressure parts, which working in high temperature and pressure conditions are often caused by overheating or corrosion. These two parameters are decisive, but not the only ones. Local stress concentration also depends on the type of headers support and external loads from pipelines. Boiler pressure parts subjected to all loads mentioned before are steam superheaters. Thermal expansion, high pressure and temperature lead to shortening superheaters lifetime. In the places with significant stress caused by all load combinations it is difficult to predict creep strains and mater

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5

Tallermo, H., I. Klevtsov, M. Uus, and R. A. Crane. "High-Temperature Corrosion of Martensite Alloy Under Oil Shale Fly Ash." Journal of Pressure Vessel Technology 123, no. 3 (2000): 387–90. http://dx.doi.org/10.1115/1.1360693.

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Superheater surfaces in oil shale steam boilers, constructed from pearlitic or austenitic alloys, are subject to intensive corrosion, primarily from the presence of chlorine in external deposits. The applicability of martensitic alloys X10CrMoVNb91 and X20CrMoV121 for superheaters has been examined and empirical equations to predict alloy corrosion resistance have been developed for the operational temperature range. Alloy 10CrMoVNb91 is found highly suitable for superheaters in boilers firing fossil fuels that contain alkaline metals and chlorine. An abnormal dependence of corrosion resistanc

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6

Zhang, Hongliang, Fang Zhang, Wei Su, Ya Jiang, and Yuchun Li. "Research and evaluation of T91 superheater material for high temperature corrosion in biomass power plants." Anti-Corrosion Methods and Materials 62, no. 3 (2015): 133–35. http://dx.doi.org/10.1108/acmm-01-2015-1486.

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Purpose – The purpose of this paper was to evaluate corrosion resistance of superheater T91 material based on high temperature corrosion experiments with a condensate environment. Design/methodology/approach – The contributions of water temperature, chloride concentration and corrosion time were considered and analyzed for modeling corrosion kinetics. The corrosion tendency also was predicted, and the results were compared with higher temperature exposures of T91 tube material installed in a biomass power plant. Findings – High temperature exposure tests showed that the corrosion rates of T91

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7

Li, Hongfeng, Qingtang Xue, Xinhui Nie, and Yunfei Xu. "Investigation of Chemical Cleaning of Supercritical Superheater Oxide Scale." MATEC Web of Conferences 238 (2018): 02011. http://dx.doi.org/10.1051/matecconf/201823802011.

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Recent years, as the development of thermal power plant, superheater oxide film caused by over temperature and tube explosion and the turbine blade erosion problem more and more serious. The research and development of chemical cleaning technology of superheater oxide film is one of the most effective ways to solve this problem. The chemical cleaning of superheater is rather difficult than that of boiler, for mainly the reason as below. First, the scale of superheater tube, differences in microstructure, scales dense and need to use higher cleaning medium concentration and longer cleaning time

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8

Berlanga, C., and J. A. Ruiz. "Study of Corrosion in a Biomass Boiler." Journal of Chemistry 2013 (2013): 1–8. http://dx.doi.org/10.1155/2013/272090.

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Biomass plants, apart from producing energy, help to reduce CO2(g) emissions. One of the biggest problems for their development is superheater corrosion due to fuel corrosivity, especially of the straw. This limits both the temperature of the vapour and also the effectiveness of the plant. In order to know more about the reactions which happen inside the boiler of biomass, thermodynamic calculations using software (HSC Chemistry) have been carried out. Field tests have been carried out in the Sangüesa Biomass Plant in Navarra (Spain): determination of the types of oxides and the deposits forme

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9

KEISER, JAMES R., W. B. A. SANDY SHARP, and DOUGLAS L. SINGBEIL. "Could biomass-fueled boilers be operated at higher steam temperatures? Part 2: Field tests of candidate superheater alloys." August 2014 13, no. 8 (2014): 51–63. http://dx.doi.org/10.32964/tj13.8.51.

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Operating superheater tubes of biomass-fired boilers at considerably higher temperatures than can be tolerated by commonly used structural materials could improve boiler efficiency. However, corrosion of the superheater tubes promoted by interaction with the relatively low melting point deposits that accumulate on the tubes becomes a major issue. The objective of this study was to use field exposures to determine if there are materials acceptable for use as superheater tubes that can operate at temperatures at least 100 Celsius degrees above the current maximum superheater temperature. Corrosi

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10

Muhajir, Habib, Gunawan Dwi Haryadi, and Achmad Widodo. "Remaining Life Assessment of Superheater Tube in Boiler of Coal Fired Power Plant." MATEC Web of Conferences 159 (2018): 02041. http://dx.doi.org/10.1051/matecconf/201815902041.

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Risk Based Inspection (RBI) would be able to establish an effective structural integrity management program, which reduces plant downtime, industry and regulatory burdens, and continue to maintain plant safety. The object of this research is final superheater of boiler coal fired power plant. Both straight tube and elbow tube of final superheater is in a medium risk category. Elbow tube has higher risk ranking because of the higher corrosion rate due to fly ash corrosion. The remaining life of straight tube is about 26 years and elbow tube is only about 7 years using corrosion rate calculation

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11

Trojan, Marcin, Dawid Taler, and Szymon Wielgus. "On-line monitoring of the fouling of the boiler heating surfaces." Thermal Science 23, Suppl. 4 (2019): 1289–300. http://dx.doi.org/10.2298/tsci19s4289t.

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The designed system for the monitoring of the fouling of the furnace and super-heaters/reheaters, presented in the paper, will make it possible to operate the boiler with high efficiency. Measurements of temperatures, pressures, flows, and gas analysis data are used to perform heat transfer analysis in the boiler furnace and evaporator. Power boiler efficiency is calculated by an indirect method. The local and average degree of the combustion chamber slagging is determined in an "on-line" mode. In the case of superheaters, the fouling coefficient is determined for each superheater stage, due t

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12

KEISER, JAMES R., W. B. A. SANDY SHARP, DOUGLAS A. SINGBEIL, LAURIE A. FREDERICK, and CURTIS CLEMMONS. "Performance of alternate superheater materials in a potassium-rich recovery boiler environment." TAPPI Journal 12, no. 7 (2013): 45–56. http://dx.doi.org/10.32964/tj12.7.45.

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One method to significantly improve the efficiency of biomass-fired boilers is to increase the temperature and pressure of the steam generated. However, this requires operating the superheater tubes at considerably higher temperatures than can be tolerated by conventional structural materials. The limiting temperature for conventional materials is primarily determined by corrosion of the superheater tubes that is promoted by interaction with the relatively low melting point deposits that accumulate on the tubes. An air-cooled deposit probe was used to collect samples of the deposits that accum

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13

Jaeger, M., H. Benhaim, D. Tzidony, A. Dumai, and T. Itai. "A techno-economic probabilistic approach to superheater lifetime determination." Journal of Energy in Southern Africa 17, no. 1 (2006): 66–71. http://dx.doi.org/10.17159/2413-3051/2006/v17i1a3295.

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In the commonly used approach, the lifetime of a superheater is estimated by characteristic values of the production parameters and the operating conditions. In this approach, a lower bound for a superheater lifetime is based on some arbitrary safety factor that does not necessarily reflect real life, where unexpected failures do occur. The method proposed here suggests coping with this reality, by employing a techno-economic probabilistic approach. It comprises the following two models: • A probabilistic time to failure evaluation model that considers the variability of the lifetime determini

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14

Henderson, P., P. Szakálos, R. Pettersson, C. Andersson, and J. Högberg. "Reducing superheater corrosion in wood-fired boilers." Materials and Corrosion 57, no. 2 (2006): 128–34. http://dx.doi.org/10.1002/maco.200503899.

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15

Sang, Sheng Huan, Yu Feng Duan, Hui Chao Chen, and Chang Sui Zhao. "High Temperature Corrosion of Superheater Materials in Chlorination-Oxidation Atmosphere." Advanced Materials Research 718-720 (July 2013): 52–58. http://dx.doi.org/10.4028/www.scientific.net/amr.718-720.52.

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Corrosion experiments were carried out with metals 20G, 15CrMoG and 12Cr1MoVG under the simulated atmosphere (N2-5%O2-1500μL/L HCl) of superheaters in waste plastic boilers to choose appropriate materials preventing high temperature corrosion. Corrosion dynamic curves were plotted by mass gain per unit area. Metal specimens after corrosion tests were analyzed by SEM-EDS and XRD. The results show that 20G has the poorest anti-corrosion abilities among the three materials; the corrosion process is involved in activation oxidation of chlorine. Addition of Cr in alloys can improve their corrosion

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16

Luo, Wen-Wen, Zong-De Liu, Yong-Tian Wang, and Rong-Juan Yang. "High Temperature Corrosion Behaviors of the Superheater Materials." Procedia Engineering 36 (2012): 212–16. http://dx.doi.org/10.1016/j.proeng.2012.03.033.

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17

Kumari, Amrita, S. K. Das, and P. K. Srivastava. "Data-driven modeling of fireside corrosion rate." Anti-Corrosion Methods and Materials 64, no. 4 (2017): 397–404. http://dx.doi.org/10.1108/acmm-11-2016-1732.

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Purpose This paper aims to propose an efficient artificial neural network (ANN) model using multi-layer perceptron philosophy to predict the fireside corrosion rate of superheater tubes in coal fire boiler assembly using operational data of an Indian typical thermal power plant. Design/methodology/approach An efficient gradient-based network training algorithm has been used to minimize the network training errors. The input parameters comprise of coal chemistry, namely, coal ash and sulfur contents, flue gas temperature, SOX concentrations in flue gas, fly ash chemistry (Wt.% Na2O and K2O). Fi

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18

Shigeta, Jun-Ichi, Yoshio Hamao, Hiroshi Aoki, and Ichiro Kajigaya. "Development of a Coal Ash Corrosivity Index for High Temperature Corrosion." Journal of Engineering Materials and Technology 109, no. 4 (1987): 299–305. http://dx.doi.org/10.1115/1.3225981.

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Current development of Advanced Steam Cycle coal-fired power plants requires superheater and reheater tubing alloys which can withstand severe conditions for high temperature corrosion. A corrosion equation to predict corrosion rates for candidate alloys has been developed by a study of deposits removed from steam generator tubes and from test probes installed in a boiler, supplemented by laboratory studies using synthetic coal ash. The corrosion equation predicts corrosion for a particular coal as a function of its content of sulfur, acid-soluble alkalies, and acid-soluble aklaline earths. Go

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19

Brossard, Jean Michel, François Nicol, and Xavier Chaucherie. "Fireside Corrosion in Energy Recovery Boilers and Maintenance Issues." Materials Science Forum 595-598 (September 2008): 281–88. http://dx.doi.org/10.4028/www.scientific.net/msf.595-598.281.

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Fireside corrosion is since a long time the main limitation to increase efficiency of energy recovery boilers of waste to energy (W-t-E) facilities. Nevertheless, the increase of steam conditions in addition with the variation of feeding fuels composition imply greater risks of fouling and corrosion along with heat exchanger failure, loss of plant availability and high maintenance costs. Fireside corrosion mechanisms had already been widely treated in the literature and this paper will review the main critical factors that enhance fireside corrosion of superheater. Recent failure cases will be

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20

Asgaryan, Mohammad, Nigel Simms, and Shao Min Wu. "Prediction of the Remaining Service Life of Superheater and Reheater Tubes in Coal-Biomass Fired Power Plants." Advanced Materials Research 856 (December 2013): 343–48. http://dx.doi.org/10.4028/www.scientific.net/amr.856.343.

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Burning biomass in power plants is believed to result in severe fireside corrosion of superheater/reheater tubing and cause unexpected early failures of tubes. Morover, higher operating temeprtures and pressures (to increase the boiler efficiency) will also increase the risk of fireside and steamside oxidation damage to the boiler tubing and lead to shorter component lives. Predicting the remaining service life of superheater/reheater tubes in coal-biomass fired power plants is therefore an important aspect of managing such power plants. The path to this type of failure of tubes involves five

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21

Adnyana, D. N. "Korosi Retak Tegang pada Pipa Superheater Ketel Uap yang Baru Dibangun [Stress Corrosion Cracking of Cage Superheater Tubes of a Newly Built Boiler]." Metalurgi 32, no. 3 (2017): 123. http://dx.doi.org/10.14203/metalurgi.v32i3.357.

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A number of cage superheater tubes of a newly built steam boiler have been leaking during boiler’s first start-up commissioning. Leaking occurred when the boiler had just reached a pressure of 23.7 barg and temperature 4050 C from the intended operating pressure of 53 barg and temperature of 4850C. Type of failure and factors that may have caused the leakage of the cage superheater tube are discussed in this paper. The metallurgical assessment was conducted by preparing a number of specimens from the as received leaked cage superheater tube. Various laboratory examinations were performed inclu

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22

Lee, Doyeon, Hana Kim, Jae Hyeok Park, et al. "High Temperature Corrosion of Superheater Tube under Alkali Chlorides Deposit." Journal of Korea Society of Waste Management 34, no. 5 (2017): 482–89. http://dx.doi.org/10.9786/kswm.2017.34.5.482.

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23

Viklund, Peter, Anders Hjörnhede, Pamela Henderson, Annika Stålenheim, and Rachel Pettersson. "Corrosion of superheater materials in a waste-to-energy plant." Fuel Processing Technology 105 (January 2013): 106–12. http://dx.doi.org/10.1016/j.fuproc.2011.06.017.

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24

Valente, T. "Fireside Corrosion of Superheater Materials in Chlorine Containing Flue Gas." Journal of Materials Engineering and Performance 10, no. 5 (2001): 608–13. http://dx.doi.org/10.1361/105994901770344773.

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25

Abang, Roger, Alexander Lisk, and Hans Joachim Krautz. "Fireside Corrosion of Superheater Materials Under Oxy-coal Firing Conditions." Energy Procedia 40 (2013): 304–11. http://dx.doi.org/10.1016/j.egypro.2013.08.035.

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26

Kuntadi, Koos Sardjono. "KAJIAN KERUSAKAN MATERIAL SUPERHEATER TUBE 2” DENGAN PENDEKATAN STANDAR ASTM." Jurnal Standardisasi 8, no. 2 (2008): 74. http://dx.doi.org/10.31153/js.v8i2.663.

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<p>Equipments used in industry process and migas is generally designed from alloy of steel which hold up to high temperature and attack corrosion. Based on that, it’s require to be conducted an material operation and election, like a component Boiler that is Secondary Superheater is generally weared by pipe from alloy of steel material Cr- Mo or steel with Austenitik type.<br />To know the damage of Secondary Superheater tube 2" material, can be conducted by a chemical composition analysis, test inspection metalografi and hardness. The damage of Material Secondary Superheater tube

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27

Li, Yuchun, Hongliang Zhang, and Yuwu He. "Evaluation of Anticorrosion Performance of New Materials for Alternative Superheater Tubes in Biomass Power Plants." High Temperature Materials and Processes 35, no. 8 (2016): 799–803. http://dx.doi.org/10.1515/htmp-2015-0089.

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AbstractOne way of controlling alkali chloride-induced corrosion in biomass boilers is by designing new alloy materials used as superheater tubes. Four newly designed Cr–Ni alloy was designed and studied for applicability in biomass power plants. High-temperature oxidation experiments and high-temperature corrosion experiments were carried out for evaluation material characterization. Through analysis and discussion of the corrosion kinetics and oxidation kinetics, it can be concluded that materials with series number of “2xx” and “3xx” had better endurance ability in KCl environment under 650

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28

Li, Xiu Juan, Yong Zheng Wang, and Mao Zhen Yue. "Experimental Study on the Corrosion Characteristics during Co-Firing of Cornstalk and Lean Coal." Advanced Materials Research 347-353 (October 2011): 2622–25. http://dx.doi.org/10.4028/www.scientific.net/amr.347-353.2622.

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The elemental and phase compositions of cornstalk ash are largely different from that of lean coal ash. In comparison with pure lean coal, co-firing of cornstalk and lean coal may result in serious corrosion to the heating surface of superheater. This paper presents a composition comparison between the two ashes by means of Energy Dispersive Spectrometer (EDS) analysis and X-Ray Diffraction (XRD) analysis. A number of experiments were carried out in a tubular furnace to investigate the ash corrosion characteristics. Measured corrosion characteristic curves show the agreement of parabolic rule,

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29

Brossard, Jean Michel, Xavier Chaucherie, François Nicol, Christophe Rapin, and Michel Vilasi. "Superheater Fireside Corrosion Mechanisms of SA192 and AISI 316L in WtE Environment: Lab-Scale and Industrial Results." Materials Science Forum 696 (September 2011): 212–17. http://dx.doi.org/10.4028/www.scientific.net/msf.696.212.

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Increase of the energy recovery efficiency facilities is one of the challenges fixed recently by UE to Municipal Solid Waste Incineration (MSWI) operators. To achieve this target, one option consists in optimizing the water/steam cycle to increase electrical efficiency. Nevertheless, higher steam temperature into heat exchanger tube is expected to increase the risks of fireside corrosion, particularly on superheater tubes, along with important loss of materials, frequent shutdowns for repairs and high operational costs. In this study, fireside corrosion test had been performed using an innovat

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30

Kawahara, Yuuzou, Kouji Sasaki, and Yuuji Nakagawa. "Development and Application of High Cr-High Si-Fe-Ni Alloys to High Efficiency Waste-To-Energy Boilers." Materials Science Forum 522-523 (August 2006): 513–22. http://dx.doi.org/10.4028/www.scientific.net/msf.522-523.513.

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In order to improve the durability of high efficiency waste-to-energy boilers, it is essential to develop and apply high temperature corrosion-resistant materials having a long life time according to the intensity of the corrosion conditions. Two types of high Cr-high Si-Fe-Ni base and high Cr-high Si-Ni-Fe base alloy seamless tubes; MAC-N (26Cr-3.5Si-11Fe-Ni base) alloy and MAC-F (23Cr-3.8Si-38Ni-Fe base) alloy respectively which contain no expensive Mo and have better corrosion resistance than the existing alloys under severe corrosive environments of waste combustion gas, have developed. Th

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31

Bankiewicz, Dorota, Patrik Yrjas, and Mikko Hupa. "High-Temperature Corrosion of Superheater Tube Materials Exposed to Zinc Salts†." Energy & Fuels 23, no. 7 (2009): 3469–74. http://dx.doi.org/10.1021/ef801012z.

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32

Katamipour, Alireza, Mohsen Shamshirsaz, and Abdolhossein Fereidoon. "Failure of Secondary Superheater Tube by Caustic Stress Corrosion Cracking (CSCC)." Journal of Failure Analysis and Prevention 15, no. 5 (2015): 583–92. http://dx.doi.org/10.1007/s11668-015-9991-y.

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33

Pettersson, J., C. Pettersson, Nicklas Folkeson, Lars Gunnar Johansson, Erik Skog, and Jan Erik Svensson. "The Influence of Sulfur Additions on the Corrosive Environments in a Waste-Fired CFB Boiler." Materials Science Forum 522-523 (August 2006): 563–70. http://dx.doi.org/10.4028/www.scientific.net/msf.522-523.563.

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Corrosion/deposition field tests have been carried out in the superheater region of a commercial waste-fired 75MW CFBC boiler using air cooled probes. The influence of material temperature (450-500°C), flue gas temperature, temperature variations (i.e. thermal cycling) and additives to the fuel (elemental sulphur and dolomite) on deposition and corrosion was studied. The results presented here mainly consider the influence of sulphur additions to the fuel. The fuel was a mixture of 50% household waste and 50% industrial waste. After exposure the samples were analyzed by ESEM/EDX, XRD, AAS, FIB

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34

Folkeson, Nicklas, J. Pettersson, C. Pettersson, et al. "Fireside Corrosion of Stainless and Low Alloyed Steels in a Waste-Fired CFB Boiler; The Effect of Adding Sulphur to the Fuel." Materials Science Forum 595-598 (September 2008): 289–97. http://dx.doi.org/10.4028/www.scientific.net/msf.595-598.289.

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Corrosion field tests have been carried out in the superheater region of a commercial waste-fired 75MW CFBC boiler using air cooled probes. Exposure time was 24 and 1000 hours. The effect of adding sulphur to the fuel on the corrosion of two high alloyed steels and a low alloyed steel was studied. The fuel consisted of 50% household waste and 50% industrial waste. The exposed samples were analyzed by ESEM/EDX and XRD. Metal loss was determined after 1000 hours. Both materials suffered significant corrosion in the absence of sulphur addition and the addition of sulphur to the fuel reduced corro

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35

Kish, J. R., C. Reid, D. L. Singbeil, and R. Seguin. "Corrosion of High-Alloy Superheater Tubes in a Coastal Biomass Power Boiler." CORROSION 64, no. 4 (2008): 356–66. http://dx.doi.org/10.5006/1.3278479.

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36

Nakagawa, Kiyokazu, Teiich Isozaki, and Shigemitu Kihara. "Effects of Ash Composition on the Coal Ash Corrosion of Superheater Tube." CORROSION ENGINEERING 36, no. 6 (1987): 376–82. http://dx.doi.org/10.3323/jcorr1974.36.6_376.

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37

Aho, M., P. Yrjas, R. Taipale, M. Hupa, and J. Silvennoinen. "Reduction of superheater corrosion by co-firing risky biomass with sewage sludge." Fuel 89, no. 9 (2010): 2376–86. http://dx.doi.org/10.1016/j.fuel.2010.01.023.

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38

Stein-Brzozowska, Gosia, Jörg Maier, Günter Scheffknecht, et al. "Fireside Corrosion of Applied and Modern Superheater-alloys Under Oxy-fuel Conditions." Energy Procedia 37 (2013): 1448–61. http://dx.doi.org/10.1016/j.egypro.2013.06.020.

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39

Asnavandi, Majid, Mohaddeseh Kahram, Milad Rezaei, and Davar Rezakhani. "Fire-Side Corrosion: A Case Study of Failed Tubes of a Fossil Fuel Boiler." International Journal of Corrosion 2017 (2017): 1–8. http://dx.doi.org/10.1155/2017/7367046.

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The failures of superheater and reheater boiler tubes operating in a power plant utilizing natural gas or mazut as a fuel have been analysed and the fire-side corrosion has been suggested as the main reason for the failure in boiler tubes. The tubes have been provided by a fossil fuel power plant in Iran and optical and electron microscopy investigations have been performed on the tubes as well as the corrosion products on their surfaces. The results showed that the thickness of the failed tubes is not uniform which suggests that fire-side corrosion has happened on the tubes. Fire-side corrosi

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40

Singh Sidhu, Varinder Pal, Khushdeep Goyal, and Rakesh Goyal. "Corrosion Behaviour of HVOF Sprayed Coatings on ASME SA213 T22 Boiler Steel in an Actual Boiler Environment." Advanced Engineering Forum 20 (January 2017): 1–9. http://dx.doi.org/10.4028/www.scientific.net/aef.20.1.

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In present study HVOF spraying process had been employed for depositing 93(WC-Cr3C2)-7Ni, 75Cr3C2-25NiCr, 83WC-17CO and 86WC-10CO-4Cr coatings on ASME SA213 T22. All the coatings were found dense and uniform having thickness between 200-250µm. All the coatings on ASME SA213 T22 used in present studies have provided resistance to corrosion in coal fired boiler environment in superheater zone when exposed for 10 cycles at 900°C. Each cycle consists of 100 hours heating followed by 1 hour cooling at ambient conditions. X-ray diffraction (XRD), Scanning Electron Microscopy/Energy Dispersive Spectr

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41

Arivazhagan, N., P. R. Hari, M. Nageswara Rao, and A. H. V. Pavan. "Hot Corrosion of Alloy 617 OCC in Simulated USC Power Plant Environment." Materials Science Forum 941 (December 2018): 1748–53. http://dx.doi.org/10.4028/www.scientific.net/msf.941.1748.

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Alloy 617 OCC, a variant of INCONEL 617 with optimised chemical composition, has been produced in India for manufacture of superheater and reheater tubing in boilers operating in advanced ultrasupercritical (A-USC) power plants. The tubing encounters intense hot corrosion conditions during service. The present study deals with hot corrosion behaviour of 617 OCC in A-USC environment. The environment occurring in A-USC plants was simulated in the laboratory by exposing the material coated with a mixture of salts at 700°C in a flowing gas mixture. For use in A-USC boiler technology, the metal los

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Chatha, Sukhpal Singh, Hazoor S. Sidhu, and Buta Singh Sidhu. "Performance of 75Cr₃C₂-25NiCr Coating Produced by HVOF Process in a Coal-Fired Thermal Power Plant." Advanced Materials Research 1137 (June 2016): 88–100. http://dx.doi.org/10.4028/www.scientific.net/amr.1137.88.

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In the present investigation, 75Cr3C2-25NiCr coating was deposited on T91 boiler tube steel substrate by high velocity oxy-fuel (HVOF) process to enhance high-temperature corrosion resistance. High-temperature performance of bare, as well as HVOF-coated steel specimens was evaluated for 1500 h under cyclic conditions in the platen superheater zone coal-fired boiler, where the temperature was around 900 °C. Experiments were carried out for 15 cycles each of 100 h duration followed by 1 h cooling at ambient temperature. The performance of the bare and coated specimens was assessed via metal thic

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Weulersse, Katia, Gérard Moulin, P. Billard, and G. Pierotti. "High Temperature Corrosion of Superheater Tubes in Waste Incinerators and Coal-Fired Plants." Materials Science Forum 461-464 (August 2004): 973–80. http://dx.doi.org/10.4028/www.scientific.net/msf.461-464.973.

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Uusitalo, Mikko A., Mikko Kaipiainen, Petri M. J. Vuoristo, and Tapio A. Mäntylä. "High-Temperature Erosion-Corrosion of Superheater Materials and Coatings in Chlorine-Containing Environments." Materials Science Forum 369-372 (October 2001): 475–82. http://dx.doi.org/10.4028/www.scientific.net/msf.369-372.475.

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Nakagawa, Kiyokazu, Shigemitu Kihara, Teruaki Kawamoto, and Akira Ohtomo. "Electrochemical Evaluation for Corrosion Resistance of Superheater Tube Materials in Coal Ash Atmosphere." CORROSION ENGINEERING 35, no. 3 (1986): 149–56. http://dx.doi.org/10.3323/jcorr1974.35.3_149.

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Hussain, Tanvir, Adnan U. Syed, and Nigel J. Simms. "Fireside Corrosion of Superheater Materials in Coal/Biomass Co-fired Advanced Power Plants." Oxidation of Metals 80, no. 5-6 (2013): 529–40. http://dx.doi.org/10.1007/s11085-013-9394-y.

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Lehmusto, Juho, Patrik Yrjas, and Leena Hupa. "Pre-oxidation as a Means to Increase Corrosion Resistance of Commercial Superheater Steels." Oxidation of Metals 91, no. 3-4 (2019): 311–26. http://dx.doi.org/10.1007/s11085-019-09898-x.

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Otsuka, N., Y. Fukuda, Y. Kawahara, and T. Hosoda. "Laboratory corrosion tests for simulating fireside wastage of superheater materials in waste incinerators." Materials and Corrosion 51, no. 4 (2000): 236–41. http://dx.doi.org/10.1002/(sici)1521-4176(200004)51:4<236::aid-maco236>3.0.co;2-#.

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Pang, Sheng Jiao, Ping Li, Ting Ju Li, and Jie Zhao. "Study on the Corrosion Resistance Behavior of Multi-Elements Alloy CoCrFeNiTi0.5." Applied Mechanics and Materials 541-542 (March 2014): 61–68. http://dx.doi.org/10.4028/www.scientific.net/amm.541-542.61.

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Multi-elements alloy with good thermal stability is expected to serve as the superheater tube material of ultra-supercritical boiler and may suffer from hot corrosion under the coal-fired atmosphere. In this study, the corrosion resistance behavior of multi-elements alloy CoCrFeNiTi0.5 coated with alkali metal sulfates at 750°C is investigated systematically. The results showed the corrosion kinetics curves of the alloy followed a parabolic growth rate. The corrosion products, which consisted of volatile Na (CrO4) (SO4), (Fe,Ni) xSy, Cr/Ti oxide as well as compound oxides with spinel structure

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Lebel, Florimonde, Christophe Rapin, Jean François Mareche, et al. "Development of a Laboratory-Scale Pilot for Studying Corrosion on MSWI Heat Exchangers." Materials Science Forum 595-598 (September 2008): 271–80. http://dx.doi.org/10.4028/www.scientific.net/msf.595-598.271.

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The efficiency of Waste-to-Energy (W-t-E) boilers is affected by fireside corrosion of the heat exchangers that involve unexpected shutdown of facilities for repairs and limit the increase of steam conditions used to produce electricity. The parameters governing fireside corrosion are various and mechanisms are very complex, nevertheless, they are relatively well documented in the literature. In this paper, a laboratory-scale corrosion pilot, which reproduces MSWI boilers conditions, is described. The specificity of our approach includes simultaneous simulation of the temperature gradient at f

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