Fireside Corrosion of Ni Base Self-Fluxing Alloy Coatings in WtE Plant: Effect of Flue-Gas and Metal Temperature

2017 ◽  
Vol 87 (5-6) ◽  
pp. 741-756
Author(s):  
J. M. Brossard ◽  
F. Maad ◽  
J. Chartier ◽  
R. Chavrot ◽  
Y. Kawahara
Keyword(s):  
Flue Gas ◽  
Metal Temperature ◽  
Fireside Corrosion ◽  
Plant Effect

Could biomass-fueled boilers be operated at higher steam temperatures? Part 3: Initial analysis of costs and benefits

TAPPI Journal ◽  
2014 ◽  
Vol 13 (8) ◽  
pp. 65-78 ◽  
Author(s):  
W.B.A. (SANDY) SHARP ◽  
W.J. JIM FREDERICK ◽  
JAMES R. KEISER ◽  
DOUGLAS L. SINGBEIL
Keyword(s):  
Flue Gas ◽  
Power Plants ◽  
Superheated Steam ◽  
Black Liquor ◽  
Simulation Software ◽  
Operating Conditions ◽  
Costs And Benefits ◽  
Steam Generation ◽  
Fireside Corrosion ◽  
Corrosion Resistant

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 the value of the additional power that could be generated by operating with higher superheated steam temperatures is estimated. Calculations are presented for five plants that produce both steam and power. Two are powered by black liquor recovery boilers and three by wood-fired boilers. Steam generation parameters for these plants were supplied by industrial partners. Calculations using thermodynamics-based plant simulation software show that the value of the increased power that could be generated in these units by increasing superheated steam temperatures 100°C above current operating conditions ranges between US$2,410,000 and US$11,180,000 per year. The costs and benefits of achieving higher superheated steam conditions in an individual boiler depend on local plant conditions and the price of power. However, the magnitude of the increased power that can be generated by increasing superheated steam temperatures is so great that it appears to justify the cost of corrosion-mitigation methods such as installing corrosion-resistant materials costing far more than current superheater alloys; redesigning biomassfueled boilers to remove the superheater from the flue gas path; or adding chemicals to remove corrosive constituents from the flue gas. The most economic pathways to higher steam temperatures will very likely involve combinations of these methods. Particularly attractive approaches include installing more corrosion-resistant alloys in the hottest superheater locations, and relocating the superheater from the flue gas path to an externally-fired location or to the loop seal of a circulating fluidized bed boiler.

Development of a Laboratory-Scale Pilot for Studying Corrosion on MSWI Heat Exchangers

2008 ◽  
Vol 595-598 ◽  
pp. 271-280 ◽  
Author(s):  
Florimonde Lebel ◽  
Christophe Rapin ◽  
Jean François Mareche ◽  
Renaud Podor ◽  
Xavier Chaucherie ◽  
...  
Keyword(s):  
Flue Gas ◽  
Heat Exchangers ◽  
Laboratory Scale ◽  
Waste To Energy ◽  
Metal Loss ◽  
Gas Temperature ◽  
Fireside Corrosion ◽  
The Face ◽  
Corrosion Scales ◽  
Corrosion Mechanisms

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 flue-gas/tube interface, the velocity of flue-gas and ashes. Corrosion rates obtained on Tu37C carbon steel at a metal temperature equal to 400°C and a flue gas temperatures of 650°C and 850°C (1100 ppm HCl, 110 ppm SO2 and synthetic ashes free of heavy metals) are respectively around 1.6 2m/hour and 5.6 2m/hour. Preferential metal loss, attributed to erosion-corrosion phenomena, is also observed at low flue-gas temperature (T=650°C) on the face exposed at 90° to the flue-gas. The analysis of corrosion scales demonstrates the reproducibility of results and the reliability of corrosion mechanisms determined from experiments, with degradation observed similar to superheater tubes from EfW facilities. Thus, the corrosion pilot developed can be used as an accurate simulator of the environment encountered in MSWI.

scholarly journals Fireside Corrosion of Austenitic Alloys at High Temperature in a Fluidized Bed Coal Combustor

1979 ◽  
Author(s):  
M. R. Carroll ◽  
T. G. Godfrey ◽  
K. R. Drake ◽  
R. H. Cooper
Keyword(s):  
Corrosion Resistance ◽  
High Temperature ◽  
Fluidized Bed ◽  
Metal Temperature ◽  
Test Facility ◽  
Materials Selection ◽  
Fireside Corrosion ◽  
Test Parameters ◽  
Austenitic Alloys ◽  
Fluidized Bed Combustor

A 2.25 sq ft (0.21 sq m) atmospheric fluidized bed combustor (AFBC), using Illinois No. 6 coal and Quincy limestone is being used to test the in-bed corrosion resistance of selected austenitic alloys with a maximum metal temperature of 870 C (1600 F). This paper describes the combustor test facility, test parameters, materials selection and summarizes the results after 1500 hr of testing.

Effect of Sulfur and Chlorine on Fireside Corrosion Behavior of Inconel 740 H Superalloy

2018 ◽  
Vol 37 (3) ◽  
pp. 245-251 ◽  
Author(s):  
Lu Jin-tao ◽  
Li Yan ◽  
Yang Zhen ◽  
Huang Jin-yang ◽  
Zhu Ming ◽  
...  
Keyword(s):  
Corrosion Resistance ◽  
Oxide Film ◽  
Corrosion Behavior ◽  
Flue Gas ◽  
Coal Ash ◽  
Corrosion Process ◽  
Fireside Corrosion

AbstractFireside corrosion behavior of Inconel 740H superalloy was studied at 750 °C in simulated coal ash/flue gas environments by means of XRD, SEM and EDS. The results indicated that the corrosion behavior was strongly related to the SO2 levels and was significantly affected by NaCl additions. In presence of the atmospheres with 0.1 % SO2, the alloy exhibited the highest corrosion resistance due to formation of a stable and dense Cr2O3 film. In presence of the atmosphere with 1.5 % SO2, however, a non-coherent and porous Cr2O3 film was formed. The thickness of film and internal sulfides were substantially increased. The NaCl additions significantly accelerated the corrosion process. A non-protective outer oxide film was formed, composed by multiple layers with serious inner sulfide and spallation. The depths of internal oxidizing and sulfuration zones were significantly increased. The mechanism of ash corrosion formation was also discussed.

The Effects of Varied Hydrogen Chloride Gas Concentrations on Corrosion Rates of Commercial Tube Alloys Under Simulated Environment of WTE Facilities

2008 ◽  
Author(s):  
Shang-Hsiu Lee ◽  
Marco J. Castaldi
Keyword(s):  
Flue Gas ◽  
Metal Temperature ◽  
Waste To Energy ◽  
Composition Analysis ◽  
Gas Composition ◽  
Gas Temperature ◽  
Elementary Composition ◽  
Corrosion Rates ◽  
Simulated Environment ◽  
Hcl Concentration

In order to clarify the effects of HCl concentrations on corrosion rates of commercial tubing in Waste-to-Energy (WTE) boilers, a corrosion test was made by altering the HCl concentration from 0 to 1000ppm, together with simulated flue gas composition. Three commercial tubing SA178A, SA213 T11 and NSSER-4 samples were investigated under a well controlled thermal gradient where the gas temperature was at 700°C and metal temperatures ranged from 480 to 580°C. The duration of each test was 100 hours. The posttest analyses included observations of surface morphology and elementary composition analysis of corrosion products by scanning electron microscope (SEM) and energy dispersive spectroscopy (EDS). The corrosion rates were acquired by measuring the mass loss of samples after the test. The results showed that the addition of HCl to the flue gas increased the corrosion rates of test samples, but the relation between the HCl concentration and corrosion rate was not linear. The HCl effects on corrosion rates were more prominent when its concentration changed from 0 to 500ppm. In addition, the HCl effects were promoted by the increase of metal temperature in particular when metal temperature was over 560°C.

Data-driven modeling of fireside corrosion rate

2017 ◽  
Vol 64 (4) ◽  
pp. 397-404 ◽  
Author(s):  
Amrita Kumari ◽  
S.K. Das ◽  
P.K. Srivastava
Keyword(s):  
Fly Ash ◽  
Corrosion Rate ◽  
Flue Gas ◽  
Thermal Power ◽  
Coal Ash ◽  
Gas Temperature ◽  
Ann Model ◽  
Fireside Corrosion ◽  
Content Type ◽  
Network Training

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). Findings Effects of coal ash and sulfur contents, Wt.% of Na2O and K2O in fly ash and operating variables such as flue gas temperature and percentage excess air intake for coal combustion on the fireside corrosion behavior of superheater boiler tubes have been computationally investigated and parametric sensitivity analysis has been undertaken. Originality/value Quite good agreement between ANN model predictions and the measured values of fireside corrosion rate has been observed which is corroborated by the regression fit between these values.

Method for Determining the Change in Gas Turbine Firing Temperature

2021 ◽  
Author(s):  
Bo Wang ◽  
Fabian Rosner ◽  
Ashok Rao ◽  
Lifeng Zhao ◽  
Scott Samuelsen
Keyword(s):  
Heat Transfer ◽  
Gas Turbine ◽  
Firing Temperature ◽  
Flue Gas ◽  
Pressure Ratio ◽  
Metal Temperature ◽  
Gas Composition ◽  
Blade Surface ◽  
Cooling Flows ◽  
Study Performance

Abstract The maximum firing temperature of a gas turbine (GT) is limited by material constraints. Critical for the operation of the GT is the blade metal temperature, which is impacted by the heat transfer from the combustor outlet gas to the blade surface. In this study, performance characteristics for an H-class-type GT have been established and two correlations for the change in the maximum permissible firing temperature as function of combustor outlet gas composition or flue gas composition and pressure ratio have been derived: I) for detailed GT modeling with cooling flows and II) for simplified GT modelling without specifying cooling flows.

Fireside Corrosion of 9Cr-1Mo Steel at High Temperatures, in the Acid Flue Gas from an Oil Refinery

2021 ◽  
pp. 109878
Author(s):  
Anibal Alviz-Meza ◽  
S Ismat Shah ◽  
Viatcheslav Kafarov ◽  
Darío Peña-Ballesteros
Keyword(s):  
High Temperatures ◽  
Flue Gas ◽  
Oil Refinery ◽  
Fireside Corrosion

Corrosion of Heat-Exchange Tubes in a Simulated Coal-Fired MHD System

1971 ◽  
Vol 93 (2) ◽  
pp. 249-256
Author(s):  
D. Bienstock ◽  
R. J. Demski ◽  
R. C. Corey
Keyword(s):  
Wall Temperature ◽  
Stainless Steels ◽  
Flue Gas ◽  
Experimental Unit ◽  
Steam Generators ◽  
Fireside Corrosion ◽  
Combustion Gas ◽  
Metal Composition ◽  
Mhd System ◽  
Potential Use

An experimental unit was built to burn 125 lb of coal an hour at 4000 deg F in a cyclone burner with oxygen-enriched air preheated to 1500 deg F to ascertain the fireside corrosion problems that might be encountered in the coal-fired MHD generation of power. Potassium carbonate was added to the coal at seed concentrations that would be expected in an MHD combustor. Tubes having a metal composition used in conventional steam generators, and also having a range of alloy compositions that might have potential use in an MHD system, were maintained at surface temperatures of 800–1500 deg F and exposed to products of combustion at 1800–2500 deg F. The seeded flue gas was generally more corrosive than the unseeded. In tests up to 100-hr duration, Haynes 25 was slightly attacked at a wall temperature of 1500 deg F in combustion gas at 2500 deg F; the stainless steels 310, 316, and 446 were resistant at a metal temperature of 1100 deg F in gas at 2100 deg F; carbon steel was attacked at 800 deg F wall temperature and 1800 deg F flue gas.

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