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1
Moumakwa, Donald Omphemetse. "Tribology in coal-fired power plants." Master's thesis, University of Cape Town, 2005. http://hdl.handle.net/11427/16616.
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Includes bibliographical references (pages 90-94).A series of alumina ceramics and silicon carbide (SiC) particulate composites were evaluated in terms of their erosive and abrasive wear behaviour under different conditions, with the aim of reducing wear damage in power plants. The alumina ceramics tested ranged in composition from 90% alumina to 97% alumina content. A nitride fired and an oxide fired SiC particulate composites were also tested for comparison. The impact angle, impact velocity, as well as particle size and type were varied for solid-partide erosion, whereas effects of the applied load, abrasive speed and type of abrasive were studied for abrasive wear. The target materials were also evaluated in terms of morphology and mechanical properties including hardness, flexural modulus and flexural strengths. The erosion rates of the tested alumina ceramics increase with an increase in the impact angle, reaching a maximum at 90°. The high purity 96% alumina dry-pressed body has the best erosion resistance at most impact angles, while the 92% alumina dry pressed body has the worst erosion resistance. The erosion rates also increased with an increase in particle impact velocity, resulting in a velocity exponent (n) value of 1.5. A decrease in the erosion rate was observed for both an increase in particle size range and a decrease in erodent partide hardness. At all angles of impact, solid partide erosion of the target materials is dominated by intergranular fracture and surfaces are typically characterized by erosion pits. The five alumina target materials also show a marked increase in erosion rates when the test temperature is increased from ambient to 150°C. The abrasive wear rates for the materials increased with both applied load and abrasive speed, owing to increased tribological stresses at the contacting asperities. There is also a general trend of increasing abrasion resistance with increasing alumina content. Severe wear, characterized by fracture and grain pullout, is the dominant mechanism of material removal during abrasive wear. This was accompanied by the formation of grooves on the wear surfaces. Although this study was successful in terms of material selection for wear damage reduction in power plants, it also highlighted significant factors and modifications that might need to be considered in future studies.
2
Dugstad, Tore, and Esben Tonning Jensen. "CO2 Capture from Coal fired Power Plants." Thesis, Norwegian University of Science and Technology, Department of Energy and Process Engineering, 2008. http://urn.kb.se/resolve?urn=urn:nbn:no:ntnu:diva-9770.
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Coal is the most common fossil resource for power production worldwide and generates 40% of the worlds total electricity production. Even though coal is considered a pollutive resource, the great amounts and the increasing power demand leads to extensive use even in new developed power plants. To cover the world's future energy demand and at the same time limit our effect on global warming, coal fired power plants with CO2 capture is probably a necessity. An Integrated Gasification Combined Cycle (IGCC) Power Plant is a utilization of coal which gives incentives for CO2 capture. Coal is partially combusted in a reaction with steam and pure oxygen. The oxygen is produced in an air separation process and the steam is generated in the Power Island. Out of the gasifier comes a mixture of mainly H2 and CO. In a shift reactor the CO and additional steam are converted to CO2 and more H2. Carbon dioxide is separated from the hydrogen in a physical absorption process and compressed for storage. Hydrogen diluted with nitrogen from the air separation process is used as fuel in a combined cycle similar to NGCC. A complete IGCC Power Plant is described in this report. The air separation unit is modeled as a Linde two column process. Ambient air is compressed and cooled to dew point before it is separated into oxygen and nitrogen in a cryogenic distillation process. Out of the island oxygen is at a purity level of 95.6% and the nitrogen has a purity of 99.6%. The production cost of oxygen is 0.238 kWh per kilogram of oxygen delivered at 25°C and 1.4bar. The oxygen is then compressed to a gasification pressure of 42bar. In the gasification unit the oxygen together with steam is used to gasify the coal. On molar basis the coal composition is 73.5% C, 22.8% H2, 3.1% O2, 0.3% N2 and 0.3% S. The gasification temperature is at 1571°C and out of the unit comes syngas consisting of 66.9% CO, 31.1% H2, 1.4% H2O, 0.3% N2, 0.2% H2S and 0.1% CO2. The syngas is cooled and fed to a water gas shift reactor. Here the carbon monoxide is reacted with steam forming carbon dioxide and additional hydrogen. The gas composition of the gas out of the shift reactor is on dry basis 58.2% H2, 39.0% CO2, 2.4% CO, 0.2% N2 and 0.1% H2S. Both the gasification process and shift reactor is exothermal and there is no need of external heating. This leads to an exothermal heat loss, but parts of this heat is recovered. The gasifier has a Cold Gas Efficiency (CGE) of 84.0%. With a partial pressure of CO2 at 15.7 bar the carbon dioxide is easily removed by physical absorption. After separation the solvent is regenerated by expansion and CO2 is pressurized to 110bar to be stored. This process is not modeled, but for the scrubbing part an energy consumption of 0.08kWh per kilogram CO2 removed is assumed. For the compression of CO2, it is calculated with an energy consumption of 0.11kWh per kilogram CO2 removed. Removal of H2S and other pollutive unwanted substances is also removed in the CO2 scrubber. Between the CO2 removal and the combustion chamber is the H2 rich fuel gas is diluted with nitrogen from the air separation unit. This is done to increase the mass flow through the turbine. The amount of nitrogen available is decided by the amount of oxygen produced to the gasification process. Almost all the nitrogen produced may be utilized as diluter except from a few percent used in the coal feeding procedure to the gasifier. The diluted fuel gas has a composition of 50.4% H2, 46.1% N2, 2.1% CO and 1.4% CO2. In the Power Island a combined cycle with a gas turbine able to handle large H2 amounts is used. The use of steam in the gasifier and shift reactor are integrated in the heat recovery steam generator (HRSG) in the steam cycle. The heat removed from the syngas cooler is also recovered in the HRSG. The overall efficiency of the IGCC plant modeled is 36.8%. This includes oxygen and nitrogen production and compression, production of high pressure steam used in the Gasification Island, coal feeding costs, CO2 removal and compression and pressure losses through the processes. Other losses are not implemented and will probably reduce the efficiency.
3
Sasi, Giuma A. A. "Evaluation Of Metal Concentrations In Groundwater Nearby Soma Coal-fired Power Plant." Master's thesis, METU, 2005. http://etd.lib.metu.edu.tr/upload/12606756/index.pdf.
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ABSTRACT
EVALUATION OF METAL CONCENTRATIONS IN GROUNDWATER NEARBY SOMA COAL FIRED POWER PLANT
Giuma Sasi
M.S., Department of Chmistry
Supervisor: Prof. Dr. Semra G. Tuncel
December 2005, 95 Pages
In this work, metal pollution in groundwater near by Soma coal-fired power plant was invistigated. Coal combustion results in huge amounts of bottom ash from which metals can originate and migrate to groundwater and pollute it. Forty groundwater samples were collected from water wells in an area near by the power plant to determine 14 metals namelyNa, Ca, K, Mg, Al, Ba, Fe, Zn, Cu, Pb, Cr, Cd, Ni and V. Samples were collected in polyethylene bottles, the pH of the water was measured. Then, the samples were acidified and stored to be analyzed. FAAS, FAES, GFAAS and ICP-AES were used to determine the elements. The results were compared with the WHO, the Turkish and EC guidelines for drinking water quality. Fe concentrations in 12 wells were higher the three guidelines. Zn concentrations in 5 wells were higher than the EC guidelines, but not higher than the Turkish guidelines. Pb concentrations was less than all guilelines but it was relatively high in 8 wells. The other anthropogenic elements were lower than all guidelines but these metals tend to accumulate and they will exceed the guildlines overtime. Enrichment factor calculations showed that the anthropogenic elements were enriched in the regions close to the ash piles pointing out that the ash piles are the main source of these elements. Factor analysis was applied and four main factors of the determined metals were found indicating that the power plant and the ash piles are the main source for the anthropogenic elements.
4
Vir, Arun. "Solar Booster Augmentation for Existing Coal Fired Power Plant (A Feasibility Study)." Thesis, KTH, Kraft- och värmeteknologi, 2012. http://urn.kb.se/resolve?urn=urn:nbn:se:kth:diva-103911.
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The fast depletion of fossil fuel has increased the havoc and need of finding an alternative for the existing fossil fuel based energy industry. As a result, many renewable energy sources such as Solar, Wind, Geo Thermal, Bio mass, etc... are being looked in to. One of the major sources of renewable energy is our sun. There are two methods of tapping the energy from the sun. 1. Solar Thermal It involves using the sun’s heat directly in some processes or indirectly to produce electricity. 2. Photo Voltaic It involves using the light to produce electricity using Photo Voltaic cells. This report involves only the Solar Thermal part where the sun’s heat is indirectly used to produce electricity. This report focuses mainly on a method known as Compact Linear Fresnel Reflectors (CLFR). This method involves the focusing of sun’s energy to an over head tube through mirrors arranged to form the shape similar to that of a Fresnel lens and hence the name. Water runs in the over head tube, the focused energy from the sun, heats up the over head tube and produces steam which in turn runs a steam turbine which in turn produces electricity. This report focuses mainly the potential of using CLFR technology to be augmented in to existing coal fired power plants in India. India has a solar reception of 5 Peta watt hours per year with an average of 4 – 7 kW/m2 DNI. One of National Thermal Power Corporation’s Coal fired thermal power station, Dadri Thermal Power Station, has been chosen for the purpose of case study for this particular thesis. Since there is coal shortage at the power plant location and the plant is not able to produce the peak load, our primary objective was to achieve the production of peak load. The existing power cycle and the solar steam augmented power cycles have been simulated using Thermoflow software and the results have been tabulated.
5
Syed, Muzaffar Ali. "CO2-fuel gas separtationfor a conventional coal-fired power plant (first approach)." Thesis, Högskolan i Borås, Institutionen Ingenjörshögskolan, 2008. http://urn.kb.se/resolve?urn=urn:nbn:se:hb:diva-18705.
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In order to mitigate climate change, there is a desperate need to reduce CO2 emissionsfrom different sources. CO2 capture and sequestration will play an important role in thesereductions. This report is focused on the capture of CO2 from flue gas emitted by a coalfired power plant, which is also described in this report. From the available technologies,post combustion capture with chemical absorption is chosen. It is already been shown byprevious work that it is possible to capture CO2 by this method; this report goes a stepahead to simulate this process. Various methods available are described briefly alongwith the justification why 30% (wt) MEA is used as solvent for this kind of process. Afirst approach is made towards the simulation of the process using Aspen Plus 2006. Themass balance and the energy required for the process have been calculated. Forsimulation the help was taken from Aspen Plus 2006 documentation, also previous workassisted in performing it. The results obtained can be used as the base for optimizing thesimulation.Uppsatsnivå: D
6
Paredez, Jose Miguel. "Coal-fired power plant flue gas desulfurization wastewater treatment using constructed wetlands." Thesis, Kansas State University, 2014. http://hdl.handle.net/2097/18255.
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Master of ScienceDepartment of Civil Engineering
Natalie Mladenov
In the United States approximately 37% of the 4 trillion kWh of electricity is generated annually by combusting coal (USEPA, 2013). The abundance of coal, ease of storage, and transportation makes it affordable at a global scale (Ghose, 2009). However, the flue gas produced by combusting coal affects human health and the environment (USEPA, 2013). To comply with federal regulations coal-fired power plants have been implementing sulfur dioxide scrubbing systems such as flue gas desulfurization (FGD) systems (Alvarez-Ayuso et al., 2006). Although FGD systems have proven to reduce atmospheric emissions they create wastewater containing harmful pollutants. Constructed wetlands are increasingly being employed for the removal of these toxic trace elements from FGD wastewater. In this study the effectiveness of using a constructed wetland treatment system was explored as a possible remediation technology to treat FGD wastewater from a coal-fired power plant in Kansas. To simulate constructed wetlands, a continuous flow-through column experiment was conducted with undiluted FGD wastewater and surface sediment from a power plant in Kansas. To optimize the performance of a CWTS the following hypotheses were tested: 1) decreasing the flow rate improves the performance of the treatment wetlands due to an increase in reaction time, 2) the introduction of microbial cultures (inoculum) will increase the retention capacity of the columns since constructed wetlands improve water quality through biological process, 3) the introduction of a labile carbon source will improve the retention capacity of the columns since microorganisms require an electron donor to perform life functions such as cell maintenance and synthesis. Although the FGD wastewater collected possessed a negligible concentration of arsenic, the mobilization of arsenic has been observed in reducing sediments of wetland environments. Therefore, constructed wetlands may also represent an environment where the mobilization of arsenic is possible. This led us to test the following hypothesis: 4) Reducing environments will cause arsenic desorption and dissolution causing the mobilization of arsenic. As far as removal of the constituents of concern (arsenic, selenium, nitrate, and sulfate) in the column experiments, only sulfate removal increased as a result of decreasing the flow rate by half (1/2Q). In addition, sulfate-S exhibited greater removal as a result of adding organic carbon to the FGD solution when compared to the control (at 1/2Q). Moderate selenium removal was observed; over 60% of selenium in the influent was found to accumulate in the soil. By contrast, arsenic concentrations increased in the effluent of the 1/2Q columns, most likely by dissolution and release of sorbed arsenic. When compared to the control (at 1/2Q), arsenic dissolution decreased as a result of adding inoculum to the columns. Dissolved arsenic concentrations in the effluent of columns with FGD solution amended with organic carbon reached 168 mg/L. These results suggest that native Kansas soils placed in a constructed wetland configuration and amended with labile carbon do possess an environment where the mobilization of arsenic is possible.
7
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 .
8
Mohd, Nistah Nong Nurnie. "An Intelligent Monitoring Interface for a Coal-Fired Power Plant Boiler Trips." Thesis, Curtin University, 2018. http://hdl.handle.net/20.500.11937/77234.
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A power plant monitoring system embedded with artificial intelligence can enhance its effectiveness by reducing the time spent in trip analysis and follow up procedures. Experimental results showed that Multilayered perceptron neural network trained with Levenberg-Marquardt (LM) algorithm achieved the least mean squared error of 0.0223 with the misclassification rate of 7.435% for the 10 simulated trip prediction. The proposed method can identify abnormality of operational parameters at the confident level of ±6.3%.
9
Eastwick, Carol Norma. "Mathematical modelling of pulverised coal-fired burners." Thesis, University of Nottingham, 1995. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.283535.
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Edge, Penelope Jayne. "Modelling and simulation of oxy-coal fired power plants." Thesis, University of Leeds, 2011. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.550804.
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Meeting energy demand while mitigating catastrophic climate change is a serious challenge faced by governments around the globe. The role of coal in the energy mix is integral to this problem: coal is a relatively cheap, flexible and plentiful energy resource; however it is also one of the most polluting. CO2 emissions from coal-fired power plants contribute to global warming. Development and deployment of carbon capture and sequestration (CCS) technology is vital in order to reduce the environmental impact of burning coal. CCS involves capturing and purifying C02 from the emission source and then sequestering it safely and securely to avoid emission to the atmosphere. Oxyfuel combustion, in which the fuel is burnt in a mixture of pure oxygen and recycled flue gas instead of air, is a viable option for CCS from coal-fired power plants. The subject of this discourse is modelling and simulation of oxy-coal combustion. Accurate prediction of the operating characteristics of oxy-coal plants is a vital step towards deployment of the technology. This requires a fundamental understanding of the processes involved and how they might differ from conventional air-firing operation. The distribution of the furnace heat transfer determines the integration between the gas and the water/steam cycles. In order for existing boiler technology to be converted to oxyfuel operation, heat transfer in an oxy-coal furnace should be very similar to air-firing. A combination of fundamental modelling, fluid dynamics, and process simulation have been applied in order to study the impact of oxyfuel combustion on electricity generation. Effectively, nitrogen is replaced with CO2 in the combustion gases and this will affect the gas specific heat capacity, thermal conductivity, diffusivity and absorptivity/emissivity and hence change the rate of convective and radiative heat transfer. The gas-side heat transfer processes are intrinsically linked to chemical reactions and turbulence, and these are accounted for using a CFD model of the furnace. The CFD-generated data are then linked to a full plant simulation in order to investigate the impact of oxyfuel combustion on plant operation. The heat transfer components in the full plant model are developed specifically for detailed prediction of heat transfer and account for changes in composition and mass flow of the flue gases. A range of inlet oxygen concentrations varying from 21-35 vol-% and recycle ratios varying from 80-65% are investigated and the combined simulations reveal a 'working range' of approximately 30-33% inlet oxygen and 72-68% recycle ratio where the distribution of heat transfer is sufficiently similar to allow the plant to operate within the given set- points for air-firing.
11
Peng, J. X. "NOx emission modelling from coal-fired power generation boilers." Thesis, Queen's University Belfast, 2003. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.273143.
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Baziotopoulos, Con, and mikewood@deakin edu au. "Utilising solar energy within conventional coal fired power stations." Deakin University. School of Engineering and Technology, 2002. http://tux.lib.deakin.edu.au./adt-VDU/public/adt-VDU20060817.145445.
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Although the thermodynamic advantages of using solar energy to replace the bled off steam in the regeneration system of Rankine cycle coal fired power stations has been proven theoretically, the practical techno/economic feasibility of the concept has yet to be confirmed relative to real power station applications. To investigate this concept further, computer modelling software THERMSOLV was specifically developed for this project at Deakin University, together with the support of the Victorian power industry and Australian Research Council (ARC). This newly developed software simulates the steam cycle to assess the techno/economic merit of the solar aided concept for various power station structures, locations and local electricity market conditions. Two case studies, one in Victoria Australia and one in Yunnan Province, China, have been carried out with the software. Chapter one of this thesis defines the aims and scope of this study. Chapter two details the literature search in the related areas for this study. The thermodynamic concept of solar aid power generation technology has been described in chapter three. In addition, thermodynamic analysis i.e. exergy/availability has been described in this chapter. The Thermosolv software developed in this study is detailed in chapter four with its structure, functions and operation manual included. In chapter five the outcomes of two case studies using the Thermosolv software are presented, with discussions and conclusions about the study in chapters 6 and 7 respectfully. The relevant recommendations are then made in chapter eight.
13
Arcot, Vijayasarathy Udayasarathy. "Mercury emission control for coal fired power plants using coal and biomass." [College Station, Tex. : Texas A&M University, 2007. http://hdl.handle.net/1969.1/ETD-TAMU-2535.
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Guler, Mehmet. "Evaluation Of State Owned Indigenous Coal Fired Power Plants Including Coal Reserves." Master's thesis, METU, 2010. http://etd.lib.metu.edu.tr/upload/12611591/index.pdf.
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Fossil fuels has preserved their importance in gradually increasing production and consumption of both energy and electricity of the world. Asia, especially China and India, has arisen new actors of the sector.
Energy and electricity consumption of Turkey has also increased in parallel with her economic development, but due to her limited resources, she has become more and more energy dependent in order to meet her growing demand.
Although hard coal is only found around Zonguldak region, with its abundant and widely spread reserves, Turkey ranked world&rsquos third place in lignite production in 2008. Having low calorific value together with high ash and moisture content, most of lignites extracted is being consumed in thermic power plants located near those reserves. In the first two chapters of this study, energy in the world and Turkey will be considered seperately, then coal resources in Turkey will be analysed in the next coming chapter. Indirect and direct greenhouse emissions presented to the UNFCCC will be handled in the fifth chapter In the last chapter, first past and present performances of all indigenous coal fired power plants will be analysed, then after projecting their generation and fuel needs, they are evaluated considering with the reserves they are located. Finally, at the end of decomissioning of those power plants, remaining reserves will be re-evaluated and additional new units will be proposed accordingly.
15
Sekar, Ram C., John E. Parsons, Howard J. Herzog, and Henry D. Jacoby. "Future Carbon Regulations and Current Investments in Alternative Coal-Fired Power Plant Designs." MIT Joint Program on the Science and Policy of Global Change, 2005. http://hdl.handle.net/1721.1/30594.
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This paper assesses the role of uncertainty over future U.S. carbon regulations in shaping the current choice of which type of power plant to build. The pulverized coal technology (PC) still offer the lowest cost power— assuming there is no need to control emissions of carbon. The integrated coal gasification combined cycle technology (IGCC) may be cheaper if carbon must be captured. Since a plant built now will be operated for many years, and since carbon regulations may be instituted in the future, a U.S. electric utility must make the current investment decision in light of the uncertain future regulatory rules. This paper shows how this decision is to be made. We start by describing the economics of the two key coal-fired power plant technologies, PC and IGCC. We then analyze the potential costs of future carbon regulations, including the costs of retrofitting the plant with carbon capture technology and the potential cost of paying charges for emissions. We present the economics of each design in the form of a cash flow spreadsheet yielding the present value cost, and show the results for different scenarios of emissions regulation. We then discuss how to incorporate uncertainty about the future regulation of carbon emissions into the decision to build one plant design or the other. As an aid to decision making, we provide some useful benchmarks for possible future regulation and show how these benchmarks relate back to the relative costs of the two technologies and the optimal choice for the power plant investment. Few of the scenarios widely referenced in the public discussion warrant the choice of the IGCC technology. Instead, the PC technology remains the least costly. The level of future regulation required to justify a current investment in the IGCC technology appears to be very aggressive, if not out of the question. However, the current price placed on carbon emissions in the European Trading System, is higher than these benchmarks. If it is any guide to possible future penalties for emissions in the U.S., then current investment in the IGCC technology is warranted.Abstract in HTML and technical report in PDF available on the Massachusetts Institute of Technology Joint Program on the Science and Policy of Global Change website (http://mit.edu/globalchange/www/).
This research was supported by the MIT Joint Program on the Science and Policy of Global Change and the MIT Carbon Sequestration Initiative. The MIT modeling facility used in this analysis was supported by the US Department of Energy, Office of Biological and Environmental Research [BER] (DE-FG02-94ER61937), the US Environmental Protection Agency (XA-83042801-0), the Electric Power Research Institute, and by a consortium of industry and foundation sponsors.
16
Brajkovic, Jurica. "Evaluating investment in base load coal fired power plant using real options approach." Thesis, University of Southampton, 2010. https://eprints.soton.ac.uk/171553/.
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This thesis investigates the impact of uncertainty on investment in a coalfired power plant using a real options (RO) framework. It is organized in five chapters. In the first chapter I give an outline of the thesis. In Chapter 2 I review the background material. I describe the electricity sector in the pre- and post-liberalization periods and discuss the implication of the transition on investment in new generation capacity. Further, I analyze the mainstream approach to investment analysis used by the majority of electricity companies, the discounted cash flow (DCF) approach. Next, I describe an alternative approach for evaluating investments, RO. In Chapter 3 I perform an econometric analysis of dark spread prices. I select four different stochastic processes and fit them to the observed data. The goal is to find which of the four processes (arithmetic Brownian motion (ABM), Ornstein-Uhlenbeck (OU), Cox-Ingersoll-Ross (CIR) and the Schwartz one-factor process) can best describe the evolution of dark spread prices. The analysis shows that the CIR process is the most appropriate model to use to represent the evolution of dark spread prices. In Chapter 4 I evaluate an investment in a coal-fired power plant assuming the dark spread is the only source of uncertainty and using the stochastic processes for which I estimated parameters in Chapter 3. First I calculate the optimal investment threshold using a traditional budgeting approach based on the DCF principle. Following this, using the RO framework, I calculate the optimal investment threshold for the four stochastic processes. I conclude that one should use mean reverting process to model the investment decision but the choice of mean reverting process does not significantly affect the investment threshold values. In Chapter 5 I extend the analysis and model coal and electricity prices separately. Now the investment decision is affected by two factors: the price of electricity (output) and the price of coal (input). The goal of this chapter is to analyze whether this increase in complexity (going from a one-factor to a two-factor model) affects the result obtained in the previous chapter. Given the different dynamics of electricity and coal prices, I find that this approach enriches the investment analysis and gives additional insights. In particular, the higher the coal price, the greater the dark spread needs to be in order to undertake the investment. Finally, Chapter 6 concludes. The thesis contributes to the existing knowledge in several ways. RO have been applied to the electricity sector before, but this is the first time they have been applied to the evaluation of investment in a coal-fired power plant. Secondly, this is the first time that dark spread, electricity and coal prices are modeled for use in a RO analysis. Finally, the thesis provides a comparison of investment analysis for a coal-fired power plant using RO based on single and two state variables, which has not been carried out so far.
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Agbonghae, Elvis Osamudiamen. "Modelling and optimization of coal-fired power plant generation systems with CO2 capture." Thesis, University of Leeds, 2015. http://etheses.whiterose.ac.uk/7816/.
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This thesis investigates the capture of CO2 from the flue gas of coal-fired power plants using an aqueous solution of MEA, and the main aim of this thesis is the development of an optimized amine-based post-combustion CO2 capture (PCC) process that can be integrated optimally with a pulverized coal-fired power plant. The relevance of this thesis cannot be overemphasised because the reduction of solvent regeneration energy is the focus of most of the solvent-based post-combustion CO2 capture (PCC) research currently being performed globally. From the view point of current research and development (R&D) activities worldwide, three main areas are being investigated in order to reduce the regeneration energy requirement of an amine-based PCC process, namely: (i) development of new solvents with better overall performance than 30 wt% monoethanolamine (MEA) aqueous solution, (ii) PCC plant optimization, and (iii) optimal integration of the PCC Plant, including the associated CO2 compression system, to the upstream power plant. In this thesis, PCC plant optimization and the optimal integration of an optimized PCC Plant, including the associated CO2 compression system, with an upstream coal-fired power plant has been investigated. Thus, an integrated process comprising ~550 MWe (net power after CO2 capture and compression) pulverized coal-fired (PC-fired) supercritical power plant, an MEA-based post-combustion capture (PCC) plant and a CO2 compression system has been modelled, simulated and optimized. The scale-up design of the PCC plant was performed using a novel method based on a rate-based calculation and thus the unnecessary over-design of the PCC plant columns was avoided. Furthermore, because of the importance of the operating pressure of the stripper in a PCC plant integrated to a PC-fired power plant, the impact of the operating pressure of the stripper on the net plant efficiency of the integrated system has been quantified. Also, the impacts of coal type on the overall performance of the integrated process have been quantified.
18
Berry, David A. "Investigation of hot gas desulfurization utilizing a transport reactor." Morgantown, W. Va. : [West Virginia University Libraries], 1999. http://etd.wvu.edu/templates/showETD.cfm?recnum=500.
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Thesis (M.S.)--West Virginia University, 1999.Title from document title page. Document formatted into pages; contains vi, 101 p. : ill. (some col.) Includes abstract. Includes bibliographical references (p. 82-85).
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Bouzguenda, Mounir. "Study of the combined cycle power plant as a generation expansion alternative." Thesis, Virginia Polytechnic Institute and State University, 1987. http://hdl.handle.net/10919/101165.
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Analysis of future alternatives for US utilities is needed as a part of evaluating the impact of combined cycle and phased-construction of integrated coal gasifier power plants on generation expansion. The study encompassed both large and small electric utilities and long-run, least-cost expansion plan for the generating system and studies of the short-run production cost of electrical generation for selected years. The long-run studies were carried out using the Wien Automatic System Planning Package (WASP-II). The optimal combined cycle penetration level was determined for a set of assumptions that involve economics, new technology trends, and feasibility as well as the utility's existing capacity and load forecast. Additional cases were run to account for phased construction and coal gasification. Two electric utilities were selected in this study. These are a U.S. southeastern utility the Bangladesh Electric Utility. The former was chosen as the large utility. The latter was considered a small size utility. WASP-II enhancements enabled us to run cases using IBM-RT and to account for phased construction. The sensitivity studies involved the penetration levels, the fuel supply (oil and natural gas), and economic dispatch of coal gasifiers in particular, and combined cycle power plants in general. Load forecast, and availability of hydroelectric energy were kept uniform. However, adding new power plants and retiring old ones were considered to achieve a more economical and reliable planning strategy while considering issues of technical feasibility.M.S.
20
Schuhbauer, Christian [Verfasser]. "Dynamic and Coupled Simulation of the 700°C Coal-Fired Power Plant / Christian Schuhbauer." München : Verlag Dr. Hut, 2013. http://d-nb.info/1045988774/34.
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Shimeles, Surafel. "Thermo-economic Analysis of Retrofitting an Existing Coal-Fired Power Plant with Solar Heat." Thesis, Högskolan i Gävle, Avdelningen för bygg- energi- och miljöteknik, 2014. http://urn.kb.se/resolve?urn=urn:nbn:se:hig:diva-17216.
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At a time when global environmental change is posing a growing challenge to the world’s economy and creating uncertainties to livelihood of its inhabitants, Coal thermal power plants are under pressure to meet stringent environmental regulations into achieving worldwide set millennial goals for mitigating the effect of emission gases on the atmosphere. Owing to its abundance, it is unlikely to see the use of coal completely missing from the global energy mix within the next hundred years to come. While innovative emission reduction technologies are evolving for the better, trendy technological solutions which require reintegration of these coal plants with alternative greener fuels are growing at the moment. Among these solutions, the following paper investigates possible means for repowering a coal steam power plant with indirect solar heating solutions to boost its annual outputs. Two widely deployable solar thermal technologies, parabolic trough and Central tower receiver systems, are introduced at different locations in the steam plant to heat working fluid thereby enhancing the thermodynamic quality of steam being generated. Potential annual energy output was estimated using commercially available TRNSYS software upon mass and heat balance to every component of solar and steam plant. The annual energy outputs are weighed against their plant erecting and running costs to evaluate the economic vitality of the proposed repowering options. The results show that parabolic trough heating method could serve as the most cost effective method generating electricity at competitive prices than solar only powered SEGS plants. While cost may be acceptable in the unit of energy sense, the scale of implementation has been proven to be technically limited.Kriel Power Plant
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Mohamed, Omar R. Ibrahim. "Study of energy efficient supercritical coal-fired power plant dynamic responses and control strategies." Thesis, University of Birmingham, 2012. http://etheses.bham.ac.uk//id/eprint/3662/.
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The world is facing the challenge of global warming and environment protection. On the other hand, the demand of electricity is growing fast due to economic growth and increase in population. Since the growth in demand is also a heavy factor in energy equations, then the renewable energy alone is not able to generate enough electricity to fill the gap within a short time of period. Therefore, fossil fuel such as coal fired power plants cannot be ruled out immediately due to their generation capacity and flexibility in load following. However, any new coal fired stations should be cleaner compared with traditional power plants. Supercritical power plants are one of the most suitable choices for environmental enhancement and higher efficiency. However, there has been an issue of whether or not to adopt this technology in the UK because it is not clear whether the performance for SC plants can satisfy the British Gird Code requirement. This thesis reports a study of dynamic responses of SC power plants through mathematical modeling, and simulation for Gird Code compliance. It also presents a new control strategy based on an alternative configuration of generalized predictive control for power plant control.
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Zhao, Qiao. "Conception and optimization of supercritical CO2 Brayton cycles for coal-fired power plant application." Thesis, Université de Lorraine, 2018. http://www.theses.fr/2018LORR0080/document.
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L'amélioration des systèmes énergétiques est considérée comme un levier technologique pour répondre aux défis liés à la croissance de la demande d’électricité et des émissions des gaz à effet de serre. Les futures centrales devraient présenter une intégration thermique plus flexible et des sources de chaleur mixtes possibles. Une des solutions fiables consiste à utiliser un cycle de Brayton au CO2 supercritique (CO2-SC), un tel cycle à haut rendement est théoriquement prometteur pour les applications nucléaires, fossiles et solaires thermiques. Un des principaux obstacles au déploiement du cycle de Brayton au CO2-SC est de justifier sa faisabilité, sa viabilité et son potentiel à l’échelle industrielle. Dans ce contexte deux axes de recherche ont été identifiées : • Une sélection rigoureuse de l’équation d’état qui permet de représenter les propriétés d’intérêt du CO2-SC. • Une nouvelle méthodologie pour l’optimisation des centrales électriques, permettant de sélectionner automatiquement le procédé optimal parmi une grande quantité de configurations possibles (dénomme superstructure). Les résultats de la première partie de cette thèse mettent en lumière que l’équation de SW est pertinente pour limiter l’impact de l’imprécision de l’équation d’état sur le dimensionnement du procédé. Dans cette thèse, un simulateur de procédé commercial, ProSimPlus a été combiné avec un solveur type évolutionnaire (MIDACO) afin d’effectuer des optimisations superstructure. Premièrement, le critère d’optimisation est de maximiser le rendement énergétique du procédé. Dans un deuxième temps, on cherche simultanément à minimiser les coûts du procédé. Pour ce faire, des fonctions de coût internes à EDF ont été utilisées afin de permettre l’estimation des coûts d'investissement (CAPEX), des dépenses opérationnelles (OPEX) et du coût actualisé de l'électricité (LCOE)Efficiency enhancement in power plant can be seen as a key lever in front of increasing energy demand. Nowadays, both the attention and the emphasis are directed to reliable alternatives, i.e., enhancing the energy conversion systems. The supercritical CO2 (SC-CO2) Brayton cycle has recently emerged as a promising solution for high efficiency power production in nuclear, fossil-thermal and solar-thermal applications. Currently, studies on such a thermodynamic power cycle are directed towards the demonstration of its reliability and viability before the possible building of an industrial-scale unit. The objectives of this PhD can be divided in two main parts: • A rigorous selection procedure of an equation of state (EoS) for SC-CO2 which permits to assess influences of thermodynamic model on the performance and design of a SC-CO2 Brayton cycle. • A framework of optimization-based synthesis of energy systems which enables optimizing both system structure and the process parameters. The performed investigations demonstrate that the Span-Wagner EoS is recommended for evaluating the performances of a SC-CO2 Brayton cycle in order to avoid inaccurate predictions in terms of equipment sizing and optimization. By combining a commercial process simulator and an evolutionary algorithm (MIDACO), this dissertation has identified a global feasible optimum design –or at least competitive solutions– for a given process superstructure under different industrial constraints. The carried out optimization firstly base on cycle energy aspects, but the decision making for practical systems necessitates techno-economic optimizations. The establishment of associated techno-economic cost functions in the last part of this dissertation enables to assess the levelized cost of electricity (LCOE). The carried out multi-objective optimization reflects the trade-off between economic and energy criteria, but also reveal the potential of this technology in economic performance
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Cantrell, Corey L. "Performance modeling of a pulverized coal boiler : a dissertation presented to the faculty of the Graduate School, Tennessee Technological University /." Click to access online version, 2007. http://proquest.umi.com/pqdweb?index=78&did=1445047991&SrchMode=1&sid=1&Fmt=6&VInst=PROD&VType=PQD&RQT=309&VName=PQD&TS=1255119231&clientId=28564.
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Akpan, Patrick Udeme-Obong. "Impact on heat rate and subsequent emissions due to varying operation of coal fired power plants." Doctoral thesis, Faculty of Engineering and the Built Environment, 2019. https://hdl.handle.net/11427/31647.
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Energy mix modellers often use a constant emissions factor model, which more or less implies a constant heat rate, when trying to show the emissions reduction benefits of integrating renewable power generation system on the grid. This approach does not consider the fact that there is a deterioration in the heat rate with load for the Coal Fired Power Plants that need to accommodate the additional renewable supply. If varying heat rate were to be included in a study, it is often limited to plant specific cases. This PhD presents a novel Variable Turbine Cycle Heat Rate (V-TCHR) model for predicting the part load Turbine cycle heat rate (TCHR) response of various Coal Fired Power Plant (CFPP) architectures, without detail knowledge of the entire steam cycle parameters. A total of 192 process models of representative CFPP architectures were developed using a Virtual Plant software. The models had different combinations of the degree of reheat; the throttle temperature; throttle pressure; and condenser cooling technology. The part load response of all the models were simulated using the software.
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Cheng, Lei. "CO2 Separation from Coal-Fired Power Plants by Regenerable Mg(OH)2 Solutions." University of Cincinnati / OhioLINK, 2013. http://rave.ohiolink.edu/etdc/view?acc_num=ucin1378216250.
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Draganescu, Mihai. "Study of supercritical coal-fired power plant dynamic responses and control for grid code compliance." Thesis, University of Warwick, 2015. http://wrap.warwick.ac.uk/73963/.
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The thesis is concerned with the study of the dynamic responses of a supercritical coal-fired power plant via mathematical modelling and simulation. Supercritical technology leads to much more efficient energy conversion compared with subcritical power generation technology so it is considered to be a viable option from the economic and environmental aspects for replacement of aged thermal power plants in the United Kingdom. However there are concerns for the adoption of this technology as it is unclear whether the dynamic responses of supercritical power plants can meet the Great Britain Grid Code requirement in frequency responses and frequency control. To provide answers to the above concerns, the PhD research project is conducted with the following objectives: to study the dynamic responses of the power plant under different control modes in order to assess its compliance in providing the frequency control services specified by the Great Britain Grid Code; to evaluate and improve the performance of the existing control loops of the power plant simulator and in this regard a controller based on the Dynamic Matrix Control algorithm was designed to regulate the coal flow rate and another controller based on the Generalized Predictive Control algorithm was implemented to regulate the temperature of the superheated steam; to conduct an investigation regarding frequency control at the power plant level followed by an analysis of the frequency control requirements extracted from the Grid Codes of several European and non-European countries. The structure and operation of the supercritical power plant was intensively studied and presented. All the simulation tests presented in this thesis were carried out by the mean of a complex 600 megawatts power plant simulator developed in collaboration with Tsinghua University from Beijing, China. The study of the conducted simulation tests indicate that it is difficult for this type of power plant to comply with the frequency control requirements of the Great Britain Grid Code in its current control method. Therefore, it is essential to investigate more effective control strategies aiming at improving its dynamic responses. In the thesis, new Model Predictive Control power plant control strategies are developed and the performance of the control loops and consequently of the power plant are greatly improved through implementation of Model Predictive Control based controllers.
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Shomo, Laurie Suzanne 1951. "Biotic and physico-chemical conditions in a cooling reservoir of a coal-fired power plant." Thesis, The University of Arizona, 1991. http://hdl.handle.net/10150/277958.
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Cholla Lake is a cooling reservoir for the coal-fired Cholla electrical generating plant. The lake provides recreational fishing and water contact recreation. The fish populations are self-sustaining. I collected water, sediment, and whole body fish samples to be analyzed for levels of some possibly toxic inorganic constituents. I also measured dissolved oxygen, pH, Secchi disk transparency. I compared current fish population structure, fish stomach contents, and the frequency of occurrence of benthos, with those same parameters in previous studies. Water temperature and turbidity have increased; catfish and bluegill have increased in their relative abundance; and the density of benthic invertebrates has decreased. Aquatic insects occur most commonly in the stomach contents of bluegill and filamentous algae in the stomachs of catfish. Selenium levels in all matrices exceed national averages and are above levels in a nearby reservoir unaffected by the power station.
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Furl, Chad Van Lehr Larry L. Van Walsum G. Peter White Joseph Daniel. "A baseline assessment of local mercury deposition from coal-fired power plants in Central Texas." Waco, Tex. : Baylor University, 2006. http://hdl.handle.net/2104/4741.
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Fay, James A., and Dan S. Golomb. "Economics of seasonal gas substitution in coal- and oil-fired power plants." MIT Energy Lab, 1987. http://hdl.handle.net/1721.1/18199.
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Sekar, Ram Chandra. "Carbon dioxide capture from coal-fired power plants : a real potions analysis." Thesis, Massachusetts Institute of Technology, 2005. http://hdl.handle.net/1721.1/32292.
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Thesis (S.M.)--Massachusetts Institute of Technology, Engineering Systems Division, Technology and Policy Program; and, (S.M.)--Massachusetts Institute of Technology, Dept. of Mechanical Engineering, 2005.Includes bibliographical references.
Investments in three coal-fired power generation technologies are valued using the "real options" valuation methodology in an uncertain carbon dioxide (CO2) price environment. The technologies evaluated are pulverized coal (PC), integrated coal gasification combined cycle (baseline IGCC), and IGCC with pre-investments that make future retrofit for CO2 capture less expensive (pre-investment IGCC). All coal-fired power plants can be retrofitted to capture CO2 and can be considered "capture-capable", even though the cost and technical difficulty to retrofit may vary greatly. However, initial design and investment that take into consideration such future retrofit, makes the transition easier and less expensive to accomplish. Plants that have such an initial design can be considered to be "capture-ready". Pre-investment IGCC can be considered to be "capture-ready" in comparison to PC and baseline IGCC on this basis. Furthermore, baseline IGCC could be taken as "capture-ready" in comparison to PC. Cash flow models for specific cases of these three technologies were developed based on literature studies. The problem was formulated such that CO2 price is the only uncertain cash flow variable. All cases were designed to have a constant net electric output before and after CO2 retrofit. As a result, electricity price uncertainty had no differential impact on the competitive positions of the different technologies. While coal price was taken to be constant, sensitivity analysis were conducted to show the impact of varying coal prices. Investment valuation was done using the "real options" approach.
(cont.) This approach combines (i) Market Based Valuation (MBV) to valuing cash flow uncertainty, with (ii) Dynamic quantitative modeling of uncertainty, which helps model dynamic retrofit decision making. The thesis addresses three research questions: (i) What is the economic value of temporal flexibility in making the decision to retrofit CO2 capture equipment? (ii) How does the choice of valuation methodology (DCF v. MBV) impact the investment decision to become "capture-ready"? (iii) Among the coal-fired power plant technologies, which should a firm choose to invest in, given an uncertain CO2 policy? What are the economic factors that influence this choice? The answers to the research questions strongly depend on the input assumptions to the cash flow and CO2 price models, and the choice of representative cases of the technologies. For the specific cases analyzed in this thesis, it was found that investing in "capture-ready" power plants was not economically attractive.
by Ram Chandra Sekar.
S.M.
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Weir, Scott M. "Mercury concentrations in wetlands associated with coal-fired power plants in Illinois /." Available to subscribers only, 2009. http://proquest.umi.com/pqdweb?did=1796120981&sid=2&Fmt=2&clientId=1509&RQT=309&VName=PQD.
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Weir, Scott. "Mercury concentrations in wetlands associated with coal-fired power plants in Illinois." OpenSIUC, 2009. https://opensiuc.lib.siu.edu/theses/540.
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Burning of fossil fuels by coal-fired power plants (CFPPs) is one of the largest sources of environmental mercury in the United States and there have been conflicting reports of local impacts due to CFPPs in the US. Illinois has 23 coal-fired electrical generating plants that may be contributing to elevated environmental mercury concentrations that have contributed to mercury advisories for 13 bodies of water located throughout the state. The objective of the current study is to determine if there is a pattern of total mercury concentrations in sediment and tadpoles collected from ponds located upwind and downwind of 4 coal-fired electrical generating plants in Illinois. Baldwin, Joppa, Newton, and Southern Illinois Power Cooperative (SIPC) coal-fired power plants were chosen for study. Three sediment samples were collected from ponds located 3-5, 8-10, and 13-15 km downwind and from ponds located 3-5 km upwind of each power plant and analyzed for total mercury concentration. Temperature of overlying water (C), pH, oxidation-reduction potential (mV), and texture were determined for each sediment sample. Bullfrog (Lithobates catesbeiana) or Green frog (Lithobates clamitans) tadpoles were collected opportunistically from 29 of the 44 ponds chosen for study. Each tadpole was identified to species and Gosner stage, and then weighed and measured for total length prior to total mercury analysis. For Baldwin, Joppa, and SIPC power plants, no significant pattern of total mercury could be determined from either sediment or tadpole data. For Newton power plant, total mercury concentrations were significantly greater 3-5 km downwind for sediment, and 8-15 km downwind for tadpoles compared to concentrations at upwind locations. Sediment total mercury concentrations were not significantly correlated with any of the characteristic variables (e.g. pH). Tadpole total mercury was significantly negatively correlated with length and weight, but not significantly correlated with any of the sediment variables. Sediment and tadpole concentrations were not significantly correlated.
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Wang, Kelin. "Mercury Transportation in Soil Using Gypsum from Flue Gas Desulphurization Unit in Coal-Fired Power Plant." TopSCHOLAR®, 2012. http://digitalcommons.wku.edu/theses/1199.
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This work investigates mercury flux in soil amended by gypsum from flue gas desulphurization (FGD) units of coal-fired power plants. There are two phases of this research, including field and greenhouse studies. Previous studies indicate that FGD gypsum could increase corn yield, but may lead to more mercury uptake by corn.
Recent studies have been carried out in greenhouses to investigate mercury transport in FGD gypsum treated soil. Major aspects include uptake of mercury by plants and emission of mercury into the atmosphere based on application rates of FGD gypsum. Additional aspects include rainfall, temperature, soil, and plants types. Higher FGD gypsum application rates generally led to higher mercury concentration in the soil, as well as, increased mercury emission into the atmosphere, and increased mercury levels in plants, especially roots and leaves. Soil properties and plant species also played important roles in mercury transport. In addition, it was also found that increased water and higher temperatures may contribute to mercury emission in the atmosphere.
Some plants, such as tall fescue, were able to prevent mercury from atmospheric emission and infiltration within the soil. Mercury concentration in the stem of plants was found to be increased and then plateaued upon increasing FGD gypsum application. However, mercury in roots and leaves was generally increased upon increasing FGD gypsum application rates. Some mercury was likely absorbed by leaves of plants from mercury in the surrounding atmosphere.
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Lange, Ian. "Investigating the effects of the 1990 Clean Air Act Amendments on inputs to coal-fired power plants /." Thesis, Connect to this title online; UW restricted, 2005. http://hdl.handle.net/1773/7421.
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Khobo, Rendani Yaw-Boateng Sean. "A modelling methodology to quantify the impact of plant anomalies on ID fan capacity in coal fired power plants." Master's thesis, Faculty of Engineering and the Built Environment, 2020. http://hdl.handle.net/11427/32244.
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In South Africa, nearly 80 % of electricity is generated from coal fired power plants. Due to the complexity of the interconnected systems that make up a typical power plant, analysis of the root causes of load losses is not a straightforward process. This often leads to losses incorrectly being ascribed to the Induced Draught (ID) fan, where detection occurs, while the problem actually originates elsewhere in the plant. The focus of this study was to develop and demonstrate a modelling methodology to quantify the effects of major plant anomalies on the capacity of ID fans in coal fired power plants. The ensuing model calculates the operating point of the ID fan that is a result of anomalies experienced elsewhere in the plant. This model can be applied in conjunction with performance test data as part of a root cause analysis procedure. The model has three main sections that are integrated to determine the ID fan operating point. The first section is a water/steam cycle model that was pre-configured in VirtualPlantTM. The steam plant model was verified via energy balance calculations and validated against original heat balance diagrams. The second is a draught group model developed using FlownexSETM. This onedimensional network is a simplification of the flue gas side of the five main draught group components, from the furnace inlet to the chimney exit, characterising only the aggregate heat transfer and pressure loss in the system. The designated ID fan model is based on the original fan performance curves. The third section is a Boiler Mass and Energy Balance (BMEB) specifically created for this purpose to: (1) translate the VirtualPlant results for the steam cycle into applicable boundary conditions for the Flownex draught group model; and (2) to calculate the fluid properties applicable to the draught group based on the coal characteristics and combustion process. The integrated modelling methodology was applied to a 600 MW class coal fired power plant to investigate the impact of six major anomalies that are typically encountered. These are: changes in coal quality; increased boiler flue gas exit temperatures; air ingress into the boiler; air heater inleakage to the flue gas stream; feed water heaters out-of-service; and condenser backpressure degradation. It was inter alia found that a low calorific value (CV) coal of 14 MJ/kg compared to a typical 17 MJ/kg reduced the fan's capacity by 2.1 %. Also, having both HP FWH out of service decreased the fan's capacity by 16.2 %.
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Arumugam, Senthilvasan. "Nitrogen oxides emission control through reburning with biomass in coal-fired power plants." Thesis, Texas A&M University, 2004. http://hdl.handle.net/1969.1/1508.
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Oxides of nitrogen from coal-fired power stations are considered to be major pollutants, and there is increasing concern for regulating air quality and offsetting the emissions generated from the use of energy. Reburning is an in-furnace, combustion control technology for NOx reduction. Another environmental issue that needs to be addressed is the rapidly growing feedlot industry in the United States. The production of biomass from one or more animal species is in excess of what can safely be applied to farmland in accordance with nutrient management plans and stockpiled waste poses economic and environmental liabilities. In the present study, the feasibility of using biomass as a reburn fuel in existing coal-fired power plants is considered. It is expected to utilize biomass as a low-cost, substitute fuel and an agent to control emission. The successful development of this technology will create environment-friendly, low cost fuel source for the power industry, provide means for an alternate method of disposal of biomass, and generate a possible revenue source for feedlot operators. In the present study, the effect of coal, cattle manure or feedlot biomass, and blends of biomass with coal on the ability to reduce NOx were investigated in the Texas A&M University 29.31 kW (100,000 Btu/h) reburning facility. The facility used a mixture of propane and ammonia to generate the 600 ppm NOx in the primary zone. The reburn fuel was injected using air. The stoichiometry tested were 1.00 to 1.20 in the reburn zone. Two types of injectors, circular jet and fan spray injectors, which produce different types of mixing within the reburn zone, were studied to find their effect on NOx emissions reduction. The flat spray injector performed better in all cases. With the injection of biomass as reburn fuel with circular jet injector the maximum NOx reduction was 29.9 % and with flat spray injector was 62.2 %. The mixing time was estimated in model set up as 936 and 407 ms. The maximum NOx reduction observed with coal was 14.4 % and with biomass it was 62.2 % and the reduction with blends lay between that of coal and biomass.
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Le, Grange Willie. "Component development for a high fidelity transient simulation of a coal-fired power plant using Flownex SE." Master's thesis, University of Cape Town, 2018. http://hdl.handle.net/11427/29863.
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Large coal-fired power stations are designed to be run predominantly at full load and optimum conditions. The behaviour of plants, operating at low load and varying conditions, is getting more and more attention due to the introduction of variable renewable generation on the grid. Consequently, the need for a fully transient high-fidelity system based model has grown, as this will enable one to study the behaviour of plants under such non-ideal conditions. This report details the development of a feedwater heater, deaerator and turbine component for such a high-fidelity transient system model using the Flownex Simulation Environment, a onedimensional thermohydraulic network solver. The components have been modelled all with the aim of using minimal design input data. The feedwater heater component model includes transient effects and thermodynamic relations to represent aspects such as heater performance, level control and transient inertia. In determining the heat transfer characteristics, the model makes use of plant-performance data and correlates the amount of heat transfer by using the feedwater mass flow as the load indicating parameter. This approach eliminates the need for specific geometrical details to calculate the effective heat transfer area. The level control is modelled by using a level representation built from using heat exchanger design methods. The turbine component is modelled by using Fuls’ Semi-Ellipse law or the pressure drop modelling and Ray’s semi-empirical method for the efficiency modelling. The model also contains transient effects, which include thermal inertia due to the shaft and casing, and rotational inertia due to the shaft. The deaerator component is modelled by adapting the model presented by Banda, and modifying the model to work under various conditions. This involved using curve fit methods in Flownex to use input data to model the pressure drop over the main condensate valve. Each of the mentioned components was validated and verified with plant data and finally packaged into a compound component which is a component consisting of a subnetwork in Flownex. These compound components further contain design inputs which are easily accessible by the user. The component models were integrated into larger networks in which various scenarios can be run. A short transient scenario was run on the low-pressure feedwater train of a specific power station. The scenario involved a turbine trip where the bled steam valves for the heaters were closed suddenly. The speed of the valves closing was however unknown and after closing the valves in approximately 10 seconds, results agreed relatively well with plant data. This illustrated the short transient capabilities of the feedwater heater component model. The three component models (feedwater heater, turbine and deaerator) were finally integrated into a regenerative Rankine cycle and was set up using minimal design data. The boiler, condenser and condensate pump were set as boundary conditions in the network but all extraction points for the network were connected. Steady-state results were obtained for various load cases and the main temperature, flow and pressure results were compared. Results agree well with plant data, even at low load conditions
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Arzuman, Anry Misra Anil. "Fate and aqueous transport of mercury in light of the Clean Air Mercury Rule of coal-fired electric power plants." Diss., UMK access, 2006.
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Thesis (Ph. D.)--School of Computing and Engineering and Dept. of Geosciences. University of Missouri--Kansas City, 2006."A dissertation in engineering and geosciences." Advisor: Anil Misra. Typescript. Vita. Title from "catalog record" of the print edition Description based on contents viewed Oct. 30, 2007. Includes bibliographical references (leaves 210-220 ). Online version of the print edition.
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Sliger, Rebecca North. "Development of a chemical kinetic model for the homogeneous oxidation of mercury by chlorine species : a tool for mercury emissions control /." Thesis, Connect to this title online; UW restricted, 2001. http://hdl.handle.net/1773/7102.
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Tolvanen, Merja. "Mass balance determination for trace elements at coal-, peat- and bark-fired power plants /." Espoo [Finland] : VTT Technical Research Centre of Finland, 2004. http://www.vtt.fi/inf/pdf/publications/2004/P524.pdf.
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Xu, Jiangang Chemical Sciences & Engineering Faculty of Engineering UNSW. "Coal related bed material agglomeration in pressurized fluidized bed combustion." Awarded by:University of New South Wales. School of Chemical Sciences and Engineering, 2006. http://handle.unsw.edu.au/1959.4/25131.
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The thermodynamic behaviours in a PFBC combustor were simulated for the ash from all of the six coals with sand and limestone as bed material. Ash components determined the ash thermodynamic behaviour at high temperature, and each component had different effects. For assessment of the potential for bed material agglomeration, the temperature at which 15% of the ash would become liquid (T15) was calculated with the coal ash, the cyclone ash and the cyclone ash mixed with varying amounts of limestone. Both the bed ash and fly ash, collected from an industrial PFBC plant, consisted of limestone/lime particles with different extent of sulphation, and coal ash particles. The calcium aluminosilicate material formed on the coal ash particles but not on the limestone particles. The aluminosilicate materials appeared to be formed from fine ash and lime particles at some local hot zones in the boiler. The melted materials may glue ash and bed material particle into large particles leading to bed agglomeration and defluidization. Four mechanisms were proposed for the formation of bed material agglomeration in PFBC, which may occur under different conditions. One mechanism explains the bed material agglomeration with the high localized high temperature zone due to the improper design or operation, while the bed agglomeration through the other three mechanisms results from the unsuitable coals burnt in the PFBC combustor. The maximum char temperature and the minimum T15 were used simultaneously to predict the tendency towards bed material agglomeration in PFBC burning different coals. Both char properties and ash properties should be considered during coal selection process for PFBC, to ameliorate the potential problem of bed agglomeration.
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Alie, Colin F. "CO₂ capture with MEA integrating the absorption process and steam cycle of an existing coal-fired power plant /." Waterloo, Ont. : University of Waterloo, 2004. http://etd.uwaterloo.ca/etd/calie2004.pdf.
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Thesis (M.A.Sc.)--University of Waterloo, 2004.Contains hypertext links. "A thesis presented to the University of Waterloo in fulfilment of the thesis requirement for the degree of Master of Applied Science in Chemical Engineering". Includes bibliographical references.
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Clay, Joshua Dewaine. "An Energetic and Exergetic Analysis of a Mid-Sized, Coal Fired Power Plant in the Midwestern United States." OpenSIUC, 2018. https://opensiuc.lib.siu.edu/theses/2459.
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The focus of this project is the performance of an energy and exergy audit on a 173 MW pulverized coal fired, subcritical steam power plant unit in the Midwestern United States. Thermal efficiency is good for measuring the overall energy conversion capability of a process but it does not account for the entropy generation which occurs in real-world processes. This is where exergy analysis can be used to identify the greatest sources of loss due to the system’s irreversibilities, an unavoidable consequence of the second law of thermodynamics. The goal of this study is the calculation and mapping of energy and exergy cycle performance characteristics as well as the amounts of exergy destroyed throughout the process in the various components. With the magnitudes of the losses and their sources identified, mitigation options are compiled. The overall cycle energetic and exergetic efficiencies were found to be 32.8% and 33.7%, respectively. These values fall within the normal range expected for plants of this size and type. The largest source of exergy destruction in the cycle was found to be within the steam generator.
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Chalmers, Hannah. "Flexible operation of coal-fired power plants with post-combustion capture of carbon dioxide." Thesis, University of Surrey, 2010. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.521724.
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Hutchens, Steven Jason. "Modeled sulfur dioxide exposure from a proposed coal fired power plant, using geographic information systems and air dispersion modeling." Morgantown, W. Va. : [West Virginia University Libraries], 2004. https://etd.wvu.edu/etd/controller.jsp?moduleName=documentdata&jsp%5FetdId=3376.
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Thesis (M.S.)--West Virginia University, 2004.Title from document title page. Document formatted into pages; contains xii, 161 p. : ill. (some col.), maps (some col.). Includes abstract. Includes bibliographical references (p. 132-137).
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Lesley, Michael Patrick. "The fluxes and fates of arsenic, selenium, and antimony from coal fired power plants to rivers." Thesis, Available online, Georgia Institute of Technology, 2004:, 2003. http://etd.gatech.edu/theses/available/etd-04082004-180307/unrestricted/lesley%5fmichael%5fp%5f200312%5fms.pdf.
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Ming-ChouTsai and 蔡銘洲. "Optimization Matching Analysis for Coal-fired Power Plant." Thesis, 2010. http://ndltd.ncl.edu.tw/handle/72607197342122093457.
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碩士國立成功大學
工學院工程管理專班
98
As it is well known, traditional fire power plants are coal-fired. The exhaust gas, however, contains substances such as fly ash, sulfur oxide, nitrogen oxide and carbon dioxide, which worsen the environment and global warming. Unfortunately, there is no single type of coal that can be used to generate electricity with regard to the environmental protection. Apart from that, the quality of coal has a tremendous influence on the operation of the boiler. As a result, it requires a circumspect investigation and evaluation to select and matching the coal. Since various characteristics of the coal will decrease boiler efficiency and exceed the limit set by the environmental protection policy, the cost will consequently increase.To learn to lower the cost, the study investigates the conditions of the equipment in power plants and the data of burning coal. Then, it analyses both the relationship between the coal quality and the materials concerned, and the operation cost that is affected. Using the Linear Programming Model, this study obtains the optimization matching formula of coal with the minimum price and the range of price changes. This case study indicates that, by setting up the Linear Programming Model,the optimization matching formula can be obtained despite various limitations. Since the material purchasing, coal price, coal amount,payment and the emissions of air pollutants can be estimated in advance, it helps the power plant to set up the annual budget, including material purchasing and sales amount, and therefore to improve the overall operational performance. In addition, Situational Analysis can help power plants to increase the accuracy of investment analysis as they try to ameliorate the equipments or expand the power plant.
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Marett, Lanette Simone. "Trace metal particulates in coal-fired power plant emissions." 2007. http://purl.galileo.usg.edu/uga%5Fetd/marett%5Flanette%5Fs%5F200705%5Fms.
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Chen, Meng-Kan, and 陳孟甘. "Constituents of Coal-Fired Power Plant Flue Gas Characteristic." Thesis, 2013. http://ndltd.ncl.edu.tw/handle/93095442900315862311.
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碩士崑山科技大學
環境工程研究所
101
Taiwan has more than 60% areas dependent on the coal-fired power generation, will produce air pollutants of combustion process and cause the destruction of the environment and the ecosystem, constitutes a serious threat to human health and animal and plant. Through the analysis of exhaust gas composition, to understand the characteristic of the emitted pollutants and their precursor substances, advanced air pollution prevention and control for the coal-fired power generation in the future. Coal main components for carbon, hydrogen, oxygen few of nitrogen, sulfur and other element, sulfur is coal most main impurities one of, usually to sulphides of forms appeared coal of combustion generated material in this research for domestic a coal-fired power plant of smoke road wall crystals, stack flue and smoke flow gas for sampling analysis; crystal detection results found main anionic ingredients for F-, and Cl- and the SO42-; cationic part is to NH4+ and Na+. Testing basic Physical chemistry stack flue exhaust composition differences, dry exhaust average exhaust flow, flow rate, temperature, oxygen, water, carbon dioxide, carbon monoxide and other projects, in different units moving emissions stable. Exhaust emissions of NH3 in the composition and H2SO4 to pipe gas main ingredient, and crystallization of particulate anion and caution SO42-, NH4+ primary characteristic ingredients of consistent results.