Relevant bibliographies by topics / Gas-turbines – Corrosion

Contents

  1. Journal articles
  2. Dissertations / Theses
  3. Books
  4. Book chapters
  5. Conference papers

Academic literature on the topic 'Gas-turbines – Corrosion'

Author: Grafiati
Published: 4 June 2021
Last updated: 1 February 2022

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Journal articles on the topic "Gas-turbines – Corrosion"

1

Meadowcroft, J. M., and J. Stringer. "Corrosion in coal-fired gas turbines." Materials Science and Technology 3, no. 7 (July 1987): 562–70. http://dx.doi.org/10.1080/02670836.1987.11782268.

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Nicholls, J. R., N. J. Simms, and A. Encinas-Oropesa. "Modelling hot corrosion in industrial gas turbines." Materials at High Temperatures 24, no. 3 (September 2007): 149–62. http://dx.doi.org/10.3184/096034007x263587.

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McCreath, C. G. "Hot corrosion site environment in gas turbines." Materials Science and Technology 3, no. 7 (July 1987): 494–500. http://dx.doi.org/10.1080/02670836.1987.11782260.

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Condé, J. F. G., G. C. Booth, and A. F. Taylor. "Protection against hot corrosion in marine gas turbines." Materials Science and Technology 2, no. 3 (March 1986): 314–17. http://dx.doi.org/10.1179/mst.1986.2.3.314.

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Kanao, H., and T. Doi. "Application of corrosion resistant coatings to gas turbines." Welding International 1, no. 10 (January 1987): 976–82. http://dx.doi.org/10.1080/09507118709449048.

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Bavarian, Behzad, Jia Zhang, and Lisa Reiner. "Corrosion Inhibition of Stress Corrosion Cracking and Localized Corrosion of Turbo-Expander and Steam/Gas Turbines Materials." Key Engineering Materials 488-489 (September 2011): 61–64. http://dx.doi.org/10.4028/www.scientific.net/kem.488-489.61.

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Stress corrosion cracking of 7050 aluminum alloys and ASTM A470 steel in the turbo expander and steam/gas turbine industry can cause expensive catastrophic failures, especially for turbo machinery systems performing in hostile, corrosive environments. Commercially available inhibitors were investigated for their effectiveness in reducing and controlling the corrosion susceptibility. Inhibitor effectiveness was confirmed with electrochemical corrosion techniques in different solutions. Polarization resistance increased with concentration of corrosion inhibitor due to film formation and displacement of water molecules. Cyclic polarization behavior for samples in the 1.0% and 5.0% inhibitors showed a shift in the passive film breakdown potential. The substantial increase in the passive range has positive consequences for neutralizing pitting and crevice corrosion cell chemistry. The strain to failure and tensile strength obtained from the slow strain rate studies for both alloys showed pronounced improvement due to corrosion inhibitor ability to mitigate SCC; the fractographic analysis showed a changed morphology with ductile overload as the primary failure mode instead of transgranular or intergranular cracking.
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Bander, F. "Multifuel Gas Turbine Propulsion for Naval Ships: Gas Turbine Cycles Implementing a Rotating Gasifier." Journal of Engineering for Gas Turbines and Power 107, no. 3 (July 1, 1985): 758–68. http://dx.doi.org/10.1115/1.3239798.

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The purpose of this paper is to investigate the possibilities of implementing a rotating gasifier to convert aero-derived gas turbines into multifuel ship propulsion units, thereby combining the advantages of lightweight and compact gas turbines with the multifuel characteristics of a rotating gasifier. Problems (and possible solutions) to be discussed are: (i) aerodynamic interaction between gas turbine and gasifier; (ii) attaining maximum energy productivity together with ease of control; (iii) corrosion and/or erosion of gas turbine components.
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Rocca, E., P. Steinmetz, and M. Moliere. "Revisiting the Inhibition of Vanadium-Induced Hot Corrosion in Gas Turbines." Journal of Engineering for Gas Turbines and Power 125, no. 3 (July 1, 2003): 664–69. http://dx.doi.org/10.1115/1.1456095.

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Since the 1970s, nothing substantially new has been published in the gas turbine community about the hot corrosion by vanadium and its inhibition, after the “inhibition orthodoxy” based on the formation of magnesium vanadate, was established. However, the experience acquired since the late 1980s with heavy-duty gas turbines burning ash-forming fuels in southern China, shows that the combustion of very contaminated fuels does not entail corrosion nor abundant ash-deposit on gas turbines buckets. Analyses of deposits collected from gas turbines fired with these crude oils showed that the ash-deposit contains a large amount of nickel. These new facts led to revisit the role played by nickel and envisage its possible inhibiting action against the vanadium-induced hot corrosion. A thorough review of the literature on the vanadium-induced corrosion have been carried out, and the study of the nickel effects with respect to magnesium effects on the ash deposit have been performed. Results show that nickel presents an interesting way to substitute magnesium for the inhibition of vanadium-induced hot corrosion. The advantages of nickel with respect to magnesium are to be efficient at alow Ni/V ratio, to produce less abundant, less adherent ash and to act, to some extent, as a self-cleaning agent for the blades of the turbine.
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Steinmetz, J., Pierre Steinmetz, and Anne Marie Huntz. "Corrosion Processes Related to Superalloys used in Gas Turbines." Solid State Phenomena 21-22 (January 1992): 223–76. http://dx.doi.org/10.4028/www.scientific.net/ssp.21-22.223.

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Goward, G. W. "Low-Temperature Hot Corrosion in Gas Turbines: A Review of Causes and Coatings Therefor." Journal of Engineering for Gas Turbines and Power 108, no. 2 (April 1, 1986): 421–25. http://dx.doi.org/10.1115/1.3239921.

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In about 1975 an apparently new form of hot corrosion attack of gas turbine airfoils was identified during low-power, low-metal-temperature operation of a marine gas turbine. The rate of this corrosion was substantially greater at about 700° C than that usually observed for sulfate-induced hot corrosion at 800° to 1000° C. The same type of hot corrosion has been subsequently reported to occur in ground-based gas turbines, and is similar in principle to fireside corrosion of boiler tubes. This paper presents a review of probable mechanisms of this so-called low-temperature hot corrosion, of test methods for its laboratory and rig simulation, and of coatings in use or in advanced development for protection of gas turbine airfoils operating in this corrosion regime.
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Dissertations / Theses on the topic "Gas-turbines – Corrosion"

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Smith, P. J. "Predicting hot corrosion rates under coal fired combined cycle power plant conditions." Thesis, Cranfield University, 1994. http://dspace.lib.cranfield.ac.uk/handle/1826/10512.

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Type 11 hot corrosion has been identified as a major life limiting factor of gas turbine components in the topping cycle of coal fired combined cycle power plant. Impurities in the coal combustion gases provide the environmental contaminants necessary for type 11 hot corrosion to occur. It is the purpose of the present study to develop corrosion lifting models such that corrosion rates and thus component lives in coal fired combined cycle plant gas turbines may be accurately predicted thus minimising efficiency losses and plant downtime due to corrosion related problems. Type 11 hot corrosion has been shown to follow bi11lodal distributions which cannot be modelled using the well known mathematical models. It has been shown that a probabilistic approach to modelling is appropriate and that the Gumbel Type I extreme value model of maxima can be used to model the maximum extreme corrosion data This is appropriate as it is the maximum extreme corrosion which in life limiting in the plant gas turbine. Basic corrosion data has been generated through a series of laboratory hot corrosion tests designed to simulate the ambient conditions within the plant gas turbine. The variables having most influence on the corrosion process have been identified as ; temperature, thermal cycling, alkali (Na + K) metal sulphate deposition rate, S02 and HCl in the ambient atmosphere. The corrosion models have been developed from this data which accurately predict the type 11 hot corrosion rates observed in the coal fired gas turbine of a combined cycle power plant .
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Enin-Okut, Edu Owominekaje. "The effect of alumina coatings on the oxidation behavior of nickel-base alloys." Thesis, Georgia Institute of Technology, 1998. http://hdl.handle.net/1853/20226.

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Nowak, Wojciech [Verfasser]. "High temperature corrosion of alloys and coatings in gas-turbines fired with hydrogen-rich syngas fuels / Wojciech Nowak." Aachen : Hochschulbibliothek der Rheinisch-Westfälischen Technischen Hochschule Aachen, 2014. http://d-nb.info/1067263837/34.

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Fisher, Gary Anthony. "The optimisation of bondcoat oxides for improved thermal barrier coating adhesion." Thesis, Cranfield University, 1998. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.245488.

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Bordenet, Bettina [Verfasser]. "High temperature corrosion in gas turbines: thermodynamic modelling and experimental results / vorgelegt von Bettina Maria Elisabeth Bordenet, geb. Waschbüsch." 2004. http://d-nb.info/971724520/34.

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Books on the topic "Gas-turbines – Corrosion"

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Development, North Atlantic Treaty Organization Advisory Group for Aerospace Research and. Erosion, corrosion and foreign object damage effects in gas turbines. Neuilly sur Seine, France: AGARD, 1994.

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North Atlantic Treaty Organization. Advisory Group for Aerospace Research and Development. Erosion, corrosion and foreign object damage effects in gas turbines: Papers presented at the Propulsion and Energetics Panel (PEP) Symposium held in Rotterdam, The Netherlands, 25-28 April 1994. Neuilly-sur-Seine: AGARD, 1994.

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3

Effects of surface chemistry on hot corrosion life: Second annual report. [Cleveland, Ohio]: National Aeronautics and Space Administration, Lewis Research Center, 1985.

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1930-, Radway Jerrold E., ed. Corrosion and deposits from combustion gases: Abstracts and index. Washington: Hemisphere Pub. Corp., 1985.

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E, Leese Gail, and Lewis Research Center, eds. Effects of surface chemistry on hot corrosion life: Final report. [Cleveland, Ohio]: National Aeronautics and Space Administration, Lewis Research Center, 1986.

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Erosion, corrosion and foreign object damage effects in gas turbines: Papers presented at the Propulsion and Energetics Panel (PEP) Symposiumheld in Rotterdam, the Netherlands, 25-28 April, 1994. Neuilly sur Seine: Agard, 1994.

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Book chapters on the topic "Gas-turbines – Corrosion"

1

Pillai, R., K. Kane, M. Lance, and B. A. Pint. "Computational Methods to Accelerate Development of Corrosion Resistant Coatings for Industrial Gas Turbines." In Superalloys 2020, 824–33. Cham: Springer International Publishing, 2020. http://dx.doi.org/10.1007/978-3-030-51834-9_81.

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"Corrosion of Industrial Gas Turbines." In Corrosion: Environments and Industries, 486–90. ASM International, 2006. http://dx.doi.org/10.31399/asm.hb.v13c.a0004158.

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"Hot Corrosion in Gas Turbines." In High-Temperature Corrosion and Materials Applications, 249–58. ASM International, 2007. http://dx.doi.org/10.31399/asm.tb.htcma.t52080249.

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Gurrappa, Injeti, I. V. S. Yashwanth, I. Mounika, Hideyuki Murakami, and Seiji Kuroda. "The Importance of Hot Corrosion and Its Effective Prevention for Enhanced Efficiency of Gas Turbines." In Gas Turbines - Materials, Modeling and Performance. InTech, 2015. http://dx.doi.org/10.5772/59124.

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Müller, Michael. "Thermodynamic prediction of the risk of hot corrosion in gas turbines." In The SGTE Casebook. CRC Press, 2008. http://dx.doi.org/10.1201/9781439832516.ch19b.

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Müller, Michael. "Thermodynamic prediction of the risk of hot corrosion in gas turbines." In The SGTE Casebook, 239–47. Elsevier, 2008. http://dx.doi.org/10.1533/9781845693954.2.239.

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Henao, John, and Oscar Sotelo. "Surface Engineering at High Temperature." In Production, Properties, and Applications of High Temperature Coatings, 131–59. IGI Global, 2018. http://dx.doi.org/10.4018/978-1-5225-4194-3.ch006.

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Thermal and chemical properties are key aspects that determines whether a coating material is useful for high temperature applications. The progress in the application of coatings as high performance and functional materials is currently driven by their reliability under changing environmental conditions. Particularly, for high temperature applications, new gas turbines, propulsion systems, and cutting tools are outstanding examples for the development of enhanced coating systems. With the increase in the complexity of applications of coatings at high temperature, it became necessary that engineers and designers look inside into various aspects of material properties. In that order of ideas, this chapter focuses on reviewing the main physical and chemical concepts related with the performance of engineering coatings at high temperature. Especially, the subjects for reviewing here are thermal shock and hot corrosion.
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ZVBZDIN, Y. I., E. L. KATS, Y. V. KOTOV, V. P. LUBENETS, E. V. SPIRIDONOV, and M. L. KONTER. "NEW CORROSION-RESISTANT NICKEL-BASE SUPER-ALLOYS AND TECHNOLOGICAL PROCESSES OF CASTING GAS TURBINES PARTS WITH DIRECTIONAL SINGLE CRYSTAL AND REGULABLE EQUIAXIAL MINIMIZED MICROPOROSITY STRUCTURE." In Mechanical Behaviour of Materials VI, 111–16. Elsevier, 1992. http://dx.doi.org/10.1016/b978-0-08-037890-9.50137-x.

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Conference papers on the topic "Gas-turbines – Corrosion"

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Shifler, David A. "The Increasing Complexity of Corrosion in Gas Turbines." In ASME Turbo Expo 2019: Turbomachinery Technical Conference and Exposition. American Society of Mechanical Engineers, 2019. http://dx.doi.org/10.1115/gt2019-90111.

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Abstract Removal of fuel sulfur assumes that hot corrosion events will subsequently end in shipboard and aero gas turbine engines. Most papers in the literature since the 1970s consider Na2SO4 and SO3 as the primary reactants causing hot corrosion. However, several geographical sites around the world have relatively high pollutant levels (particulate matter, SO2, etc.) that have the potential to initiate high-temperature corrosion. The deposit chemistry influencing hot corrosion is more complex consisting of multiple sulfates and silicates with the addition of chlorides in a marine environment. Sulfur species may still enter a ship combustion chamber as contaminants via air intake or with seawater entrained in air entering through the ship air intake. High levels of impurities (SO2) above 2 ppm can lead to hot corrosion attack. Research is needed to determine how sulfate salt mixtures and air impurities influence hot corrosion in marine and non-marine conditions. Other impurities such as phosphorus, lead, chlorides, sand, and unburned carbon may lower salt melting temperatures, alter the sulfate activity, or change the solution chemistry and acidity/basicity that leads to accelerating hot corrosion. Other issues need to be considered in non-metallic materials system.
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Wenglarz, Richard A. "Deposition, Erosion and Corrosion Protection for Coal-Fired Gas Turbines." In ASME 1985 Beijing International Gas Turbine Symposium and Exposition. American Society of Mechanical Engineers, 1985. http://dx.doi.org/10.1115/85-igt-61.

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Probably the greatest technical uncertainty for gas turbines directly fired with coal fuels is flowpath degradation due to deposition, erosion and corrosion from coal ash. Mechanisms of turbine deposition, erosion, and corrosion are discussed here and critical factors affecting these degradation processes are identified. Control of these factors is addressed as a basis for providing acceptable lifetimes of turbines operating with coal-derived and other ash bearing fuels.
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3

Rocca, Emmanuel, Pierre Steinmetz, and Michel Moliere. "Revisiting the Inhibition of Vanadium-Induced Hot Corrosion in Gas Turbines." In ASME Turbo Expo 2001: Power for Land, Sea, and Air. American Society of Mechanical Engineers, 2001. http://dx.doi.org/10.1115/2001-gt-0005.

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Since the 70’s, nothing substantially new has been published in the Gas Turbine Community about the hot corrosion by vanadium and its inhibition, after the “inhibition orthodoxy” based on the formation of magnesium vanadate, was established. However, the experience acquired since the late 80’s with Heavy Duty Gas Turbines burning ash-forming fuels in Southern China, shows that the combustion of very contaminated fuels does not entail corrosion nor abundant ash-deposit on gas turbines buckets. Analyses of deposits collected from gas turbines fired with these crude oils showed that the ash-deposit contains a large amount of nickel. These new facts led to revisit the role played by nickel and envisage its possible inhibiting action against the vanadium-induced hot corrosion. A thorough review of the literature on the vanadium-induced corrosion have been carried out, and the study of the nickel effects with respect to magnesium effects on the ash deposit have been performed Results show that nickel presents an interesting way to substitute magnesium for the inhibition of vanadium-induced hot corrosion. The advantages of nickel with respect to magnesium are to be efficient at a low Ni/V ratio, to produce less abundant, less adherent ash and to act, to some extent, as a self-cleaning agent for the blades of the turbine.
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4

Schmid, R., and A. R. Nicoll. "Advances in Abradable Coatings for Gas Turbines." In ASME 1994 International Gas Turbine and Aeroengine Congress and Exposition. American Society of Mechanical Engineers, 1994. http://dx.doi.org/10.1115/94-gt-449.

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Gas turbine engine development continues to accelerate, creating more demanding requirements for abradable seal coatings. These coatings are necessary to provide very small clearances between the rotating and stationary parts in order to minimize gap losses and so Increase efficiency. The relatively few abradable coating materials developed over the last 20 years still perform well in many blade tip seal and labyrinth seal applications. However, rising operating temperatures, corrosion and other environmental changes, longer overhaul times and even better tip clearances are dictating the design of new coating materials which requires a strong scientific approach. For example, ways are being Investigated to replace Nickel-Graphite and other flame sprayed coatings being used between 450 and 700°C respectively because of steady state/corrosion/oxidation/erosion and wear problems respectively. New plasma and HVOF sprayed coatings have been developed using a systematic approach based on material response to operating conditions, minimizing trial and error. The major steps in the programme were: 1. Selection of constituent materials able to withstand service temperatures up to 325 (AISI-Polyester or Polyimide), 450 (AISI base), 700 (MCrAlY base) and 1100°C (ceramic base) respectively. 2. Powder particle manufacture and coating deposition to guarantee highly reproducible coatings. 3. Coating optimization based on wear tests carried out using a fully instrumented abradability test rig and wear mechanism analysis. 4. An investigation of blade tipping systems for high temperature applications. This paper discusses the results of plasma sprayed coatings developed for use at 450 and 700°C.
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Ceschini, Giuseppe Fabio, and Federico Iozzelli. "Gas Turbines Axial Compressor NDE by Eddy Current Probes to Detect Corrosion Pitting." In ASME Turbo Expo 2009: Power for Land, Sea, and Air. ASMEDC, 2009. http://dx.doi.org/10.1115/gt2009-60028.

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Corrosion Pitting is a failure mode that appears in several cases in which there is a combination of Gas Turbines poor Inlet Filtration system (or wrong maintenance of it) and a particularly aggressive environment, characterized by presence of sulfides and chlorides. The corrosion pitting spots can cause crack initiation on the axial compressor blades and, with operation, go on propagating by HCF failure mechanism. This paper describes the application of a new type of Eddy Current probe, suitable to detect those very small spots on the first stage blades, avoiding to disassembly the gas turbine casings, in the very early stage of the corrosion phenomena. A specific experience on some LNG plants is reported.
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Cerri, Giovanni, Laila Chennaoui, Ambra Giovannelli, Mauro Miglioli, and Coriolano Salvini. "Fuel Emulsification Plants on Board of Gas Turbines." In ASME Turbo Expo 2010: Power for Land, Sea, and Air. ASMEDC, 2010. http://dx.doi.org/10.1115/gt2010-22044.

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An innovative Emulsification Engine Feeding System (EEFS) has been developed in the Roma Tre University Fluid Machinery Lab. It is based on an emulsification loop, where fuel and water are fed in real time with the emulsion injection. Thus no chemicals to stabilize water in diesel fuel or ethanol in diesel fuel emulsions, are used. The system assures a sufficient stability level of the emulsion to be injected inside the combustor. Tests carried out on the EEFS, developed for a 250–300 kW gas turbine have shown the good quality of the emulsion in terms of the water droplet diameters and volumetric mixing ratio at the various engine loadings. A water separation section that operates for the duration of the engine shutdown is an unique feature of the EEFS to avoid corrosion during stops.
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Parsons, Edward L., Holmes A. Webb, and Charles M. Zeh. "Assessment of Hot Gas Cleanup Technologies in Coal-Fired Gas Turbines." In ASME 1990 International Gas Turbine and Aeroengine Congress and Exposition. American Society of Mechanical Engineers, 1990. http://dx.doi.org/10.1115/90-gt-111.

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This paper reviews the status of in situ gas stream cleanup technologies which are an integral part of the direct coal-fired gas turbine systems being developed through the U.S. Department of Energy (DOE), Morgantown Energy Technology Center (METC). The technical discussion focuses on the proof-of-concept systems under development in the DOE/METC Advanced Coal-Fueled Gas Turbine Systems (ACFGTS) program initiated in 1986. In this program, Solar Turbines Inc., the Allison Gas Turbine Division of General Motors Corporation, and Westinghouse Electric Corporation have completed bench-scale tests of integrated combustion and hot gas cleanup systems in preparation for full-size subsystem tests. All these projects include the development of cleanup systems for contaminants resulting from the combustion of coal. These systems will both control emissions of pollutants and protect the turbine gas path from fouling, erosion, and corrosion. The bench-scale tests have demonstrated efficient combustion of coal-water slurries (CWS) and dry coal in high-pressure, short residence-time combustors. The tests have also yielded promising results in the abatement of nitrogen oxides (NOx) and volatile alkali and in the removal of ash and sulfur species from the hot gas streams.
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Krishnan, Vaidyanathan, Sanjeev Bharani, J. S. Kapat, Y. H. Sohn, and V. H. Desai. "Prediction of Low Temperature Hot Corrosion Rate in Film Cooled Coal Fired Gas Turbines." In ASME 2003 International Mechanical Engineering Congress and Exposition. ASMEDC, 2003. http://dx.doi.org/10.1115/imece2003-41541.

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The concept of coal based gas turbine power plants has drawn considerable interest in recent years. Coal or syngas based power plants like IGCC have shown significant potential for meeting the ever-increasing power demands as well as stricter environmental regulations. The trouble free operational life of such power plants is limited by a major factor namely hot corrosion of the turbine components. Hitherto, the mechanism of hot corrosion has been investigated in a simpler context, which is not directly applicable to gas turbines in the presence of film cooling techniques. The present paper is an attempt to model hot corrosion in the presence of film cooling relevant to gas turbines, using a simple resistance model and the inherent analogy between heat and mass transfer. This paper considers film cooling air temperatures in the range of 450°C to 550°C, and a free stream gas temperature of 1425°C, with 0.5% sulfur in the fuel. For lower cooling air temperatures (less than 500°C), film cooling air suppresses corrosion, whereas for higher cooling air temperature corrosion rate is more in the presence of film cooling. With film cooling, there is a sharp peak in corrosion rate close to the cooling hole (within 10 slot widths). Due to the possibility that the base superalloy may be exposed in this region, designers should consider the high corrosion rate seriously. However, the present model is limited in its prediction because of its simplicity. Further improvement of the model is essential for optimization purposes.
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Hassan, Khairia Salman, Ahmed Ibrahim Razooqi, and Ayad Khudhair Al-Nadawi. "The effect of coating with nano oxide on pitting corrosion of gas turbines blade." In THE 7TH INTERNATIONAL CONFERENCE ON APPLIED SCIENCE AND TECHNOLOGY (ICAST 2019). AIP Publishing, 2019. http://dx.doi.org/10.1063/1.5123114.

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Wright, I. G., and J. Stringer. "Erosion and Corrosion Considerations for PFBC Gas Turbine Expanders." In ASME 1986 International Gas Turbine Conference and Exhibit. American Society of Mechanical Engineers, 1986. http://dx.doi.org/10.1115/86-gt-217.

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Considerable interest has been developed over the past few years in the application of gas turbines to expand the hot, dirty flue gases from pressurized fluidized-bed combustors (PFBCs) burning coal. Although no full-size gas turbine has yet operated on a PFBC, firm commitments have been made to build commercial PFBC-GT power plants. In addition, there are a number of projects at various stages of development aimed at operating gas turbines on dirty fuels ranging from the expansion of flue gas from the combustion of pulverized coal, to the direct firing of coal-water mixtures. Common concerns of all these applications include erosion and corrosion of the gas turbine hot gas path components. This paper attempts to provide an overview of results of research and testing so far reported in these areas, and to make an assessment of the engineering trade-offs required for the successful operation of PFBC gas turbine expanders.
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