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  1. Tracking New Coal-Fired Power Plants

    U.S. Department of Energy (DOE) all webpages (Extended Search)

    January 8, 2010 National Energy Technology Laboratory Office of Systems Analyses and Planning Erik Shuster 2 Tracking New Coal-Fired Power Plants This report is intended to...

  2. Global Coal Fired Power Generation Market | OpenEI Community

    Open Energy Information (Open El) [EERE & EIA]

    Coal Fired Power Generation Market Home There are currently no posts in this category. Syndicate content...

  3. Coal Fired Power Generation Market Forecast | OpenEI Community

    Open Energy Information (Open El) [EERE & EIA]

    Coal Fired Power Generation Market Forecast Home There are currently no posts in this category. Syndicate...

  4. Coal Fired Power Generation Market Trends | OpenEI Community

    Open Energy Information (Open El) [EERE & EIA]

    Coal Fired Power Generation Market Trends Home There are currently no posts in this category. Syndicate...

  5. Coal Fired Power Generation Market Analysis | OpenEI Community

    Open Energy Information (Open El) [EERE & EIA]

    Coal Fired Power Generation Market Analysis Home There are currently no posts in this category. Syndicate...

  6. Coal Fired Power Generation Market Size | OpenEI Community

    Open Energy Information (Open El) [EERE & EIA]

    Coal Fired Power Generation Market Size Home There are currently no posts in this category. Syndicate...

  7. Life Cycle Assessment of Coal-fired Power Production (Technical...

    Office of Scientific and Technical Information (OSTI)

    Life Cycle Assessment of Coal-fired Power Production Citation Details In-Document Search Title: Life Cycle Assessment of Coal-fired Power Production You are accessing a document ...

  8. Thermal energy storage for coal-fired power generation

    SciTech Connect (OSTI)

    Drost, M.K.; Somasundaram, S.; Brown, D.R.; Antoniak, Z.I.

    1990-11-01

    This paper presents an engineering and economic evaluation of using thermal energy storage (TES) with coal-fired conventional and combined cycle power plants. In the first case, conventional pulverized coal combustion equipment was assumed to continuously operate to heat molten nitrate salt which was then stored in a tank. During intermediate-load demand periods, hot salt was withdrawn from storage and used to generate steam for a Rankine steam power cycle. This allowed the coal-fired salt heater to be approximately one-third the size of a coal-fired boiler in a conventional cycling plant. The use of nitrate salt TES also reduced the levelized cost of power by between 5% and 24% depends on the operating schedule. The second case evaluate the use of thermal energy storage with an integrated gasification combined cycle (IGCC) power plant. In this concept, the nitrate salt was heated by a combination of the gas turbine exhaust and the hot fuel gas. The IGCC plant also contained a low-temperature storage unit that uses a mixture of oil and rock as the thermal storage medium. Thermal energy stored in the low-temperature TES was used to preheat the feedwater after it leaves the condenser and to produce process steam for other applications in the IGCC plant. This concept study also predicted a 5% to 20% reduction in levelized cost of power compared to other coal-fired alternatives. If significant escalation rates in the price of fuel were assumed, the concept could be competitive with natural-gas-fired intermediate-load power generation. A sensitivity analysis of using a direct-contact heat exchanger instead of the conventional finned-tube design showed a significant reduction in the installed capital cost. 3 refs., 2 figs., 6 tabs.

  9. Coal-fired high performance power generating system. Final report

    SciTech Connect (OSTI)

    1995-08-31

    As a result of the investigations carried out during Phase 1 of the Engineering Development of Coal-Fired High-Performance Power Generation Systems (Combustion 2000), the UTRC-led Combustion 2000 Team is recommending the development of an advanced high performance power generation system (HIPPS) whose high efficiency and minimal pollutant emissions will enable the US to use its abundant coal resources to satisfy current and future demand for electric power. The high efficiency of the power plant, which is the key to minimizing the environmental impact of coal, can only be achieved using a modern gas turbine system. Minimization of emissions can be achieved by combustor design, and advanced air pollution control devices. The commercial plant design described herein is a combined cycle using either a frame-type gas turbine or an intercooled aeroderivative with clean air as the working fluid. The air is heated by a coal-fired high temperature advanced furnace (HITAF). The best performance from the cycle is achieved by using a modern aeroderivative gas turbine, such as the intercooled FT4000. A simplified schematic is shown. In the UTRC HIPPS, the conversion efficiency for the heavy frame gas turbine version will be 47.4% (HHV) compared to the approximately 35% that is achieved in conventional coal-fired plants. This cycle is based on a gas turbine operating at turbine inlet temperatures approaching 2,500 F. Using an aeroderivative type gas turbine, efficiencies of over 49% could be realized in advanced cycle configuration (Humid Air Turbine, or HAT). Performance of these power plants is given in a table.

  10. LOCAL IMPACTS OF MERCURY EMISSIONS FROM COAL FIRED POWER PLANTS.

    SciTech Connect (OSTI)

    SULLIVAN, T.M.; BOWERMAN, B.; ADAMS, J.; MILIAN, L.; LIPFERT, F.; SUBRAMANIAM, S.; BLAKE, R.

    2005-09-21

    Mercury is a neurotoxin that accumulates in the food chain and is therefore a health concern. The primary human exposure pathway is through fish consumption. Coal-fired power plants emit mercury and there is uncertainty over whether this creates localized hot spots of mercury leading to substantially higher levels of mercury in water bodies and therefore higher exposure. To obtain direct evidence of local deposition patterns, soil and vegetations samples from around three U.S. coal-fired power plants were collected and analyzed for evidence of hot spots and for correlation with model predictions of deposition. At all three sites, there was no correlation between modeled mercury deposition and either soil concentrations or vegetation concentrations. It was estimated that less than 2% of the total mercury emissions from these plants deposited within 15 km of these plants. These small percentages of deposition are consistent with the literature review findings of only minor perturbations in environmental levels, as opposed to hot spots, near the plants. The major objective of the sampling studies was to determine if there was evidence for hot spots of mercury deposition around coal-fired power plants. From a public health perspective, such a hot spot must be large enough to insure that it did not occur by chance, and it must increase mercury concentrations to a level in which health effects are a concern in a water body large enough to support a population of subsistence fishers. The results of this study suggest that neither of these conditions has been met.

  11. Ways to Improve Russian Coal-Fired Power Plants

    SciTech Connect (OSTI)

    Tumanovskii, A. G. Olkhovsky, G. G.

    2015-07-15

    Coal is an important fuel for the electric power industry of Russia, especially in Ural and the eastern part of the country. It is fired in boilers of large (200 – 800 MW) condensing power units and in many cogeneration power plants with units rated at 50 – 180 MW. Many coal-fired power plants have been operated for more than 40 – 50 years. Though serviceable, their equipment is obsolete and does not comply with the current efficiency, environmental, staffing, and availability standards. It is urgent to retrofit and upgrade such power plants using advanced equipment, engineering and business ideas. Russian power-plant engineering companies have designed such advanced power units and their equipment such as boilers, turbines, auxiliaries, process and environmental control systems similar to those produced by the world’s leading manufacturers. Their performance and ways of implementation are discussed.

  12. Controlling mercury emissions from coal-fired power plants

    SciTech Connect (OSTI)

    Chang, R.

    2009-07-15

    Increasingly stringent US federal and state limits on mercury emissions form coal-fired power plants demand optimal mercury control technologies. This article summarises the successful removal of mercury emissions achieved with activated carbon injection and boiler bromide addition, technologies nearing commercial readiness, as well as several novel control concepts currently under development. It also discusses some of the issues standing in the way of confident performance and cost predictions. In testing conducted on western coal-fired units with fabric filters or TOXECON to date, ACI has generally achieved mercury removal rates > 90%. At units with ESPs, similar performance requires brominated ACI. Alternatively, units firing western coals can use boiler bromide addition to increase flue gas mercury oxidation and downstream capture in a wet scrubber, or to enhance mercury removal by ACI. At eastern bituminous fired units with ESPs, ACI is not as effective, largely due to SO{sub 3} resulting from the high sulfur content of the coal or the use of SO{sub 3} flue gas conditioning to improve ESP performance. 7 refs., 3 figs.

  13. LOCAL IMPACTS OF MERCURY EMISSIONS FROM COAL FIRED POWER PLANTS.

    SciTech Connect (OSTI)

    SULLIVAN, T.M.; BOWERMAN, B.; ADAMS, J.; LIPFERT, D.D.; MORRIS, S.M.; BANDO, A.; ET AL.

    2004-03-30

    A thorough quantitative understanding of the processes of mercury emissions, deposition, and translocation through the food chain is currently not available. Complex atmospheric chemistry and dispersion models are required to predict concentration and deposition contributions, and aquatic process models are required to predict effects on fish. There are uncertainties in all of these predictions. Therefore, the most reliable method of understanding impacts of coal-fired power plants on Hg deposition is from empirical data. A review of the literature on mercury deposition around sources including coal-fired power plants found studies covering local mercury concentrations in soil, vegetation, and animals (fish and cows (Lopez et al. 2003)). There is strong evidence of enhanced local deposition within 3 km of the chlor-alkali plants, with elevated soil concentrations and estimated deposition rates of 10 times background. For coal-fired power plants, the data show that atmospheric deposition of Hg may be slightly enhanced. On the scale of a few km, modeling suggests that wet deposition may be increased by a factor of two or three over background. The measured data suggest lower increases of 15% or less. The effects of coal-fired plants seem to be less than 10% of total deposition on a national scale, based on emissions and global modeling. The following summarizes our findings from published reports on the impacts of local deposition. In terms of excesses over background the following increments have been observed within a few km of the plant: (1) local soil concentration Hg increments of 30%-60%, (2) sediment increments of 18-30%, (3) wet deposition increments of 11-12%, and (4) fish Hg increments of about 5-6%, based on an empirical finding that fish concentrations are proportional to the square root of deposition. Important uncertainties include possible reductions of RGM to Hg(0) in power plant plumes and the role of water chemistry in the relationship between Hg

  14. Impacts of TMDLs on coal-fired power plants.

    SciTech Connect (OSTI)

    Veil, J. A.; Environmental Science Division

    2010-04-30

    The Clean Water Act (CWA) includes as one of its goals restoration and maintenance of the chemical, physical, and biological integrity of the Nation's waters. The CWA established various programs to accomplish that goal. Among the programs is a requirement for states to establish water quality standards that will allow protection of the designated uses assigned to each water body. Once those standards are set, state agencies must sample the water bodies to determine if water quality requirements are being met. For those water bodies that are not achieving the desired water quality, the state agencies are expected to develop total maximum daily loads (TMDLs) that outline the maximum amount of each pollutant that can be discharged to the water body and still maintain acceptable water quality. The total load is then allocated to the existing point and nonpoint sources, with some allocation held in reserve as a margin of safety. Many states have already developed and implemented TMDLs for individual water bodies or regional areas. New and revised TMDLs are anticipated, however, as federal and state regulators continue their examination of water quality across the United States and the need for new or revised standards. This report was funded by the U.S. Department of Energy's (DOE's) National Energy Technology Laboratory (NETL) Existing Plants Research Program, which has an energy-water research effort that focuses on water use at power plants. This study complements its overall research effort by evaluating water issues that could impact power plants. One of the program missions of the DOE's NETL is to develop innovative environmental control technologies that will enable full use of the Nation's vast coal reserves, while at the same time allowing the current fleet of coal-fired power plants to comply with existing and emerging environmental regulations. Some of the parameters for which TMDLs are being developed are components in discharges from coal-fired power

  15. Repowering a small coal-fired power plant

    SciTech Connect (OSTI)

    Miell, R.

    2007-11-15

    The Arkansas River Power Authority (ARPA) Lamar Repowering Project is moving forward. The new generator, capable of producing 18 MW of electricity, is scheduled to be online in June 2008 bringing the total generation to 43 MW. New coal handling equipment, with infrared fire detectors, is almost complete. The new 18 MW steam turbine will be cooled by an air-cooled condenser. Coal will be delivered in a railroad spur to an unloading site then be unloaded onto a conveyor under the tracks and conveyed to two storage domes each holding 6000 tons of coal. It will be drawn out of these through an underground conveyor system, brought into a crusher, conveyed through overhead conveyors and fed into the new coal- fired fluidized bed boilers. 1 photo.

  16. Water vulnerabilities for existing coal-fired power plants.

    SciTech Connect (OSTI)

    Elcock, D.; Kuiper, J.; Environmental Science Division

    2010-08-19

    This report was funded by the U.S. Department of Energy's (DOE's) National Energy Technology Laboratory (NETL) Existing Plants Research Program, which has an energy-water research effort that focuses on water use at power plants. This study complements the Existing Plants Research Program's overall research effort by evaluating water issues that could impact power plants. Water consumption by all users in the United States over the 2005-2030 time period is projected to increase by about 7% (from about 108 billion gallons per day [bgd] to about 115 bgd) (Elcock 2010). By contrast, water consumption by coal-fired power plants over this period is projected to increase by about 21% (from about 2.4 to about 2.9 bgd) (NETL 2009b). The high projected demand for water by power plants, which is expected to increase even further as carbon-capture equipment is installed, combined with decreasing freshwater supplies in many areas, suggests that certain coal-fired plants may be particularly vulnerable to potential water demand-supply conflicts. If not addressed, these conflicts could limit power generation and lead to power disruptions or increased consumer costs. The identification of existing coal-fired plants that are vulnerable to water demand and supply concerns, along with an analysis of information about their cooling systems and related characteristics, provides information to help focus future research and development (R&D) efforts to help ensure that coal-fired generation demands are met in a cost-effective manner that supports sustainable water use. This study identified coal-fired power plants that are considered vulnerable to water demand and supply issues by using a geographical information system (GIS) that facilitated the analysis of plant-specific data for more than 500 plants in the NETL's Coal Power Plant Database (CPPDB) (NETL 2007a) simultaneously with 18 indicators of water demand and supply. Two types of demand indicators were evaluated. The first type

  17. Water Extraction from Coal-Fired Power Plant Flue Gas

    SciTech Connect (OSTI)

    Bruce C. Folkedahl; Greg F. Weber; Michael E. Collings

    2006-06-30

    The overall objective of this program was to develop a liquid disiccant-based flue gas dehydration process technology to reduce water consumption in coal-fired power plants. The specific objective of the program was to generate sufficient subscale test data and conceptual commercial power plant evaluations to assess process feasibility and merits for commercialization. Currently, coal-fired power plants require access to water sources outside the power plant for several aspects of their operation in addition to steam cycle condensation and process cooling needs. At the present time, there is no practiced method of extracting the usually abundant water found in the power plant stack gas. This project demonstrated the feasibility and merits of a liquid desiccant-based process that can efficiently and economically remove water vapor from the flue gas of fossil fuel-fired power plants to be recycled for in-plant use or exported for clean water conservation. After an extensive literature review, a survey of the available physical and chemical property information on desiccants in conjunction with a weighting scheme developed for this application, three desiccants were selected and tested in a bench-scale system at the Energy and Environmental Research Center (EERC). System performance at the bench scale aided in determining which desiccant was best suited for further evaluation. The results of the bench-scale tests along with further review of the available property data for each of the desiccants resulted in the selection of calcium chloride as the desiccant for testing at the pilot-scale level. Two weeks of testing utilizing natural gas in Test Series I and coal in Test Series II for production of flue gas was conducted with the liquid desiccant dehumidification system (LDDS) designed and built for this study. In general, it was found that the LDDS operated well and could be placed in an automode in which the process would operate with no operator intervention or

  18. Coal-fired high performance power generating system

    SciTech Connect (OSTI)

    Not Available

    1992-07-01

    The goals of the program are to develop a coal-fired high performance power generation system (HIPPS) by the year 2000 that is capable of > 47% thermal efficiency; NO[sub x] SO [sub x] and Particulates < 25% NSPS; Cost of electricity 10% lower; coal > 65% of heat input and all solid wastes benign. In order to achieve these goals our team has outlined a research plan based on an optimized analysis of a 250 MW[sub e] combined cycle system applicable to both frame type and aeroderivative gas turbines. Under the constraints of the cycle analysis we have designed a high temperature advanced furnace (HITAF) which integrates several combustor and air heater designs with appropriate ash management procedures. Most of this report discusses the details of work on these components, and the R D Plan for future work. The discussion of the combustor designs illustrates how detailed modeling can be an effective tool to estimate NO[sub x] production, minimum burnout lengths, combustion temperatures and even particulate impact on the combustor walls. When our model is applied to the long flame concept it indicates that fuel bound nitrogen will limit the range of coals that can use this approach. For high nitrogen coals a rapid mixing, rich-lean, deep staging combustor will be necessary. The air heater design has evolved into two segments: a convective heat exchanger downstream of the combustion process; a radiant panel heat exchanger, located in the combustor walls; The relative amount of heat transferred either radiatively or convectively will depend on the combustor type and the ash properties.

  19. DOE Seeks Projects to Advance Carbon Dioxide Utilization from Coal-Fired Power Plants

    Office of Energy Efficiency and Renewable Energy (EERE)

    The U.S. Department of Energy (DOE) has announced approximately $6.7 million in federal funding for cost-shared projects that will develop technologies that utilize carbon dioxide (CO2) from coal-fired power plants to produce useful products.

  20. Emissions, Monitoring, and Control of Mercury from Subbituminous Coal-Fired Power Plants - Phase II

    SciTech Connect (OSTI)

    Alan Bland; Jesse Newcomer; Allen Kephart; Volker Schmidt; Gerald Butcher

    2008-10-31

    Western Research Institute (WRI), in conjunction with Western Farmers Electric Cooperative (WFEC), has teamed with Clean Air Engineering of Pittsburgh PA to conduct a mercury monitoring program at the WEFC Hugo plant in Oklahoma. Sponsored by US Department of Energy Cooperative Agreement DE-FC-26-98FT40323, the program included the following members of the Subbituminous Energy Coalition (SEC) as co-sponsors: Missouri Basin Power Project; DTE Energy; Entergy; Grand River Dam Authority; and Nebraska Public Power District. This research effort had five objectives: (1) determine the mass balance of mercury for subbituminous coal-fired power plant; (2) assess the distribution of mercury species in the flue gas (3) perform a comparison of three different Hg test methods; (4) investigate the long-term (six months) mercury variability at a subbituminous coal-fired power plant; and (5) assess operation and maintenance of the Method 324 and Horiba CEMS utilizing plant personnel.

  1. ATMOSPHERIC AEROSOL SOURCE-RECEPTOR RELATIONSHIPS: THE ROLE OF COAL-FIRED POWER PLANTS

    SciTech Connect (OSTI)

    Allen L. Robinson; Spyros N. Pandis; Cliff I. Davidson

    2004-12-01

    This report describes the technical progress made on the Pittsburgh Air Quality Study (PAQS) during the period of March 2004 through August 2004. Significant progress was made this project period on the analysis of ambient data, source apportionment, and deterministic modeling activities. Results highlighted in this report include evaluation of the performance of PMCAMx+ for an air pollution episode in the Eastern US, an emission profile for a coke production facility, ultrafine particle composition during a nucleation event, and a new hybrid approach for source apportionment. An agreement was reached with a utility to characterize fine particle and mercury emissions from a commercial coal fired power. Research in the next project period will include source testing of a coal fired power plant, source apportionment analysis, emission scenario modeling with PMCAMx+, and writing up results for submission as journal articles.

  2. Modeling of integrated environmental control systems for coal-fired power plants

    SciTech Connect (OSTI)

    Rubin, E.S.

    1988-10-01

    This is the fourth quarterly report of DOE Contract No. DE-AC22-87PC79864, entitled Modeling of Integrated Environmental Control Systems for Coal-Fired Power Plants.'' This report summarizes accomplishments during the period July 1, 1988 to September 30, 1988. Our efforts during the last quarter focused primarily on the completion, testing and documentation of the NO{sub x}SO process model. The sections below present the details of these developments.

  3. Gas turbines for coal-fired turbocharged PFBC boiler power plants

    SciTech Connect (OSTI)

    Wenglarz, R.; Drenker, S.

    1984-11-01

    A coal-fired turbocharged boiler using fluidized bed combustion at high pressure would be more compact than a pulverized coal fired boiler. The smaller boiler size could permit the utility industry to adopt efficient modular construction methods now widely used in other industries. A commercial turbocharger of the capacity needed to run a 250 MW /SUB e/ power plant does not exist; commercial gas turbines of the correct capacity exist, but they are not matched to this cycle's gas temperature of less than 538/sup 0/C (1000/sup 0/F). In order to avoid impeding the development of the technology, it will probably be desirable to use existing machines to the maximum extent possible. This paper explores the advantages and disadvantages of applying either standard gas turbines or modified standard gas turbines to the turbocharged boiler.

  4. Technical and economic assessment on coal-fired power generation...

    Office of Scientific and Technical Information (OSTI)

    ... Subject: 01 COAL, LIGNITE, AND PEAT; 20 FOSSIL-FUELED POWER PLANTS; CHINA; FOSSIL-FUEL POWER PLANTS; SULFUR DIOXIDE; AIR POLLUTION CONTROL; FLUE GAS; DESULFURIZATION; WASTE ...

  5. Coal-fired power generation: Proven technologies and pollution control systems

    SciTech Connect (OSTI)

    Balat, M.

    2008-07-01

    During the last two decades, significant advances have been made in the reduction of emissions from coal-fired power generating plants. New technologies include better understanding of the fundamentals of the formation and destruction of criteria pollutants in combustion processes (low nitrogen oxides burners) and improved methods for separating criteria pollutants from stack gases (FGD technology), as well as efficiency improvements in power plants (clean coal technologies). Future demand for more environmentally benign electric power, however, will lead to even more stringent controls of pollutants (sulphur dioxide and nitrogen oxides) and greenhouse gases such as carbon dioxide.

  6. Water recovery using waste heat from coal fired power plants.

    SciTech Connect (OSTI)

    Webb, Stephen W.; Morrow, Charles W.; Altman, Susan Jeanne; Dwyer, Brian P.

    2011-01-01

    The potential to treat non-traditional water sources using power plant waste heat in conjunction with membrane distillation is assessed. Researchers and power plant designers continue to search for ways to use that waste heat from Rankine cycle power plants to recover water thereby reducing water net water consumption. Unfortunately, waste heat from a power plant is of poor quality. Membrane distillation (MD) systems may be a technology that can use the low temperature waste heat (<100 F) to treat water. By their nature, they operate at low temperature and usually low pressure. This study investigates the use of MD to recover water from typical power plants. It looks at recovery from three heat producing locations (boiler blow down, steam diverted from bleed streams, and the cooling water system) within a power plant, providing process sketches, heat and material balances and equipment sizing for recovery schemes using MD for each of these locations. It also provides insight into life cycle cost tradeoffs between power production and incremental capital costs.

  7. LOCAL IMPACTS OF MERCURY EMISSIONS FROM THE MONTICELLO COAL FIRED POWER PLANT.

    SciTech Connect (OSTI)

    SULLIVAN, T.M.; ADAMS, J.; MILIAN, L.; SUBRAMANIAN, S.; FEAGIN, L.; WILLIAMS, J.; BOYD, A.

    2006-10-31

    The Clean Air Interstate Rule (CAIR) and the Clean Air Mercury Rule (CAMR) as currently proposed by the U.S. Environmental Protection Agency (EPA) when fully implemented will lead to reduction in mercury emissions from coal-fired power plants by 70 percent to fifteen tons per year by 2018. The EPA estimates that mercury deposition would be reduced 8 percent on average in the Eastern United States. The CAMR permits cap-and-trade approach that requires the nationwide emissions to meet the prescribed level, but do not require controls on each individual power plant. This has led to concerns that there may be hot-spots of mercury contamination near power plants. Partially because of this concern, many states including Pennsylvania have implemented, or are considering, state regulations that are stricter on mercury emissions than those in the CAMR. This study examined the possibility that coal-fired power plants act as local sources leading to mercury ''hot spots'', using two types of evidence. First, the world-wide literature was searched for reports of deposition around mercury sources, including coal-fired power plants. Second, soil samples from around two mid-sized U.S. coal-fired power plants were collected and analyzed for evidence of ''hot spots'' and for correlation with model predictions of deposition. The following summarizes our findings from published reports on the impacts of local deposition. In terms of excesses over background the following increments have been observed within a few km of the plant: (A) local soil concentration Hg increments of 30%-60%, (B) sediment increments of 18-30%, (C) wet deposition increments of 11-12%, and (D) fish Hg increments of about 5-6%, based on an empirical finding that fish concentrations are proportional to the square root of deposition. Important uncertainties include possible reductions of RGM to Hg(0) in power plant plumes and the role of water chemistry in the relationship between Hg deposition and fish content

  8. Automated remote control of fuel supply section for the coal fired power plant

    SciTech Connect (OSTI)

    Chudin, O.V.; Maidan, B.V.; Tsymbal, A.A.

    1996-05-01

    Approximately 6,000 miles east of Moscow, lays the city of Khabarovsk. This city`s coal-fired Power Plant 3 supplies electricity, heat and hot water to approximately 250,000 customers. Plant 3 has three units with a combined turbine capacity of 540 MW, (3 {times} 180) electrical and 780 (3 {times} 260) Gkal an hour thermal capacity with steam productivity of 2010 (3 {times} 670) tons per hour at 540 C. Coal fired thermal electric power plants rely on the equipment of the fuel supply section. The mechanism of the fuel supply section includes: conveyor belts, hammer crushers, guiding devices, dumping devices, systems for dust neutralizing, iron separators, metal detectors and other devices. As a rule, the fuel path in the power plant has three main directions: from the railroad car unloading terminal to the coal warehouse; from the coal warehouse to the acceptance bunkers of the power units, and the railroad car unloading terminal to the acceptance bunkers of power units. The fuel supply section always has a reserve and is capable of uninterruptible fuel supply during routine maintenance and/or repair work. This flexibility requires a large number of fuel traffic routes, some of which operate simultaneously with the feeding of coal from the warehouse to the acceptance bunkers of the power units, or in cases when rapid filling of the bunkers is needed, two fuel supply routes operate at the same time. The remote control of the fuel handling system at Power Plant 3 is described.

  9. Best practices in environmental monitoring for coal-fired power plants: lessons for developing Asian APEC economies

    SciTech Connect (OSTI)

    Holt, N.; Findsen, J.

    2008-11-15

    The report assesses environmental monitoring and reporting by individual coal-fired power plants, makes recommendations regarding how monitoring should be applied, and evaluates the interrelationship of monitoring and regulation in promoting CCTs. Effective monitoring is needed to ensure that power plants are performing as expected, and to confirm that they are complying with applicable environmental regulations. Older coal-fired power plants in APEC economies often have limited monitoring capabilities, making their environmental performance difficult to measure. 585 refs., 5 figs., 85 tabs.

  10. Local Impacts of Mercury Emissions from the Three Pennsylvania Coal Fired Power Plants.

    SciTech Connect (OSTI)

    Sullivan,T.; Adams,J.; Bender, M.; Bu, C.; Piccolo, N.; Campbell, C.

    2008-02-01

    The Clean Air Interstate Rule (CAIR) and the Clean Air Mercury Rule (CAMR) as proposed by the U.S. Environmental Protection Agency (EPA) when fully implemented will lead to reduction in mercury emissions from coal-fired power plants by 70 percent to fifteen tons per year by 2018. The EPA estimates that mercury deposition would be reduced 8 percent on average in the Eastern United States. The CAMR permits cap-and-trade approach that requires the nationwide emissions to meet the prescribed level, but do not require controls on each individual power plant. This has led to concerns that there may be hot-spots of mercury contamination near power plants. Partially because of this concern, many states including Pennsylvania have implemented, or are considering, state regulations that are stricter on mercury emissions than those in the CAMR. This study examined the possibility that coal-fired power plants act as local sources leading to mercury 'hot spots'. Soil and oak leaf samples from around three large U.S. coal-fired power plants in Western Pennsylvania were collected and analyzed for evidence of 'hot spots'. These three plants (Conemaugh, Homer City, and Keystone) are separated by a total distance of approximately 30 miles. Each emits over 500 pounds of mercury per year which is well above average for mercury emissions from coal plants in the U.S. Soil and oak leaf sampling programs were performed around each power plant. Sampling rings one-mile apart were used with eight or nine locations on each ring. The prevailing winds in the region are from the west. For this reason, sampling was conducted out to 10 miles from the Conemaugh plant which is southeast of the others. The other plants were sampled to a distance of five miles. The objectives were to determine if local mercury hot spots exist, to determine if they could be attributed to deposition of coal-fired power plant emissions, and to determine if they correlated with wind patterns. The study found the following

  11. Potential nanotechnology applications for reducing freshwater consumption at coal fired power plants : an early view.

    SciTech Connect (OSTI)

    Elcock, D.

    2010-09-17

    This report was funded by the U.S. Department of Energy's (DOE's) National Energy Technology Laboratory (NETL) Existing Plants Research Program, which has an energy-water research effort that focuses on water use at power plants. This study complements the overall research effort of the Existing Plants Research Program by evaluating water issues that could impact power plants. A growing challenge to the economic production of electricity from coal-fired power plants is the demand for freshwater, particularly in light of the projected trends for increasing demands and decreasing supplies of freshwater. Nanotechnology uses the unique chemical, physical, and biological properties that are associated with materials at the nanoscale to create and use materials, devices, and systems with new functions and properties. It is possible that nanotechnology may open the door to a variety of potentially interesting ways to reduce freshwater consumption at power plants. This report provides an overview of how applications of nanotechnology could potentially help reduce freshwater use at coal-fired power plants. It was developed by (1) identifying areas within a coal-fired power plant's operations where freshwater use occurs and could possibly be reduced, (2) conducting a literature review to identify potential applications of nanotechnology for facilitating such reductions, and (3) collecting additional information on potential applications from researchers and companies to clarify or expand on information obtained from the literature. Opportunities, areas, and processes for reducing freshwater use in coal-fired power plants considered in this report include the use of nontraditional waters in process and cooling water systems, carbon capture alternatives, more efficient processes for removing sulfur dioxide and nitrogen oxides, coolants that have higher thermal conductivities than water alone, energy storage options, and a variety of plant inefficiencies, which, if improved

  12. ECONOMICS AND FEASIBILITY OF RANKINE CYCLE IMPROVEMENTS FOR COAL FIRED POWER PLANTS

    SciTech Connect (OSTI)

    Richard E. Waryasz; Gregory N. Liljedahl

    2004-09-08

    ALSTOM Power Inc.'s Power Plant Laboratories (ALSTOM) has teamed with the U.S. Department of Energy National Energy Technology Laboratory (DOE NETL), American Electric Company (AEP) and Parsons Energy and Chemical Group to conduct a comprehensive study evaluating coal fired steam power plants, known as Rankine Cycles, equipped with three different combustion systems: Pulverized Coal (PC), Circulating Fluidized Bed (CFB), and Circulating Moving Bed (CMB{trademark}). Five steam cycles utilizing a wide range of steam conditions were used with these combustion systems. The motivation for this study was to establish through engineering analysis, the most cost-effective performance potential available through improvement in the Rankine Cycle steam conditions and combustion systems while at the same time ensuring that the most stringent emission performance based on CURC (Coal Utilization Research Council) 2010 targets are met: > 98% sulfur removal; < 0.05 lbm/MM-Btu NO{sub x}; < 0.01 lbm/MM-Btu Particulate Matter; and > 90% Hg removal. The final report discusses the results of a coal fired steam power plant project, which is comprised of two parts. The main part of the study is the analysis of ten (10) Greenfield steam power plants employing three different coal combustion technologies: Pulverized Coal (PC), Circulating Fluidized Bed (CFB), and Circulating Moving Bed (CMB{trademark}) integrated with five different steam cycles. The study explores the technical feasibility, thermal performance, environmental performance, and economic viability of ten power plants that could be deployed currently, in the near, intermediate, and long-term time frame. For the five steam cycles, main steam temperatures vary from 1,000 F to 1,292 F and pressures from 2,400 psi to 5,075 psi. Reheat steam temperatures vary from 1,000 F to 1,328 F. The number of feedwater heaters varies from 7 to 9 and the associated feedwater temperature varies from 500 F to 626 F. The main part of the study

  13. Life assessment and emissions monitoring of Indian coal-fired power plants. Final report

    SciTech Connect (OSTI)

    Not Available

    1992-07-01

    At the request of the Pittsburgh Energy Technology Center (PETC) of the United States Department of Energy (USDOE), the traveler, along with Dr. R. P. Krishnan, Oak Ridge National Laboratory (ORNL), Oak Ridge, Tennessee spent three weeks in India planning and performing emissions monitoring at the coal-fired Vijayawada Thermal Power Station (VTPS). The coordination for the Indian participants was provided by BHEL, Trichy and CPRI, Bangalore. The trip was sponsored by the PETC under the United States Agency for International Development (USAID)/Government of India (GOI)P Alternate Energy Resources Development (AERD) Project. The AERD Project is managed by PETC, and ORNL is providing the technical coordination and support for four coal projects that are being implemented with BHEL, Trichy. The traveler, after briefing the USAID mission in New Delhi visited BHEL, Trichy and CPRI, Bangalore to coordinate and plan the emissions test program. The site selection was made by BHEL, CPRI, TVA, and PETC. Monitoring was performed for 4 days on one of the 4 existing 210 MW coal-fired boilers at the VTPS, 400 km north of Madras, India.

  14. Life assessment and emissions monitoring of Indian coal-fired power plants

    SciTech Connect (OSTI)

    Not Available

    1992-07-01

    At the request of the Pittsburgh Energy Technology Center (PETC) of the United States Department of Energy (USDOE), the traveler, along with Dr. R. P. Krishnan, Oak Ridge National Laboratory (ORNL), Oak Ridge, Tennessee spent three weeks in India planning and performing emissions monitoring at the coal-fired Vijayawada Thermal Power Station (VTPS). The coordination for the Indian participants was provided by BHEL, Trichy and CPRI, Bangalore. The trip was sponsored by the PETC under the United States Agency for International Development (USAID)/Government of India (GOI)P Alternate Energy Resources Development (AERD) Project. The AERD Project is managed by PETC, and ORNL is providing the technical coordination and support for four coal projects that are being implemented with BHEL, Trichy. The traveler, after briefing the USAID mission in New Delhi visited BHEL, Trichy and CPRI, Bangalore to coordinate and plan the emissions test program. The site selection was made by BHEL, CPRI, TVA, and PETC. Monitoring was performed for 4 days on one of the 4 existing 210 MW coal-fired boilers at the VTPS, 400 km north of Madras, India.

  15. ENGINEERING DEVELOPMENT OF COAL-FIRED HIGH PERFORMANCE POWER SYSTEMS PHASE II AND III

    SciTech Connect (OSTI)

    1998-09-30

    This report presents work carried out under contract DE-AC22-95PC95144 "Engineering Development of Coal-Fired High Performance Systems Phase II and III." The goals of the program are to develop a coal-fired high performance power generation system (HIPPS) that is capable of: à thermal efficiency (HHV) >47%; à NOx, SOx, and particulates <10% NSPS (New Source Performance Standard); à coal providing >65% of heat input; à all solid wastes benign; à cost of electricity <90% of present plants. Phase I, which began in 1992, focused on the analysis of various configurations of indirectly fired cycles and on technical assessments of alternative plant subsystems and components, including performance requirements, developmental status, design options, complexity and reliability, and capital and operating costs. Phase I also included preliminary R&D and the preparation of designs for HIPPS commercial plants approximately 300 MWe in size. This phase, Phase II, involves the development and testing of plant subsystems, refinement and updating of the HIPPS commercial plant design, and the site selection and engineering design of a HIPPS prototype plant. Work reported herein is from: à Task 2.2 HITAF Air Heaters; à Task 6 HIPPS Commercial Plant Design Update.

  16. McHuchuma/Katewaka coal fired power plant feasibility study. Final report. Export trade information

    SciTech Connect (OSTI)

    1996-11-22

    This study, conducted by Black and Veatch International, was funded by the U.S. Trade and Development Agency. The report assesses the feasibility for the development of a new coal fueled power plant in Tanzania at the Mchuchuma/Katewaka coal concession area. Volume 3, the Main Report, is divided into the following sections: (1.0) Introduction; (2.0) Power System Development Studies; (3.0) Conceptual Design Summary of the Mchuchuma Coal Fired Power Plant; (4.0) Fuel Supply Evaluation; (5.0) Transmission System Evaluation; (6.0) Power Plant Site and Infrastructure Evaluation; (7.0) Environmental Impact Assessment; (8.0) Institutional Aspects; (9.0) Financial Evaluation and Benefit Analysis; (10.0) Sources of Finance; Appendix (A) Preliminary Design of Mchuchuma Coal Plant.

  17. Emissions, Monitoring and Control of Mercury from Subbituminous Coal-Fired Power Plants

    SciTech Connect (OSTI)

    Alan Bland; Kumar Sellakumar; Craig Cormylo

    2007-08-01

    The Subbituminous Energy Coalition (SEC) identified a need to re-test stack gas emissions from power plants that burn subbituminous coal relative to compliance with the EPA mercury control regulations for coal-fired plants. In addition, the SEC has also identified the specialized monitoring needs associated with mercury continuous emissions monitors (CEM). The overall objectives of the program were to develop and demonstrate solutions for the unique emission characteristics found when burning subbituminous coals. The program was executed in two phases; Phase I of the project covered mercury emission testing programs at ten subbituminous coal-fired plants. Phase II compared the performance of continuous emission monitors for mercury at subbituminous coal-fired power plants and is reported separately. Western Research Institute and a number of SEC members have partnered with Eta Energy and Air Pollution Testing to assess the Phase I objective. Results of the mercury (Hg) source sampling at ten power plants burning subbituminous coal concluded Hg emissions measurements from Powder River Basin (PBR) coal-fired units showed large variations during both ICR and SEC testing. Mercury captures across the Air Pollution Control Devices (APCDs) present much more reliable numbers (i.e., the mercury captures across the APCDs are positive numbers as one would expect compared to negative removal across the APCDs for the ICR data). Three of the seven units tested in the SEC study had previously shown negative removals in the ICR testing. The average emission rate is 6.08 lb/TBtu for seven ICR units compared to 5.18 lb/TBtu for ten units in the SEC testing. Out of the ten (10) SEC units, Nelson Dewey Unit 1, burned a subbituminous coal and petcoke blend thus lowering the total emission rate by generating less elemental mercury. The major difference between the ICR and SEC data is in the APCD performance and the mercury closure around the APCD. The average mercury removal values

  18. MERCURY EMISSIONS FROM COAL FIRED POWER PLANTS LOCAL IMPACTS ON HUMAN HEALTH RISK.

    SciTech Connect (OSTI)

    SULLIVAN, T.M.; BOWERMAN, B.; ADAMS, J.; LIPFERT, F.; MORRIS, S.M.; BANDO, A.; PENA, R.; BLAKE, R.

    2005-12-01

    A thorough quantitative understanding of the processes of mercury emissions, deposition, and translocation through the food chain is currently not available. Complex atmospheric chemistry and dispersion models are required to predict concentration and deposition contributions, and aquatic process models are required to predict effects on fish. However, there are uncertainties in all of these predictions. Therefore, the most reliable method of understanding impacts of coal-fired power plants on Hg deposition is from empirical data. A review of the literature on mercury deposition around sources including coal-fired power plants found studies covering local mercury concentrations in soil, vegetation, and animals (fish and cows). There is strong evidence of enhanced local deposition within 3 km of the chlor-alkali plants, with elevated soil concentrations and estimated deposition rates of 10 times background. For coal-fired power plants, the data show that atmospheric deposition of Hg may be slightly enhanced. On the scale of a few km, modeling suggests that wet deposition may be increased by a factor of two or three over background. The measured data suggest lower increases of 15% or less. The effects of coal-fired plants seem to be less than 10% of total deposition on a national scale, based on emissions and global modeling. The following summarizes our findings from published reports on the impacts of local deposition. In terms of excesses over background the following increments have been observed within a few km of the plant: (1) local soil concentration Hg increments of 30%-60%, (2) sediment increments of 18-30%, (3) wet deposition increments of 11-12%, and (4) fish Hg increments of about 5-6%, based on an empirical finding that fish concentrations are proportional to the square root of deposition. Important uncertainties include possible reductions of RGM to Hg{sub 0} in power plant plumes and the role of water chemistry in the relationship between Hg

  19. Small, modular, low-cost coal-fired power plants for the international market

    SciTech Connect (OSTI)

    Zauderer, B.; Frain, B.; Borck, B.; Baldwin, A.L.

    1997-12-31

    This paper presents recent operating results of Coal Tech`s second generation, air cooled, slagging coal combustor, and its application to power plants in the 1 to 20 MW range. This 20 MMBtu/hour combustor was installed in a new demonstration plant in Philadelphia, PA in 1995. It contains the combustion components of a 1 MWe coal fired power plant, a 17,500 lb/hour steam boiler, coal storage and feed components, and stack gas cleanup components. The plant`s design incorporates improvements resulting from 2,000 hours of testing between 1987 and 1993 on a first generation, commercial scale, air cooled combustor of equal thermal rating. Since operations began in early 1996, a total of 51 days of testing have been successfully completed. Major results include durability of the combustor`s refractory wall, excellent combustion with high ash concentration in the fuel, removal of 95% to 100% of the slag in the combustor, very little ash deposition in the boiler, major reduction of in-plant parasitic power, and simplified power system control through the use of modular designs of sub-systems and computer control. Rapid fuel switching between oil, gas, and coal and turndown of up to a factor of three was accomplished. All these features have been incorporated in advanced coal fired plant designs in the 1 to 20 MWe range. Incremental capital costs are only $100 to $200/kW higher than comparable rated gas or oil fired steam generating systems. Most of its components and subsystems can be factory assembled for very rapid field installation. The low capital, low operating costs, fuel flexibility, and compatibility with very high ash fuels, make this power system very attractive in regions of the world having domestic supplies of these fuels.

  20. Comprehensive assessment of toxic emissions from coal-fired power plants

    SciTech Connect (OSTI)

    Brown, T D; Schmidt, C E; Radziwon, A S

    1991-01-01

    The Pittsburgh Energy Technology Center (PETC) of the US Department of Energy (DOE) has two current investigations, initiated before passage of the Clean Air Act Amendment (CAAA), that will determine the air toxic emissions from coal-fired electric utilities. DOE has contracted with Battelle Memorial Institute and Radian corporation to conduct studies focusing on the potential air toxics, both organic and inorganic, associated with different size fractions of fine particulate matter emitted from power plant stacks. Table 2 indicates the selected analytes to be investigated during these studies. PETC is also developing guidance on the monitoring of Hazardous Air Pollutants (HAPS) to be incorporated in the Environmental Monitoring plans for the demonstration projects in its Clean Coal Technology Program.

  1. Modeling of integrated environmental control systems for coal-fired power plants

    SciTech Connect (OSTI)

    Rubin, E.S.

    1989-10-01

    The general goal of this research project is to enhance, and transfer to DOE, a new computer simulation model for analyzing the performance and cost of environmental control systems for coal-fired power plants. Systems utilizing pre-combustion, combustion, or post-combustion control methods, individually or in combination, may be considered. A unique capability of this model is the probabilistic representation of uncertainty in model input parameters. This stochastic simulation capability allows the performance and cost of environmental control systems to be quantified probabilistically, accounting for the interactions among all uncertain process and economic parameters. This method facilitates more rigorous comparisons between conventional and advanced clean coal technologies promising improved cost and/or effectiveness for SO{sub 2} and NO{sub x} removal. Detailed modeling of several pre-combustion and post-combustion processes of interest to DOE/PETC have been selected for analysis as part of this project.

  2. Modeling of integrated environmental control systems for coal-fired power plants. Final report

    SciTech Connect (OSTI)

    Rubin, E.S.; Salmento, J.S.; Frey, H.C.; Abu-Baker, A.; Berkenpas, M.

    1991-05-01

    The Integrated Environmental Control Model (IECM) was designed to permit the systematic evaluation of environmental control options for pulverized coal-fired (PC) power plants. Of special interest was the ability to compare the performance and cost of advanced pollution control systems to ``conventional`` technologies for the control of particulate, SO{sub 2} and NO{sub x}. Of importance also was the ability to consider pre-combustion, combustion and post-combustion control methods employed alone or in combination to meet tough air pollution emission standards. Finally, the ability to conduct probabilistic analyses is a unique capability of the IECM. Key results are characterized as distribution functions rather than as single deterministic values. (VC)

  3. Modeling of integrated environmental control systems for coal-fired power plants

    SciTech Connect (OSTI)

    Rubin, E.S.; Salmento, J.S.; Frey, H.C.; Abu-Baker, A.; Berkenpas, M.

    1991-05-01

    The Integrated Environmental Control Model (IECM) was designed to permit the systematic evaluation of environmental control options for pulverized coal-fired (PC) power plants. Of special interest was the ability to compare the performance and cost of advanced pollution control systems to conventional'' technologies for the control of particulate, SO{sub 2} and NO{sub x}. Of importance also was the ability to consider pre-combustion, combustion and post-combustion control methods employed alone or in combination to meet tough air pollution emission standards. Finally, the ability to conduct probabilistic analyses is a unique capability of the IECM. Key results are characterized as distribution functions rather than as single deterministic values. (VC)

  4. Reducing water freshwater consumption at coal-fired power plants : approaches used outside the United States.

    SciTech Connect (OSTI)

    Elcock, D.

    2011-05-09

    Coal-fired power plants consume huge quantities of water, and in some water-stressed areas, power plants compete with other users for limited supplies. Extensive use of coal to generate electricity is projected to continue for many years. Faced with increasing power demands and questionable future supplies, industries and governments are seeking ways to reduce freshwater consumption at coal-fired power plants. As the United States investigates various freshwater savings approaches (e.g., the use of alternative water sources), other countries are also researching and implementing approaches to address similar - and in many cases, more challenging - water supply and demand issues. Information about these non-U.S. approaches can be used to help direct near- and mid-term water-consumption research and development (R&D) activities in the United States. This report summarizes the research, development, and deployment (RD&D) status of several approaches used for reducing freshwater consumption by coal-fired power plants in other countries, many of which could be applied, or applied more aggressively, at coal-fired power plants in the United States. Information contained in this report is derived from literature and Internet searches, in some cases supplemented by communication with the researchers, authors, or equipment providers. Because there are few technical, peer-reviewed articles on this topic, much of the information in this report comes from the trade press and other non-peer-reviewed references. Reducing freshwater consumption at coal-fired power plants can occur directly or indirectly. Direct approaches are aimed specifically at reducing water consumption, and they include dry cooling, dry bottom ash handling, low-water-consuming emissions-control technologies, water metering and monitoring, reclaiming water from in-plant operations (e.g., recovery of cooling tower water for boiler makeup water, reclaiming water from flue gas desulfurization [FGD] systems), and

  5. Membrane Process to Capture CO{sub 2} from Coal-Fired Power Plant Flue Gas

    SciTech Connect (OSTI)

    Merkel, Tim; Wei, Xiaotong; Firat, Bilgen; He, Jenny; Amo, Karl; Pande, Saurabh; Baker, Richard; Wijmans, Hans; Bhown, Abhoyjit

    2012-03-31

    This final report describes work conducted for the U.S. Department of Energy National Energy Technology Laboratory (DOE NETL) on development of an efficient membrane process to capture carbon dioxide (CO{sub 2}) from power plant flue gas (award number DE-NT0005312). The primary goal of this research program was to demonstrate, in a field test, the ability of a membrane process to capture up to 90% of CO{sub 2} in coal-fired flue gas, and to evaluate the potential of a full-scale version of the process to perform this separation with less than a 35% increase in the levelized cost of electricity (LCOE). Membrane Technology and Research (MTR) conducted this project in collaboration with Arizona Public Services (APS), who hosted a membrane field test at their Cholla coal-fired power plant, and the Electric Power Research Institute (EPRI) and WorleyParsons (WP), who performed a comparative cost analysis of the proposed membrane CO{sub 2} capture process. The work conducted for this project included membrane and module development, slipstream testing of commercial-sized modules with natural gas and coal-fired flue gas, process design optimization, and a detailed systems and cost analysis of a membrane retrofit to a commercial power plant. The Polaris? membrane developed over a number of years by MTR represents a step-change improvement in CO{sub 2} permeance compared to previous commercial CO{sub 2}-selective membranes. During this project, membrane optimization work resulted in a further doubling of the CO{sub 2} permeance of Polaris membrane while maintaining the CO{sub 2}/N{sub 2} selectivity. This is an important accomplishment because increased CO{sub 2} permeance directly impacts the membrane skid cost and footprint: a doubling of CO{sub 2} permeance halves the skid cost and footprint. In addition to providing high CO{sub 2} permeance, flue gas CO{sub 2} capture membranes must be stable in the presence of contaminants including SO{sub 2}. Laboratory tests showed no

  6. An assessment of mercury emissions and health risks from a coal-fired power plant

    SciTech Connect (OSTI)

    Fthenakis, V.M.; Lipfert, F.; Moskowitz, P.

    1994-12-01

    Title 3 of the 1990 Clean Air Act Amendments (CAAA) mandated that the US Environmental Protection Agency (EPA) evaluate the need to regulate mercury emissions from electric utilities. In support of this forthcoming regulatory analysis the U.S. DOE, sponsored a risk assessment project at Brookhaven (BNL) to evaluate methylmercury (MeHg) hazards independently. In the US MeHg is the predominant way of exposure to mercury originated in the atmosphere. In the BNL study, health risks to adults resulting from Hg emissions from a hypothetical 1,000 MW coal-fired power plant were estimated using probabilistic risk assessment techniques. This study showed that the effects of emissions of a single power plant may double the background exposures to MeHg resulting from consuming fish obtained from a localized area near the power plant. Even at these more elevated exposure levels, the attributable incidence in mild neurological symptoms was estimated to be quite small, especially when compared with the estimated background incidence in the population. The current paper summarizes the basic conclusions of this assessment and highlights issues dealing with emissions control and environmental transport.

  7. Proceedings of the coal-fired power systems 94: Advances in IGCC and PFBC review meeting. Volume 2

    SciTech Connect (OSTI)

    McDaniel, H.M.; Staubly, R.K.; Venkataraman, V.K.

    1994-06-01

    The Coal-Fired Power Systems 94 -- Advances in IGCC and PFBC Review Meeting was held June 21--23, 1994, at the Morgantown Energy Center (METC) in Morgantown, West Virginia. This Meeting was sponsored and hosted by METC, the Office of Fossil Energy, and the US Department of Energy (DOE). METC annually sponsors this conference for energy executives, engineers, scientists, and other interested parties to review the results of research and development projects; to discuss the status of advanced coal-fired power systems and future plans with the industrial contractors; and to discuss cooperative industrial-government research opportunities with METC`s in-house engineers and scientists. Presentations included industrial contractor and METC in-house technology developments related to the production of power via coal-fired Integrated Gasification Combined Cycle (IGCC) and Pressurized Fluidized Bed Combustion (PFBC) systems, the summary status of clean coal technologies, and developments and advancements in advanced technology subsystems, such as hot gas cleanup. A keynote speaker and other representatives from the electric power industry also gave their assessment of advanced power systems. This meeting contained 11 formal sessions and one poster session, and included 52 presentations and 24 poster presentations. Volume II contains papers presented at the following sessions: filter technology issues; hazardous air pollutants; sorbents and solid wastes; and membranes. Selected papers have been processed separately for inclusion in the Energy Science and Technology Database.

  8. Proceedings of the coal-fired power systems 94: Advances in IGCC and PFBC review meeting. Volume 1

    SciTech Connect (OSTI)

    McDaniel, H.M.; Staubly, R.K.; Venkataraman, V.K.

    1994-06-01

    The Coal-Fired Power Systems 94 -- Advances in IGCC and PFBC Review Meeting was held June 21--23, 1994, at the Morgantown Energy Center (METC) in Morgantown, West Virginia. This Meeting was sponsored and hosted by METC, the Office of Fossil Energy, and the US Department of Energy (DOE). METC annually sponsors this conference for energy executives, engineers, scientists, and other interested parties to review the results of research and development projects; to discuss the status of advanced coal-fired power systems and future plans with the industrial contractors; and to discuss cooperative industrial-government research opportunities with METC`s in-house engineers and scientists. Presentations included industrial contractor and METC in-house technology developments related to the production of power via coal-fired Integrated Gasification Combined Cycle (IGCC) and Pressurized Fluidized Bed Combustion (PFBC) systems, the summary status of clean coal technologies, and developments and advancements in advanced technology subsystems, such as hot gas cleanup. A keynote speaker and other representatives from the electric power industry also gave their assessment of advanced power systems. This meeting contained 11 formal sessions and one poster session, and included 52 presentations and 24 poster presentations. Volume I contains papers presented at the following sessions: opening commentaries; changes in the market and technology drivers; advanced IGCC systems; advanced PFBC systems; advanced filter systems; desulfurization system; turbine systems; and poster session. Selected papers have been processed separately for inclusion in the Energy Science and Technology Database.

  9. Should a coal-fired power plant be replaced or retrofitted?

    SciTech Connect (OSTI)

    Dalia Patino-Echeverri; Benoit Morel; Jay Apt; Chao Chen

    2007-12-15

    In a cap-and-trade system, a power plant operator can choose to operate while paying for the necessary emissions allowances, retrofit emissions controls to the plant, or replace the unit with a new plant. Allowance prices are uncertain, as are the timing and stringency of requirements for control of mercury and carbon emissions. We model the evolution of allowance prices for SO{sub 2}, NOx, Hg, and CO{sub 2} using geometric Brownian motion with drift, volatility, and jumps, and use an options-based analysis to find the value of the alternatives. In the absence of a carbon price, only if the owners have a planning horizon longer than 30 years would they replace a conventional coal-fired plant with a high-performance unit such as a supercritical plant; otherwise, they would install SO{sub 2} and NOx controls on the existing unit. An expectation that the CO{sub 2} price will reach $50/t in 2020 makes the installation of an IGCC with carbon capture and sequestration attractive today, even for planning horizons as short as 20 years. A carbon price below $40/t is unlikely to produce investments in carbon capture for electric power. 1 ref., 5 figs., 2 tabs.

  10. Health and environmental effects of coal-fired electric power plants

    SciTech Connect (OSTI)

    Morris, S.C.; Hamilton, L.D.

    1984-05-01

    This paper describes health and environmental impacts of coal-fired electric power plants. Effects on man, agriculture, and natural ecosystems are considered. These effects may result from direct impacts or exposures via air, water, and food chains. The paper is organized by geographical extent of effect. Occupational health impacts and local environmental effects such as noise and solid waste leachate are treated first. Then, regional effects of air pollution, including acid rain, are analyzed. Finally, potential global impacts are examined. Occupational health concerns considered include exposure to noise, dust, asbestos, mercury, and combustion products, and resulting injury and disease. Local effects considered include noise; air and water emissions of coal storage piles, solid waste operations, and cooling systems. Air pollution, once an acute local problem, is now a regional concern. Acute and chronic direct health effects are considered. Special attention is given to potential effects of radionuclides in coal and of acid rain. Finally, potential global impacts associated with carbon dioxide emissions are considered. 88 references, 9 tables.

  11. Mercury capture within coal-fired power plant electrostatic precipitators: model evaluation

    SciTech Connect (OSTI)

    Clack, H.L.

    2009-03-01

    Efforts to reduce anthropogenic mercury emissions worldwide have recently focused on a variety of sources, including mercury emitted during coal combustion. Toward that end, much research has been ongoing seeking to develop new processes for reducing coal combustion mercury emissions. Among air pollution control processes that can be applied to coal-fired boilers, electrostatic precipitators (ESPs) are by far the most common, both on a global scale and among the principal countries of India, China, and the U.S. that burn coal for electric power generation. A previously reported theoretical model of in-flight mercury capture within ESPs is herein evaluated against data from a number of full-scale tests of activated carbon injection for mercury emissions control. By using the established particle size distribution of the activated carbon and actual or estimated values of its equilibrium mercury adsorption capacity, the incremental reduction in mercury concentration across each ESP can be predicted and compared to experimental results. Because the model does not incorporate kinetics associated with gas-phase mercury transformation or surface adsorption, the model predictions represent the mass-transfer-limited performance. Comparing field data to model results reveals many facilities performing at or near the predicted mass-transfer-limited maximum, particularly at low rates of sorbent injection. Where agreement is poor between field data and model predictions, additional chemical or physical phenomena may be responsible for reducing mercury removal efficiencies. 26 refs., 5 figs., 1 tab.

  12. Engineering development of coal-fired high performance power systems, Phase II and III

    SciTech Connect (OSTI)

    1999-01-01

    The goals of the program are to develop a coal-fired high performance power generation system (HIPPS) that is capable of: thermal efficiency (HHV) {ge} 47%; NOx, SOx, and particulates {le} 10% NSPS (New Source Performance Standard) coal providing {ge} 65% of heat input; all solid wastes benign; cost of electricity {le} 90% of present plants. Phase 1, which began in 1992, focused on the analysis of various configurations of indirectly fired cycles and on technical assessments of alternative plant subsystems and components, including performance requirements, developmental status, design options, complexity and reliability, and capital and operating costs. Phase 1 also included preliminary R and D and the preparation of designs for HIPPS commercial plants approximately 300 MWe in size. This phase, Phase 2, involves the development and testing of plant subsystems, refinement and updating of the HIPPS commercial plant design, and the site selection and engineering design of a HIPPS prototype plant. Work reported herein is from: Task 2.1 HITAC Combustors; Task 2.2 HITAF Air Heaters; Task 6 HIPPS Commercial Plant Design Update.

  13. Engineering development of coal-fired high performance power systems, Phase II and III

    SciTech Connect (OSTI)

    1998-07-01

    The goals of the program are to develop a coal-fired high performance power generation system (HIPPS) that is capable of: thermal efficiency (HHV) {ge} 47%, NOx, SOx, and particulates {le} 10% NSPS (New Source Performance Standard), coal providing {ge} 65% of heat input, all solid wastes benign cost of electricity {le} 90% of present plants. Phase 1, which began in 1992, focused on the analysis of various configurations of indirectly fired cycles and on technical assessments of alternative plant subsystems and components, including performance requirements, developmental status, design options, complexity and reliability, and capital and operating costs. Phase 1 also included preliminary R and D and the preparation of designs for HIPPS commercial plants approximately 300 MWe in size. This phase, Phase 2, involves the development and testing of plant subsystems, refinement and updating of the HIPPS commercial plant design, and the site selection and engineering design of a HIPPS prototype plant. Work reported herein is from: Task 2.1 HITAF Combustor; Task 2.2 HITAF Air Heaters; Task 6 HIPPS Commercial Plant Design Update.

  14. Mercury Speciation in Coal-Fired Power Plant Flue Gas-Experimental Studies and Model Development

    SciTech Connect (OSTI)

    Radisav Vidic; Joseph Flora; Eric Borguet

    2008-12-31

    The overall goal of the project was to obtain a fundamental understanding of the catalytic reactions that are promoted by solid surfaces present in coal combustion systems and develop a mathematical model that described key phenomena responsible for the fate of mercury in coal-combustion systems. This objective was achieved by carefully combining laboratory studies under realistic process conditions using simulated flue gas with mathematical modeling efforts. Laboratory-scale studies were performed to understand the fundamental aspects of chemical reactions between flue gas constituents and solid surfaces present in the fly ash and their impact on mercury speciation. Process models were developed to account for heterogeneous reactions because of the presence of fly ash as well as the deliberate addition of particles to promote Hg oxidation and adsorption. Quantum modeling was used to obtain estimates of the kinetics of heterogeneous reactions. Based on the initial findings of this study, additional work was performed to ascertain the potential of using inexpensive inorganic sorbents to control mercury emissions from coal-fired power plants without adverse impact on the salability fly ash, which is one of the major drawbacks of current control technologies based on activated carbon.

  15. OXIDATION OF MERCURY ACROSS SCR CATALYSTS IN COAL-FIRED POWER PLANTS BURNING LOW RANK FUELS

    SciTech Connect (OSTI)

    Constance Senior; Temi Linjewile

    2003-10-31

    This is the third Quarterly Technical Report for DOE Cooperative Agreement No: DE-FC26-03NT41728. The objective of this program is to measure the oxidation of mercury in flue gas across SCR catalyst in a coal-fired power plant burning low rank fuels using a slipstream reactor containing multiple commercial catalysts in parallel. The Electric Power Research Institute (EPRI) and Argillon GmbH are providing co-funding for this program. This program contains multiple tasks and good progress is being made on all fronts. During this quarter, the second set of mercury measurements was made after the catalysts had been exposed to flue gas for about 2,000 hours. There was good agreement between the Ontario Hydro measurements and the SCEM measurements. Carbon trap measurements of total mercury agreed fairly well with the SCEM. There did appear to be some loss of mercury in the sampling system toward the end of the sampling campaign. NO{sub x} reductions across the catalysts ranged from 60% to 88%. Loss of total mercury across the commercial catalysts was not observed, as it had been in the March/April test series. It is not clear whether this was due to aging of the catalyst or to changes in the sampling system made between March/April and August. In the presence of ammonia, the blank monolith showed no oxidation. Two of the commercial catalysts showed mercury oxidation that was comparable to that in the March/April series. The other three commercial catalysts showed a decrease in mercury oxidation relative to the March/April series. Oxidation of mercury increased without ammonia present. Transient experiments showed that when ammonia was turned on, mercury appeared to desorb from the catalyst, suggesting displacement of adsorbed mercury by the ammonia.

  16. Coal-fired high performance power generating system. Quarterly progress report

    SciTech Connect (OSTI)

    Not Available

    1992-07-01

    The goals of the program are to develop a coal-fired high performance power generation system (HIPPS) by the year 2000 that is capable of > 47% thermal efficiency; NO{sub x} SO {sub x} and Particulates < 25% NSPS; Cost of electricity 10% lower; coal > 65% of heat input and all solid wastes benign. In order to achieve these goals our team has outlined a research plan based on an optimized analysis of a 250 MW{sub e} combined cycle system applicable to both frame type and aeroderivative gas turbines. Under the constraints of the cycle analysis we have designed a high temperature advanced furnace (HITAF) which integrates several combustor and air heater designs with appropriate ash management procedures. Most of this report discusses the details of work on these components, and the R&D Plan for future work. The discussion of the combustor designs illustrates how detailed modeling can be an effective tool to estimate NO{sub x} production, minimum burnout lengths, combustion temperatures and even particulate impact on the combustor walls. When our model is applied to the long flame concept it indicates that fuel bound nitrogen will limit the range of coals that can use this approach. For high nitrogen coals a rapid mixing, rich-lean, deep staging combustor will be necessary. The air heater design has evolved into two segments: a convective heat exchanger downstream of the combustion process; a radiant panel heat exchanger, located in the combustor walls; The relative amount of heat transferred either radiatively or convectively will depend on the combustor type and the ash properties.

  17. OXIDATION OF MERCURY ACROSS SCR CATALYSTS IN COAL-FIRED POWER PLANTS BURNING LOW RANK FUELS

    SciTech Connect (OSTI)

    Constance Senior

    2004-12-31

    The objectives of this program were to measure the oxidation of mercury in flue gas across SCR catalyst in a coal-fired power plant burning low rank fuels using a slipstream reactor containing multiple commercial catalysts in parallel and to develop a greater understanding of mercury oxidation across SCR catalysts in the form of a simple model. The Electric Power Research Institute (EPRI) and Argillon GmbH provided co-funding for this program. REI used a multicatalyst slipstream reactor to determine oxidation of mercury across five commercial SCR catalysts at a power plant that burned a blend of 87% subbituminous coal and 13% bituminous coal. The chlorine content of the blend was 100 to 240 {micro}g/g on a dry basis. Mercury measurements were carried out when the catalysts were relatively new, corresponding to about 300 hours of operation and again after 2,200 hours of operation. NO{sub x}, O{sub 2} and gaseous mercury speciation at the inlet and at the outlet of each catalyst chamber were measured. In general, the catalysts all appeared capable of achieving about 90% NO{sub x} reduction at a space velocity of 3,000 hr{sup -1} when new, which is typical of full-scale installations; after 2,200 hours exposure to flue gas, some of the catalysts appeared to lose NO{sub x} activity. For the fresh commercial catalysts, oxidation of mercury was in the range of 25% to 65% at typical full-scale space velocities. A blank monolith showed no oxidation of mercury under any conditions. All catalysts showed higher mercury oxidation without ammonia, consistent with full-scale measurements. After exposure to flue gas for 2,200 hours, some of the catalysts showed reduced levels of mercury oxidation relative to the initial levels of oxidation. A model of Hg oxidation across SCRs was formulated based on full-scale data. The model took into account the effects of temperature, space velocity, catalyst type and HCl concentration in the flue gas.

  18. After the Clean Air Mercury Eule: prospects for reducing mercury emissions from coal-fired power plants

    SciTech Connect (OSTI)

    Jana B. Milford; Alison Pienciak

    2009-04-15

    Recent court decisions have affected the EPA's regulation of mercury emissions from coal burning, but some state laws are helping to clear the air. In 2005, the US EPA issued the Clean Air Mercury Rule (CAMR), setting performance standards for new coal-fired power plants and nominally capping mercury emissions form new and existing plants at 38 tons per year from 2010 to 2017 and 15 tpy in 2018 and thereafter; these down from 48.5 tpy in 1999. To implement the CAMR, 21 states with non-zero emissions adopted EPA's new source performance standards and cap and trade program with little or no modification. By December 2007, 23 other states had proposed or adopted more stringent requirements; 16 states prohibited or restricted interstate trading of mercury emissions. On February 2008, the US Court of Appeal for the District of Columbia Circuit unanimously vacated the CAMR. This article assesses the status of mercury emission control requirements for coal-fired power plants in the US in light of this decision, focusing on state actions and prospects for a new federal rule. 34 refs., 1 fig.

  19. Sustainability Assessment of Coal-Fired Power Plants with Carbon Capture and Storage

    SciTech Connect (OSTI)

    Widder, Sarah H.; Butner, R. Scott; Elliott, Michael L.; Freeman, Charles J.

    2011-11-30

    Carbon capture and sequestration (CCS) has the ability to dramatically reduce carbon dioxide (CO2) emissions from power production. Most studies find the potential for 70 to 80 percent reductions in CO2 emissions on a life-cycle basis, depending on the technology. Because of this potential, utilities and policymakers are considering the wide-spread implementation of CCS technology on new and existing coal plants to dramatically curb greenhouse gas (GHG) emissions from the power generation sector. However, the implementation of CCS systems will have many other social, economic, and environmental impacts beyond curbing GHG emissions that must be considered to achieve sustainable energy generation. For example, emissions of nitrogen oxides (NOx), sulfur oxides (SOx), and particulate matter (PM) are also important environmental concerns for coal-fired power plants. For example, several studies have shown that eutrophication is expected to double and acidification would increase due to increases in NOx emissions for a coal plant with CCS provided by monoethanolamine (MEA) scrubbing. Potential for human health risks is also expected to increase due to increased heavy metals in water from increased coal mining and MEA hazardous waste, although there is currently not enough information to relate this potential to actual realized health impacts. In addition to environmental and human health impacts, supply chain impacts and other social, economic, or strategic impacts will be important to consider. A thorough review of the literature for life-cycle analyses of power generation processes using CCS technology via the MEA absorption process, and other energy generation technologies as applicable, yielded large variability in methods and core metrics. Nonetheless, a few key areas of impact for CCS were developed from the studies that we reviewed. These are: the impact of MEA generation on increased eutrophication and acidification from ammonia emissions and increased toxicity

  20. POTENTIAL HEALTH RISK REDUCTION ARISING FROM REDUCED MERCURY EMISSIONS FROM COAL FIRED POWER PLANTS.

    SciTech Connect (OSTI)

    Sullivan, T. M.; Lipfert, F. W.; Morris, S. C.; Moskowitz, P. D.

    2001-09-01

    The U.S. Environmental Protection Agency (EPA) has announced plans to regulate mercury (Hg) emissions from coal-fired power plants. EPA has not prepared a quantitative assessment of the reduction in risk that could be achieved through reduction in coal plant emissions of Hg. To address this issue, Brookhaven National Laboratory (BNL) with support from the U.S. Department of Energy Office of Fossil Energy (DOE FE) prepared a quantitative assessment of the reduction in human health risk that could be achieved through reduction in coal plant emissions of Hg. The primary pathway for Hg exposure is through consumption of fish. The most susceptible population to Hg exposure is the fetus. Therefore the risk assessment focused on consumption of fish by women of child-bearing age. Dose response factors were generated from studies on loss of cognitive abilities (language skills, motor skills, etc.) by young children whose mothers consumed large amounts of fish with high Hg levels. Population risks were estimated for the general population in three regions of the country, (the Midwest, Northeast, and Southeast) that were identified by EPA as being heavily impacted by coal emissions. Three scenarios for reducing Hg emissions from coal plants were considered: (1) A base case using current conditions; (2) A 50% reduction; and, (3) A 90% reduction. These reductions in emissions were assumed to translate linearly into a reduction in fish Hg levels of 8.6% and 15.5%, respectively. Population risk estimates were also calculated for two subsistence fisher populations. These groups of people consume substantially more fish than the general public and, depending on location, the fish may contain higher Hg levels than average. Risk estimates for these groups were calculated for the three Hg levels used for the general population analyses. Analysis shows that the general population risks for exposure of the fetus to Hg are small. Estimated risks under current conditions (i.e., no

  1. Coal-fired generation staging a comeback. 2nd ed.

    SciTech Connect (OSTI)

    2007-07-01

    The report is an overview of the renewed U.S. market interest in coal-fired power generation. It provides a concise look at what is driving interest in coal-fired generation, the challenges faced in implementing coal-fired generation projects, and the current and future state of coal-fired generation. Topics covered in the report include: An overview of coal-fired generation including its history, the current market environment, and its future prospects; An analysis of the key business factors that are driving renewed interest in coal-fired generation; An analysis of the challenges that are hindering the implementation of coal-fired generation projects; A description of coal-fired generation technologies; A review of the economic drivers of coal-fired generation project success; An evaluation of coal-fired generation versus other generation technologies; A discussion of the key government initiatives supporting new coal-fired generation; and A listing of planned coal-fired generation projects. 13 figs., 12 tabs., 1 app.

  2. Radiological Impact Associated to Technologically Enhanced Naturally Occurring Radioactive Materials (TENORM) from Coal-Fired Power Plants Emissions - 13436

    SciTech Connect (OSTI)

    Dinis, Maria de Lurdes; Fiuza, Antonio; Soeiro de Carvalho, Jose; Gois, Joaquim; Meira Castro, Ana Cristina

    2013-07-01

    Certain materials used and produced in a wide range of non-nuclear industries contain enhanced activity concentrations of natural radionuclides. In particular, electricity production from coal is one of the major sources of increased human exposure to naturally occurring radioactive materials. A methodology was developed to assess the radiological impact due to natural radiation background. The developed research was applied to a specific case study, the Sines coal-fired power plant, located in the southwest coastline of Portugal. Gamma radiation measurements were carried out with two different instruments: a sodium iodide scintillation detector counter (SPP2 NF, Saphymo) and a gamma ray spectrometer with energy discrimination (Falcon 5000, Canberra). Two circular survey areas were defined within 20 km of the power plant. Forty relevant measurements points were established within the sampling area: 15 urban and 25 suburban locations. Additionally, ten more measurements points were defined, mostly at the 20-km area. The registered gamma radiation varies from 20 to 98.33 counts per seconds (c.p.s.) corresponding to an external gamma exposure rate variable between 87.70 and 431.19 nGy/h. The highest values were measured at locations near the power plant and those located in an area within the 6 and 20 km from the stacks. In situ gamma radiation measurements with energy discrimination identified natural emitting nuclides as well as their decay products (Pb-212, Pb-2142, Ra-226, Th-232, Ac-228, Th-234, Pa-234, U- 235, etc.). According to the results, an influence from the stacks emissions has been identified both qualitatively and quantitatively. The developed methodology accomplished the lack of data in what concerns to radiation rate in the vicinity of Sines coal-fired power plant and consequently the resulting exposure to the nearby population. (authors)

  3. Comprehensive assessment of toxic emissions from coal-fired power plants

    SciTech Connect (OSTI)

    1996-09-01

    The 1990 Clean Air Act Amendments (CAAA) have two primary goals: pollution prevention and a market-based least-cost approach to emission control. To address air quality issues as well as permitting and enforcement, the 1990 CAAA contain 11 sections or titles. The individual amendment titles are as follows: Title I - National Ambient Air Quality Standards Title II - Mobile Sources Title III - Hazardous Air Pollutants Title IV - Acid Deposition Control Title V - Permits Title VI - Stratospheric Ozone Protection Chemicals Title VII - Enforcement Title VIII - Miscellaneous Provisions Title IX - Clean Air Research Title X - Disadvantaged Business Concerns Title XI - Clean Air Employment Transition Assistance Titles I, III, IV, and V will change or have the potential to change how operators of coal-fired utility boilers control, monitor, and report emissions. For the purpose of this discussion, Title III is the primary focus.

  4. A supply chain network design model for biomass co-firing in coal-fired power plants

    SciTech Connect (OSTI)

    Md. S. Roni; Sandra D. Eksioglu; Erin Searcy; Krishna Jha

    2014-01-01

    We propose a framework for designing the supply chain network for biomass co-firing in coal-fired power plants. This framework is inspired by existing practices with products with similar physical characteristics to biomass. We present a hub-and-spoke supply chain network design model for long-haul delivery of biomass. This model is a mixed integer linear program solved using benders decomposition algorithm. Numerical analysis indicates that 100 million tons of biomass are located within 75 miles from a coal plant and could be delivered at $8.53/dry-ton; 60 million tons of biomass are located beyond 75 miles and could be delivered at $36/dry-ton.

  5. Energy penalty analysis of possible cooling water intake structurerequirements on existing coal-fired power plants.

    SciTech Connect (OSTI)

    Veil, J. A.; Littleton, D. J.; Gross, R. W.; Smith, D. N.; Parsons, E.L., Jr.; Shelton, W. W.; Feeley, T. J.; McGurl, G. V.

    2006-11-27

    from converting plants with once-through cooling to wet towers or indirect-dry towers. Five locations--Delaware River Basin (Philadelphia), Michigan/Great Lakes (Detroit), Ohio River Valley (Indianapolis), South (Atlanta), and Southwest (Yuma)--were modeled using an ASPEN simulator model. The model evaluated the performance and energy penalty for hypothetical 400-MW coal-fired plants that were retrofitted from using once-through cooling systems to wet- and dry-recirculating systems. The modeling was initially done to simulate the hottest time of the year using temperature input values that are exceeded only 1 percent of the time between June through September at each modeled location. These are the same temperature inputs commonly used by cooling tower designers to ensure that towers perform properly under most climatic conditions.

  6. Thermal Integration of CO{sub 2} Compression Processes with Coal-Fired Power Plants Equipped with Carbon Capture

    SciTech Connect (OSTI)

    Edward Levy

    2012-06-29

    Coal-fired power plants, equipped either with oxycombustion or post-combustion CO{sub 2} capture, will require a CO{sub 2} compression system to increase the pressure of the CO{sub 2} to the level needed for sequestration. Most analyses show that CO{sub 2} compression will have a significant effect on parasitic load, will be a major capital cost, and will contribute significantly to reduced unit efficiency. This project used first principle engineering analyses and computer simulations to determine the effects of utilizing compressor waste heat to improve power plant efficiency and increase net power output of coal-fired power plants with carbon capture. This was done for units with post combustion solvent-based CO{sub 2} capture systems and for oxyfired power plants, firing bituminous, PRB and lignite coals. The thermal integration opportunities analyzed for oxycombustion capture are use of compressor waste heat to reheat recirculated flue gas, preheat boiler feedwater and predry high-moisture coals prior to pulverizing the coal. Among the thermal integration opportunities analyzed for post combustion capture systems are use of compressor waste heat and heat recovered from the stripper condenser to regenerate post-combustion CO{sub 2} capture solvent, preheat boiler feedwater and predry high-moisture coals. The overall conclusion from the oxyfuel simulations is that thermal integration of compressor heat has the potential to improve net unit heat rate by up to 8.4 percent, but the actual magnitude of the improvement will depend on the type of heat sink used and to a lesser extent, compressor design and coal rank. The simulations of a unit with a MEA post combustion capture system showed that thermal integration of either compressor heat or stripper condenser heat to preheat boiler feedwater would result in heat rate improvements from 1.20 percent to 4.19 percent. The MEA capture simulations further showed that partial drying of low rank coals, done in combination

  7. Coal-fired boiler for petroleum refinery

    SciTech Connect (OSTI)

    Ketterman, W.R.; Heinzmann, D.A.

    1982-01-01

    There has been a significant amount of interest in conversion from oil/gas fired boilers to coal-fired equipment since the Arab oil embargo of 1973. The CRA Incorporated Coffeyville Refinery decided in 1977 to proceed with the installation of a 86.183 Kg/h coal fired boiler to generate process steam at 650 psig (4,482 k Pa) 596/sup 0/F (313/sup 0/C). A significant portion of this steam is passed through steam turbines to obtain mechanical power. Building and operating a coal-fired steam plant is a ''Different Kettle of Fish'' from building and operating an oil/gas-fired steam plant. The intention of this paper is to deal with some of the ''Why's and Wherefores'' of the conversion to coal-fired equipment.

  8. Low Cost Sorbent for Capturing CO{sub 2} Emissions Generated by Existing Coal-fired Power Plants

    SciTech Connect (OSTI)

    Elliott, Jeannine

    2013-08-31

    TDA Research, Inc. has developed a novel sorbent based post-combustion CO{sub 2} removal technology. This low cost sorbent can be regenerated with low-pressure (ca. 1 atm) superheated steam without temperature swing or pressure-swing. The isothermal and isobaric operation is a unique and advantageous feature of this process. The objective of this project was to demonstrate the technical and economic merit of this sorbent based CO{sub 2} capture approach. Through laboratory, bench-scale and field testing we demonstrated that this technology can effectively and efficiently capture CO{sub 2} produced at an existing pulverized coal power plants. TDA Research, Inc is developing both the solid sorbent and the process designed around that material. This project addresses the DOE Program Goal to develop a capture technology that can be added to an existing or new coal fired power plant, and can capture 90% of the CO{sub 2} produced with the lowest possible increase in the cost of energy. .

  9. Impacts of the Minamata Conventionon on Mercury Emissions and Global Deposition from Coal-Fired Power Generation in Asia

    SciTech Connect (OSTI)

    Giang, Amanda; Stokes, Leah C.; Streets, David G.; Corbitt, Elizabeth S.; Selin, Noelle E.

    2015-05-05

    We explore implications of the United Nations Minamata Convention on Mercury for emissions from Asian coal-fired power generation, and resulting changes to deposition worldwide by 2050. We use engineering analysis, document analysis, and interviews to construct plausible technology scenarios consistent with the Convention. We translate these scenarios into emissions projections for 2050, and use the GEOS-Chem model to calculate global mercury deposition. Where technology requirements in the Convention are flexibly defined, under a global energy and development scenario that relies heavily on coal, we project similar to 90 and 150 Mg.y(-1) of avoided power sector emissions for China and India, respectively, in 2050, compared to a scenario in which only current technologies are used. Benefits of this avoided emissions growth are primarily captured regionally, with projected changes in annual average gross deposition over China and India similar to 2 and 13 mu g.m(-2) lower, respectively, than the current technology case. Stricter, but technologically feasible, mercury control requirements in both countries could lead to a combined additional 170 Mg.y(-1) avoided emissions. Assuming only current technologies but a global transition away from coal avoids 6% and 36% more emissions than this strict technology scenario under heavy coal use for China and India, respectively.

  10. Modeling of integrated environmental control systems for coal-fired power plants. Quarterly progress report, [July 1, 1988--September 30, 1988

    SciTech Connect (OSTI)

    Rubin, E.S.

    1988-10-01

    This is the fourth quarterly report of DOE Contract No. DE-AC22-87PC79864, entitled ``Modeling of Integrated Environmental Control Systems for Coal-Fired Power Plants.`` This report summarizes accomplishments during the period July 1, 1988 to September 30, 1988. Our efforts during the last quarter focused primarily on the completion, testing and documentation of the NO{sub x}SO process model. The sections below present the details of these developments.

  11. Exploring links between innovation and diffusion: adoption of NOx control technologies at U.S. coal-fired power plants

    SciTech Connect (OSTI)

    Popp, D.

    2006-03-15

    While many studies have looked at innovation and adoption of technologies separately, the two processes are linked. Advances (and expected advances) in a single technology should affect both its adoption rate and the adoption of alternative technologies. Moreover, advances made abroad may affect adoption differently than improvements developed domestically. This paper combines plant-level data on US coal-fired electric power plants with patent data pertaining to NOx pollution control techniques to study these links. It is shown that technological advances, particularly those made abroad, are important for the adoption of newer post-combustion treatment technologies, but have little effect on the adoption of older combustion modification techniques. Moreover, it provides evidence that adaptive R&D by US firms is necessary before foreign innovations are adopted in the US. Expectations of future technological advances delay adoption. Nonetheless, as in other studies of environmental technologies, the effect of other explanatory variables is dominated by the effect of environmental regulations, demonstrating that the mere presence of environmental technologies is not enough to encourage its usage.

  12. Alstom's Chemical Looping Combustion Prototype for CO{sub 2} Capture from Existing Pulverized Coal-Fired Power Plants

    SciTech Connect (OSTI)

    Andrus, Herbert; Chiu, John; Edberg, Carl; Thibeault, Paul; Turek, David

    2012-09-30

    Alstom’s Limestone Chemical Looping (LCL™) process has the potential to capture CO{sub 2} from new and existing coal-fired power plants while maintaining high plant power generation efficiency. This new power plant concept is based on a hybrid combustion- gasification process utilizing high temperature chemical and thermal looping technology. This process could also be potentially configured as a hybrid combustion-gasification process producing a syngas or hydrogen for various applications while also producing a separate stream of CO{sub 2} for use or sequestration. The targets set for this technology is to capture over 90% of the total carbon in the coal at cost of electricity which is less than 20% greater than Conventional PC or CFB units. Previous work with bench scale test and a 65 kWt Process Development Unit Development (PDU) has validated the chemistry required for the chemical looping process and provided for the investigation of the solids transport mechanisms and design requirements. The objective of this project is to continue development of the combustion option of chemical looping (LCL-C™) by designing, building and testing a 3 MWt prototype facility. The prototype includes all of the equipment that is required to operate the chemical looping plant in a fully integrated manner with all major systems in service. Data from the design, construction, and testing will be used to characterize environmental performance, identify and address technical risks, reassess commercial plant economics, and develop design information for a demonstration plant planned to follow the proposed Prototype. A cold flow model of the prototype will be used to predict operating conditions for the prototype and help in operator training. Operation of the prototype will provide operator experience with this new technology and performance data of the LCL-C™ process, which will be applied to the commercial design and economics and plan for a future demonstration plant.

  13. Commercialization of coal-fired diesel engines for cogeneration and non-utility power markets

    SciTech Connect (OSTI)

    Wilson, R.P.; Rao, K.; Benedek, K.R.; Itse, D.; Parkinson, J.; Kimberley, J.; Balles, E.N.; Benson, C.E.; Smith, C.

    1992-01-01

    The primary objective of this METC project is to established practical, durable components compatible with clean coal slurry fuel and capable of low emissions. The components will be integrated into a coal power system for a 100-hr proof-of-concept test. The goal of this program is to advance the stationary coal-fueled diesel engine to the next plateau of technological readiness, and thus provide the springboard to commercialization.

  14. Commercialization of coal-fired diesel engines for cogeneration and non-utility power markets

    SciTech Connect (OSTI)

    Wilson, R.P.; Rao, K.; Benedek, K.R.; Itse, D.; Parkinson, J.; Kimberley, J.; Balles, E.N.; Benson, C.E.; Smith, C.

    1992-12-31

    The primary objective of this METC project is to established practical, durable components compatible with clean coal slurry fuel and capable of low emissions. The components will be integrated into a coal power system for a 100-hr proof-of-concept test. The goal of this program is to advance the stationary coal-fueled diesel engine to the next plateau of technological readiness, and thus provide the springboard to commercialization.

  15. Development of a high-performance coal-fired power generating system with pyrolysis gas and char-fired high temperature furnace (HITAF). Volume 1, Final report

    SciTech Connect (OSTI)

    1996-02-01

    A major objective of the coal-fired high performance power systems (HIPPS) program is to achieve significant increases in the thermodynamic efficiency of coal use for electric power generation. Through increased efficiency, all airborne emissions can be decreased, including emissions of carbon dioxide. High Performance power systems as defined for this program are coal-fired, high efficiency systems where the combustion products from coal do not contact the gas turbine. Typically, this type of a system will involve some indirect heating of gas turbine inlet air and then topping combustion with a cleaner fuel. The topping combustion fuel can be natural gas or another relatively clean fuel. Fuel gas derived from coal is an acceptable fuel for the topping combustion. The ultimate goal for HIPPS is to, have a system that has 95 percent of its heat input from coal. Interim systems that have at least 65 percent heat input from coal are acceptable, but these systems are required to have a clear development path to a system that is 95 percent coal-fired. A three phase program has been planned for the development of HIPPS. Phase 1, reported herein, includes the development of a conceptual design for a commercial plant. Technical and economic feasibility have been analysed for this plant. Preliminary R&D on some aspects of the system were also done in Phase 1, and a Research, Development and Test plan was developed for Phase 2. Work in Phase 2 include s the testing and analysis that is required to develop the technology base for a prototype plant. This work includes pilot plant testing at a scale of around 50 MMBtu/hr heat input. The culmination of the Phase 2 effort will be a site-specific design and test plan for a prototype plant. Phase 3 is the construction and testing of this plant.

  16. Internet Based, GIS Catalog of Non-Traditional Sources of Cooling Water for Use at America's Coal-Fired Power Plants

    SciTech Connect (OSTI)

    J. Daniel Arthur

    2011-09-30

    In recent years, rising populations and regional droughts have caused coal-fired power plants to temporarily curtail or cease production due to a lack of available water for cooling. In addition, concerns about the availability of adequate supplies of cooling water have resulted in cancellation of plans to build much-needed new power plants. These issues, coupled with concern over the possible impacts of global climate change, have caused industry and community planners to seek alternate sources of water to supplement or replace existing supplies. The Department of Energy, through the National Energy Technology Laboratory (NETL) is researching ways to reduce the water demands of coal-fired power plants. As part of the NETL Program, ALL Consulting developed an internet-based Catalog of potential alternative sources of cooling water. The Catalog identifies alternative sources of water, such as mine discharge water, oil and gas produced water, saline aquifers, and publicly owned treatment works (POTWs), which could be used to supplement or replace existing surface water sources. This report provides an overview of the Catalog, and examines the benefits and challenges of using these alternative water sources for cooling water.

  17. Evaluation of Solid Sorbents As A Retrofit Technology for CO{sub 2} Capture from Coal-Fired Power Plants

    SciTech Connect (OSTI)

    Krutka, Holly; Sjostrom, Sharon

    2011-07-31

    Through a U.S. Department of Energy (DOE) National Energy Technology Laboratory (NETL) funded cooperative agreement DE-NT0005649, ADA Environmental Solutions (ADA) has begun evaluating the use of solid sorbents for CO{sub 2} capture. The project objective was to address the viability and accelerate development of a solid-based CO{sub 2} capture technology. To meet this objective, initial evaluations of sorbents and the process / equipment were completed. First the sorbents were evaluated using a temperature swing adsorption process at the laboratory scale in a fixed-bed apparatus. A slipstream reactor designed to treat flue gas produced by coal-fired generation of nominally 1 kWe was designed and constructed, which was used to evaluate the most promising materials on a more meaningful scale using actual flue gas. In a concurrent effort, commercial-scale processes and equipment options were also evaluated for their applicability to sorbent-based CO{sub 2} capture. A cost analysis was completed that can be used to direct future technology development efforts. ADA completed an extensive sorbent screening program funded primarily through this project, DOE NETL cooperative agreement DE-NT0005649, with support from the Electric Power Research Institute (EPRI) and other industry participants. Laboratory screening tests were completed on simulated and actual flue gas using simulated flue gas and an automated fixed bed system. The following types and quantities of sorbents were evaluated: 87 supported amines, 31 carbon based materials, 6 zeolites, 7 supported carbonates (evaluated under separate funding), 10 hydrotalcites. Sorbent evaluations were conducted to characterize materials and down-select promising candidates for further testing at the slipstream scale. More than half of the materials evaluated during this program were supported amines. Based on the laboratory screening four supported amine sorbents were selected for evaluation at the 1 kW scale at two different

  18. Executive roundtable on coal-fired generation

    SciTech Connect (OSTI)

    2009-09-15

    Power Engineering magazine invited six industry executives from the coal-fired sector to discuss issues affecting current and future prospects of coal-fired generation. The executives are Tim Curran, head of Alstom Power for the USA and Senior Vice President and General Manager of Boilers North America; Ray Kowalik, President and General Manager of Burns and McDonnell Energy Group; Jeff Holmstead, head of Environmental Strategies for the Bracewell Giuliani law firm; Jim Mackey, Vice President, Fluor Power Group's Solid Fuel business line; Tom Shelby, President Kiewit Power Inc., and David Wilks, President of Energy Supply for Excel Energy Group. Steve Blankinship, the magazine's Associate Editor, was the moderator. 6 photos.

  19. Modeling of integrated environmental control systems for coal-fired power plants. Technical progress report, [June 1, 1989--September 30, 1989

    SciTech Connect (OSTI)

    Rubin, E.S.

    1989-10-01

    The general goal of this research project is to enhance, and transfer to DOE, a new computer simulation model for analyzing the performance and cost of environmental control systems for coal-fired power plants. Systems utilizing pre-combustion, combustion, or post-combustion control methods, individually or in combination, may be considered. A unique capability of this model is the probabilistic representation of uncertainty in model input parameters. This stochastic simulation capability allows the performance and cost of environmental control systems to be quantified probabilistically, accounting for the interactions among all uncertain process and economic parameters. This method facilitates more rigorous comparisons between conventional and advanced clean coal technologies promising improved cost and/or effectiveness for SO{sub 2} and NO{sub x} removal. Detailed modeling of several pre-combustion and post-combustion processes of interest to DOE/PETC have been selected for analysis as part of this project.

  20. Hybrid Solvent-Membrane CO2 Capture: A Solvent/Membrane Hybrid Post-combustion CO2 Capture Process for Existing Coal-Fired Power Plants

    SciTech Connect (OSTI)

    2010-07-01

    IMPACCT Project: The University of Kentucky is developing a hybrid approach to capturing CO2 from the exhaust gas of coal-fired power plants. In the first, CO2 is removed as flue gas is passed through an aqueous ammonium-based solvent. In the second, carbon-rich solution from the CO2 absorber is passed through a membrane that is designed to selectively transport the bound carbon, enhancing its concentration on the permeate side. The team’s approach would combine the best of both membrane- and solventbased carbon capture technologies. Under the ARPA-E award, the team is enabling the membrane operation to be a drop-in solution.

  1. EVALUATION OF SOLID SORBENTS AS A RETROFIT TECHNOLOGY FOR CO2 CAPTURE FROM COAL-FIRED POWER PLANTS

    SciTech Connect (OSTI)

    Holly Krutka; Sharon Sjostrom

    2011-07-31

    Through a U.S. Department of Energy (DOE) National Energy Technology Laboratory (NETL) funded cooperative agreement DE-NT0005649, ADA Environmental Solutions (ADA) has begun evaluating the use of solid sorbents for CO{sub 2} capture. The project objective was to address the viability and accelerate development of a solid-based CO{sub 2} capture technology. To meet this objective, initial evaluations of sorbents and the process/equipment were completed. First the sorbents were evaluated using a temperature swing adsorption process at the laboratory scale in a fixed-bed apparatus. A slipstream reactor designed to treat flue gas produced by coal-fired generation of nominally 1 kWe was designed and constructed, which was used to evaluate the most promising materials on a more meaningful scale using actual flue gas. In a concurrent effort, commercial-scale processes and equipment options were also evaluated for their applicability to sorbent-based CO{sub 2} capture. A cost analysis was completed that can be used to direct future technology development efforts. ADA completed an extensive sorbent screening program funded primarily through this project, DOE NETL cooperative agreement DE-NT0005649, with support from the Electric Power Research Institute (EPRI) and other industry participants. Laboratory screening tests were completed on simulated and actual flue gas using simulated flue gas and an automated fixed bed system. The following types and quantities of sorbents were evaluated: 87 supported amines; 31 carbon based materials; 6 zeolites; 7 supported carbonates (evaluated under separate funding); and 10 hydrotalcites. Sorbent evaluations were conducted to characterize materials and down-select promising candidates for further testing at the slipstream scale. More than half of the materials evaluated during this program were supported amines. Based on the laboratory screening four supported amine sorbents were selected for evaluation at the 1 kW scale at two different

  2. Coal-fired diesel generator

    SciTech Connect (OSTI)

    1997-05-01

    The objective of the proposed project is to test the technical, environmental, and economic viability of a coal-fired diesel generator for producing electric power in small power generating markets. Coal for the diesel generator would be provided from existing supplies transported for use in the University`s power plant. A cleanup system would be installed for limiting gaseous and particulate emissions. Electricity and steam produced by the diesel generator would be used to supply the needs of the University. The proposed diesel generator and supporting facilities would occupy approximately 2 acres of land adjacent to existing coal- and oil-fired power plant and research laboratory buildings at the University of Alaska, Fairbanks. The environmental analysis identified that the most notable changes to result from the proposed project would occur in the following areas: power plant configuration at the University of Alaska, Fairbanks; air emissions, water use and discharge, and the quantity of solid waste for disposal; noise levels at the power plant site; and transportation of coal to the power plant. No substantive adverse impacts or environmental concerns were identified in analyzing the effects of these changes.

  3. Site Characterization for CO{sub 2} Storage from Coal-fired Power Facilities in the Black Warrior Basin of Alabama

    SciTech Connect (OSTI)

    Clark, Peter; Pashin, Jack; Carlson, Eric; Goodliffe, Andrew; McIntyre-Redden, Marcella; Mann, Steven; Thompson, Mason

    2012-08-31

    Coal-fired power plants produce large quantities of carbon dioxide. In order to mitigate the greenhouse gas emissions from these power plants, it is necessary to separate and store the carbon dioxide. Saline formations provide a potential sink for carbon dioxide and delineating the capacity of the various known saline formations is a key part of building a storage inventory. As part of this effort, a project was undertaken to access the storage capacity of saline reservoirs in the Black Warrior Basin of Alabama. This basin has been a productive oil and gas reservoir that is well characterized to the west of the two major coal-fired power plants that are north of Birmingham. The saline zones were thought to extend as far east as the Sequatchie Anticline which is just east of the power plants. There is no oil or gas production in the area surrounding the power plants so little is known about the formations in that area. A geologic characterization well was drilled on the Gorgas Power Plant site, which is the farthest west of two power plants in the area. The well was planned to be drilled to approximately 8,000 feet, but drilling was halted at approximately 5,000 feet when a prolific freshwater zone was penetrated. During drilling, a complete set of cores through all of the potential injection zones and the seals above these zones were acquired. A complete set of openhole logs were run along with a vertical seismic profile (VSP). Before drilling started two approximately perpendicular seismic lines were run and later correlated with the VSP. While the zones that were expected were found at approximately the predicted depths, the zones that are typically saline through the reservoir were found to be saturated with a light crude oil. Unfortunately, both the porosity and permeability of these zones were small enough that no meaningful hydrocarbon production would be expected even with carbon dioxide flooding. iv While this part of the basin was found to be unsuitable

  4. A study of toxic emissions from a coal-fired power plant utilizing an ESP while demonstrating the ICCT CT-121 FGD Project. Final report

    SciTech Connect (OSTI)

    Not Available

    1994-06-16

    The US Department of Energy is performing comprehensive assessments of toxic emissions from eight selected coal-fired electric utility units. This program responds to the Clean Air Act Amendments of 1990, which require the US Environmental Protection Agency (EPA) to evaluate emissions of hazardous air pollutants (HAPs) from electric utility power plants for Potential health risks. The resulting data will be furnished to EPA utility power plants and health risk determinations. The assessment of emissions involves the collection and analysis of samples from the major input, process, and output streams of each of the eight power plants for selected hazardous Pollutants identified in Title III of the Clean Air Act. Additional goals are to determine the removal efficiencies of pollution control subsystems for these selected pollutants and the Concentrations associated with the particulate fraction of the flue gas stream as a function of particle size. Material balances are being performed for selected pollutants around the entire power plant and several subsystems to identify the fate of hazardous substances in each utility system. Radian Corporation was selected to perform a toxics assessment at a plant demonstrating an Innovative Clean Coal Technology (ICCT) Project. The site selected is Plant Yates Unit No. 1 of Georgia Power Company, which includes a Chiyoda Thoroughbred-121 demonstration project.

  5. A study of toxic emissions from a coal-fired power plant utilizing an ESP/Wet FGD system. Volume 1, Sampling, results, and special topics: Final report

    SciTech Connect (OSTI)

    Not Available

    1994-07-01

    This was one of a group of assessments of toxic emissions from coal-fired power plants, conducted for DOE-PETC in 1993 as mandated by the 1990 Clean Air Act. It is organized into 2 volumes; Volume 1 describes the sampling effort, presents the concentration data on toxic chemicals in several power plant streams, and reports the results of evaluations and calculations. The study involved solid, liquid, and gaseous samples from input, output, and process streams at Coal Creek Station Unit No. 1, Underwood, North Dakota (1100 MW mine-mouth plant burning lignite from the Falkirk mine located adjacent to the plant). This plant had an electrostatic precipitator and a wet scrubber flue gas desulfurization unit. Measurements were conducted on June 21--24, 26, and 27, 1993; chemicals measured were 6 major and 16 trace elements (including Hg, Cr, Cd, Pb, Se, As, Be, Ni), acids and corresponding anions (HCl, HF, chloride, fluoride, phosphate, sulfate), ammonia and cyanide, elemental C, radionuclides, VOCs, semivolatiles (incl. PAH, polychlorinated dioxins, furans), and aldehydes. Volume 2: Appendices includes process data log sheets, field sampling data sheets, uncertainty calculations, and quality assurance results.

  6. Optimized Solvent for Energy-Efficient, Environmentally-Friendly Capture of CO{sub 2} at Coal-Fired Power Plants

    SciTech Connect (OSTI)

    Farthing, G. A.; Rimpf, L. M.

    2014-04-30

    The overall goal of this project, as originally proposed, was to optimize the formulation of a novel solvent as a critical enabler for the cost-effective, energy-efficient, environmentally-friendly capture of CO{sub 2} at coal-fired utility plants. Aqueous blends of concentrated piperazine (PZ) with other compounds had been shown to exhibit high rates of CO{sub 2} absorption, low regeneration energy, and other desirable performance characteristics during an earlier 5-year development program conducted by B&W. The specific objective of this project was to identify PZ-based solvent formulations that globally optimize the performance of coal-fired power plants equipped with CO{sub 2} scrubbing systems. While previous solvent development studies have tended to focus on energy consumption and absorber size, important issues to be sure, the current work seeks to explore, understand, and optimize solvent formulation across the full gamut of issues related to commercial application of the technology: capital and operating costs, operability, reliability, environmental, health and safety (EH&S), etc. Work on the project was intended to be performed under four budget periods. The objective of the work in the first budget period has been to identify several candidate formulations of a concentrated PZ-based solvent for detailed characterization and evaluation. Work in the second budget period would generate reliable and comprehensive property and performance data for the identified formulations. Work in the third budget period would quantify the expected performance of the selected formulations in a commercial CO{sub 2} scrubbing process. Finally, work in the fourth budget period would provide a final technology feasibility study and a preliminary technology EH&S assessment. Due to other business priorities, however, B&W has requested that this project be terminated at the end of the first budget period. This document therefore serves as the final report for this project. It

  7. Oxygen-Fired CO{sub 2} Recycle for Application to Direct CO{sub 2} Capture form Coal-Fired Power Plants

    SciTech Connect (OSTI)

    Thomas Gale

    2010-09-26

    The Southern Research/Southern Company 1 MWth Pilot-Scale Coal-Fired Test Facility was successfully retrofit to fire in either the traditional air-fired mode or with 100% oxygen and recycled flue gas, with a fully integrated feedback and control system, including oxygen and recycled flue gas modulation during startup, transfer, and shutdown, safety and operational interlocks, and data acquisition. A MAXON Staged Oxygen Burner for Oxy-Coal Applications produced a stable flame over a significant range of firing turn-down, staging, and while firing five different U.S. coal types. The MAXON burner design produces lower flame temperatures than for air firing, which will enable (A) Safe operation, (B) Reduction of recycle flow without concern about furnace flame temperatures, and (C) May likely be affective at reducing slagging and fouling in the boiler and super heater at full-scale Power Plants. A CFD model of the Oxy-fired Combustion Research Facility (OCRF) was used to predict the flame geometry and temperatures in the OCRF and make a comparison with the air-fired case. The model predictions were consistent with the experimental data in showing that the MAXON burner fired with oxygen produced lower flame temperatures than the air-fired burner while firing with air.

  8. Engineering development of coal-fired high performance power systems, Phases 2 and 3. Quarterly progress report, October 1--December 31, 1996. Final report

    SciTech Connect (OSTI)

    1996-12-31

    The goals of this program are to develop a coal-fired high performance power generation system (HIPPS) by the year 2000 that is capable of: {gt} 47% efficiency (HHV); NO{sub x}, SO{sub x}, and particulates {gt} 10% NSPS; coal providing {ge} 65% of heat input; all sold wastes benign; and cost of electricity 90% of present plant. Work reported herein is from Task 1.3 HIPPS Commercial Plant Design, Task 2,2 HITAF Air Heater, and Task 2.4 Duct Heater Design. The impact on cycle efficiency from the integration of various technology advances is presented. The criteria associated with a commercial HIPPS plant design as well as possible environmental control options are presented. The design of the HITAF air heaters, both radiative and convective, is the most critical task in the program. In this report, a summary of the effort associated with the radiative air heater designs that have been considered is provided. The primary testing of the air heater design will be carried out in the UND/EERC pilot-scale furnace; progress to date on the design and construction of the furnace is a major part of this report. The results of laboratory and bench scale activities associated with defining slag properties are presented. Correct material selection is critical for the success of the concept; the materials, both ceramic and metallic, being considered for radiant air heater are presented. The activities associated with the duct heater are also presented.

  9. Bench-scale Development of an Advanced Solid Sorbent-based CO2 Capture Process for Coal-fired Power Plants

    SciTech Connect (OSTI)

    Nelson, Thomas; Kataria, Atish; Soukri, Mustapha; Farmer, Justin; Mobley, Paul; Tanthana, Jak; Wang, Dongxiang; Wang, Xiaoxing; Song, Chunshan

    2015-12-31

    It is increasingly clear that CO2 capture and sequestration (CCS) must play a critical role in curbing worldwide CO2 emissions to the atmosphere. Development of these technologies to cost-effectively remove CO2 from coal-fired power plants is very important to mitigating the impact these power plants have within the world’s power generation portfolio. Currently, conventional CO2 capture technologies, such as aqueous-monoethanolamine based solvent systems, are prohibitively expensive and if implemented could result in a 75 to 100% increase in the cost of electricity for consumers worldwide. Solid sorbent CO2 capture processes – such as RTI’s Advanced Solid Sorbent CO2, Capture Process – are promising alternatives to conventional, liquid solvents. Supported amine sorbents – of the nature RTI has developed – are particularly attractive due to their high CO2 loadings, low heat capacities, reduced corrosivity/volatility and the potential to reduce the regeneration energy needed to carry out CO2 capture. Previous work in this area has failed to adequately address various technology challenges such as sorbent stability and regenerability, sorbent scale-up, improved physical strength and attrition-resistance, proper heat management and temperature control, proper solids handling and circulation control, as well as the proper coupling of process engineering advancements that are tailored for a promising sorbent technology. The remaining challenges for these sorbent processes have provided the framework for the project team’s research and development and target for advancing the technology beyond lab- and bench-scale testing. Under a cooperative agreement with the US Department of Energy, and part of NETL’s CO2 Capture Program, RTI has led an effort to address and mitigate the challenges associated with solid sorbent CO2 capture. The overall objective

  10. Design and Feasibility Assessment of a Retrospective Epidemiological Study of Coal-Fired Power Plant Emissions in the Pittsburgh Pennsylvania Region

    SciTech Connect (OSTI)

    Richard A. Bilonick; Daniel Connell; Evelyn Talbott; Jeanne Zborowski; Myoung Kim

    2006-12-20

    Eighty-nine (89) percent of the electricity supplied in the 35-county Pittsburgh region (comprising parts of the states of Pennsylvania, Ohio, West Virginia, and Maryland) is generated by coal-fired power plants making this an ideal region in which to study the effects of the fine airborne particulates designated as PM{sub 2.5} emitted by the combustion of coal. This report demonstrates that during the period from 1999-2006 (1) sufficient and extensive exposure data, in particular samples of speciated PM{sub 2.5} components from 1999 to 2003, and including gaseous co-pollutants and weather have been collected, (2) sufficient and extensive mortality, morbidity, and related health outcomes data are readily available, and (3) the relationship between health effects and fine particulates can most likely be satisfactorily characterized using a combination of sophisticated statistical methodologies including latent variable modeling (LVM) and generalized linear autoregressive moving average (GLARMA) time series analysis. This report provides detailed information on the available exposure data and the available health outcomes data for the construction of a comprehensive database suitable for analysis, illustrates the application of various statistical methods to characterize the relationship between health effects and exposure, and provides a road map for conducting the proposed study. In addition, a detailed work plan for conducting the study is provided and includes a list of tasks and an estimated budget. A substantial portion of the total study cost is attributed to the cost of analyzing a large number of archived PM{sub 2.5} filters. Analysis of a representative sample of the filters supports the reliability of this invaluable but as-yet untapped resource. These filters hold the key to having sufficient data on the components of PM{sub 2.5} but have a limited shelf life. If the archived filters are not analyzed promptly the important and costly information they

  11. Application of Pulsed Electrical Fields for Advanced Cooling and Water Recovery in Coal-Fired Power Plant

    SciTech Connect (OSTI)

    Young Cho; Alexander Fridman

    2009-04-02

    The overall objective of the present work was to develop technologies to reduce freshwater consumption in a cooling tower of coal-based power plant so that one could significantly reduce the need of make-up water. The specific goal was to develop a scale prevention technology based an integrated system of physical water treatment (PWT) and a novel filtration method so that one could reduce the need for the water blowdown, which accounts approximately 30% of water loss in a cooling tower. The present study investigated if a pulsed spark discharge in water could be used to remove deposits from the filter membrane. The test setup included a circulating water loop and a pulsed power system. The present experiments used artificially hardened water with hardness of 1,000 mg/L of CaCO{sub 3} made from a mixture of calcium chloride (CaCl{sub 2}) and sodium carbonate (Na{sub 2}CO{sub 3}) in order to produce calcium carbonate deposits on the filter membrane. Spark discharge in water was found to produce strong shockwaves in water, and the efficiency of the spark discharge in cleaning filter surface was evaluated by measuring the pressure drop across the filter over time. Results showed that the pressure drop could be reduced to the value corresponding to the initial clean state and after that the filter could be maintained at the initial state almost indefinitely, confirming the validity of the present concept of pulsed spark discharge in water to clean dirty filter. The present study also investigated the effect of a plasma-assisted self-cleaning filter on the performance of physical water treatment (PWT) solenoid coil for the mitigation of mineral fouling in a concentric counterflow heat exchanger. The self-cleaning filter utilized shockwaves produced by pulse-spark discharges in water to continuously remove scale deposits from the surface of the filter, thus keeping the pressure drop across the filter at a relatively low value. Artificial hard water was used in the

  12. Effects of new environmental regulations on coal-fired generation

    SciTech Connect (OSTI)

    LaCount, R.

    1999-07-01

    As restructuring of the electricity industry places downward pressure on power production costs, new environmental regulations are having the opposite effect. Although power plants may be subject to a variety of environmental regulations over the next ten years including reductions in mercury, toxics, and carbon dioxide, new regulations for sulfur dioxide (SO2) and nitrogen oxides (NOX) are poised to impact the electricity industry in the very short term. The cost for coal-fired power plants to comply with these new regulations has the potential to alter their competitive position. January 1, 2000 marks the beginning of Phase II for the Environmental Protection Agency's SO2 allowance market. Starting in January, all coal and oil plants above 25 MW will be required to comply with the federal SO2 provisions. Regulatory deadlines for NOX are also fast approaching; though the ultimate requirements are still subject to change. On May 1, 1999, a NOX allowance market began for states within the Northeast Ozone Transport Commission (OTC). A second phase of this program is scheduled to begin in 2003 that will lower the overall cap for allowable NOX emissions in the participating states. EPA is also working to expand the reach of regional NOX reductions in 2003 through its NOX SIP call. This program, which is currently subject to litigation, would require NOX reductions in 14 states outside of the OTC. A new study by Resource Data International (RDI), Coal-Fired Generation in Competitive Power Markets, assessed the potential impact that the new SO2 and NOX regulations may have on the competitiveness of coal-fired generation. Overall, the study shows that coal-fired generation will continue to grow despite significant environmental costs and competition from natural gas-fired units. The new environmental regulations have the effect of increasing the dispatch cost of coal-fired units from $0.65/MWh on average in the WSCC to $4.14/MWh on average in the MAAC region. The addition

  13. Big drop in coal-fired electricity generation during first half...

    Annual Energy Outlook

    Big drop in coal-fired electricity generation during first half of 2016 The amount of U.S. electricity generated by coal continues to decline in 2016, as power plant operators turn ...

  14. Task 2.3 -- Review and assessment of results from the comprehensive characterization of toxic emissions from coal-fired power plants. Semi-annual report, January 1--June 30, 1995

    SciTech Connect (OSTI)

    Miller, S.J.

    1997-08-01

    To help meet the requirements of the 1990 Clean Air Act Amendments, the US Department of Energy (DOE) sponsored a project entitled ``Comprehensive Characterization of Toxic Emissions from Coal-Fired Power Plants.`` The Energy and Environmental Research Center was contracted to review reports discussing air toxic emissions from eight power plants as Phase 1 of the project. Additional field tests were planned as Phase 2 and are under way. The objective of the project is to provide an independent review of reports produced from the air toxic emissions study, evaluate the scientific validity of the conclusions, identify significant correlations between emissions and fuel or process parameters, compare the data with available results from Electric Power Research Institute (EPRI) studies, make recommendations for future studies, and complete a combined report that summarizes Phase 1, Phase 2, and EPRI findings.

  15. The Magnetohydrodynamics Coal-Fired Flow Facility

    SciTech Connect (OSTI)

    Not Available

    1990-11-01

    Progress continued at MHD coal-fired flow facility. UTSI reports on progress in developing the technology for the steam bottoming portion of the MHD Steam Combined Cycle Power Plant. No Proof-of-Concept (POC) testing was conducted during the quarter but data analyses are reported from the test conducted during the prior quarter. Major results include corrosion data from the first 500 hours of testing on candidate tube materials in the superheater test module (SHTM). Solids mass balance data, electrostatic precipitator (ESP) and baghouse (BH) performance data, diagnostic systems and environmental data results from previous POC tests are included. The major activities this quarter were in facility modifications required to complete the scheduled POC test program. Activities reported include the installation of an automatic ash/seed removal system on the SHTM, the BH, and ESP hoppers. Also, a higher pressure compressor (350 psi) is being installed to provide additional blowing pressure to remove solids deposits on the convective heat transfer tubes in the high temperature zone where the deposits are molten. These activities are scheduled to be completed and ready for the next test, which is scheduled for late May 1990. Also, experiments on drying western coal are reported. The recommended system for modifying the CFFF coal system to permit processing of western coal is described. Finally, a new effort to test portions of the TRW combustor during tests in the CFFF is described. The status of system analyses being conducted under subcontract by the Westinghouse Electric Corporation is also described. 2 refs., 18 figs., 3 tabs.

  16. Development of a high-performance coal-fired power generating system with pyrolysis gas and char-fired high temperature furnace (HITAF). Quarterly progress report No. 6, April--June 1993

    SciTech Connect (OSTI)

    Not Available

    1993-08-01

    A concept for an advanced coal-fired combined-cycle power generating system is currently being developed. The first phase of this three-phase program consists of conducting the necessary research and development to define the system, evaluating the economic and technical feasibility of the concept, and preparing an R&D plan to develop the concept further. The system proposed to meet these goals is a combined-cycle system where air for a gas turbine is indirectly heated to approximately 1800{degree}F in furnaces fired with coal-derived fuels and then directly heated in a natural-gas-fired combustor to about 2400{degree}F. The system is based on a pyrolyzing process that converts the coal into a low-Btu fuel gas and char. The fuel gas is relatively clean, and it is fired to heat tube surfaces that are susceptible to corrosion and problems from ash deposition. In particular, the high-temperature air heater tubes, which will need to be a ceramic material, will be located in a separate furnace or region of a furnace that is exposed to combustion products from the low-Btu fuel gas only.

  17. A study of toxic emissions from a coal-fired power plant utilizing the SNOX innovative clean coal technology demonstration. Volume 1, Sampling/results/special topics: Final report

    SciTech Connect (OSTI)

    Not Available

    1994-07-01

    This study was one of a group of assessments of toxic emissions from coal-fired power plants, conducted for DOE during 1993. The motivation for those assessments was the mandate in the 1990 Clean Air Act Amendments that a study be made of emissions of hazardous air pollutants (HAPs) from electric utilities. The report is organized in two volumes. Volume 1: Sampling describes the sampling effort conducted as the basis for this study; Results presents the concentration data on HAPs in the several power plant streams, and reports the results of evaluations and calculations conducted with those data; and Special Topics report on issues such as comparison of sampling methods and vapor/solid distributions of HAPs. Volume 2: Appendices include quality assurance/quality control results, uncertainty analysis for emission factors, and data sheets. This study involved measurements of a variety of substances in solid, liquid, and gaseous samples from input, output, and process streams at the Innovative Clean Coal Technology Demonstration (ICCT) of the Wet Sulfuric Acid-Selective Catalytic Reduction (SNOX) process. The SNOX demonstration is being conducted at Ohio Edison`s Niles Boiler No. 2 which uses cyclone burners to burn bituminous coal. A 35 megawatt slipstream of flue gas from the boiler is used to demonstrate SNOX. The substances measured at the SNOX process were the following: 1. Five major and 16 trace elements, including mercury, chromium, cadmium, lead, selenium, arsenic, beryllium, and nickel; 2. Acids and corresponding anions (HCl, HF, chloride, fluoride, phosphate, sulfate); 3. Ammonia and cyanide; 4. Elemental carbon; 5. Radionuclides; 6. Volatile organic compounds (VOC); 7. Semi-volatile compounds (SVOC) including polynuclear aromatic hydrocarbons (PAH); and 8. Aldehydes.

  18. EM Takes on Next Environmental Cleanup Challenge at SRS: Coal-Fired Ash

    Energy.gov [DOE]

    AIKEN, S.C. – A large, 1950s-era, coal-fired power plant sits cold and dark at the Savannah River Site (SRS), but employees with EM and its management and operations contractor are preparing to clean up the facility’s substantial quantities of ash generated over the decades.

  19. Secretary Chu Announces Up To $55 Million in Funding to Develop Advanced Carbon Capture Technology at Existing Coal-Fired Power Plants

    Energy.gov [DOE]

    U.S. Energy Secretary Steven Chu announced today that $55 million will be made available to develop advanced technologies that can capture carbon dioxide from flue gases at existing power plants so that the greenhouse gas may be sequestered or put to beneficial use.

  20. Retrofitted coal-fired firetube boiler and method employed therewith

    DOE Patents [OSTI]

    Wagoner, C.L.; Foote, J.P.

    1995-07-04

    A coal-fired firetube boiler and a method for converting a gas-fired firetube boiler to a coal-fired firetube boiler are disclosed. The converted boiler includes a plurality of combustion zones within the firetube and controlled stoichiometry within the combustion zones. 19 figs.

  1. Retrofitted coal-fired firetube boiler and method employed therewith

    DOE Patents [OSTI]

    Wagoner, Charles L.; Foote, John P.

    1995-01-01

    A coal-fired firetube boiler and a method for converting a gas-fired firetube boiler to a coal-fired firetube boiler, the converted boiler including a plurality of combustion zones within the firetube and controlled stoichiometry within the combustion zones.

  2. A Review of Hazardous Chemical Species Associated with CO2 Capturefrom Coal-Fired Power Plants and Their Potential Fate in CO2 GeologicStorage

    SciTech Connect (OSTI)

    Apps, J.A.

    2006-02-23

    Conventional coal-burning power plants are major contributors of excess CO2 to the atmospheric inventory. Because such plants are stationary, they are particularly amenable to CO2 capture and disposal by deep injection into confined geologic formations. However, the energy penalty for CO2 separation and compression is steep, and could lead to a 30-40 percent reduction in useable power output. Integrated gas combined cycle (IGCC) plants are thermodynamically more efficient, i.e.,produce less CO2 for a given power output, and are more suitable for CO2 capture. Therefore, if CO2 capture and deep subsurface disposal were to be considered seriously, the preferred approach would be to build replacement IGCC plants with integrated CO2 capture, rather than retrofit existing conventional plants. Coal contains minor quantities of sulfur and nitrogen compounds, which are of concern, as their release into the atmosphere leads to the formation of urban ozone and acid rain, the destruction of stratospheric ozone, and global warming. Coal also contains many trace elements that are potentially hazardous to human health and the environment. During CO2 separation and capture, these constituents could inadvertently contaminate the separated CO2 and be co-injected. The concentrations and speciation of the co-injected contaminants would differ markedly, depending on whether CO2 is captured during the operation of a conventional or an IGCC plant, and the specific nature of the plant design and CO2 separation technology. However, regardless of plant design or separation procedures, most of the hazardous constituents effectively partition into the solid waste residue. This would lead to an approximately two order of magnitude reduction in contaminant concentration compared with that present in the coal. Potential exceptions are Hg in conventional plants, and Hg and possibly Cd, Mo and Pb in IGCC plants. CO2 capture and injection disposal could afford an opportunity to deliberately capture

  3. Modeling of a coal-fired natural circulation boiler

    SciTech Connect (OSTI)

    Bhambare, K.S.; Mitra, S.K.; Gaitonde, U.N.

    2007-06-15

    Modeling of a natural circulation boiler for a coal-fired thermal power station is presented here. The boiler system is divided into seven subcomponents, and for each section, models based on conservation of mass, momentum, and energy are formulated. The pressure drop at various sections and the heat transfer coefficients are computed using empirical correlations. Solutions are obtained by using SIMULINK. The model is validated by comparing its steady state and dynamic responses with the actual plant data. Open loop responses of the model to the step changes in the operating parameters, such as pressure, temperature, steam flow, feed water flow, are also analyzed. The present model can be used for the development and design of effective boiler control systems.

  4. Developing Engineered Fuel (Briquettes) Using Fly Ash from the Aquila Coal-Fired Power Plant in Canon City and Locally Available Biomass Waste

    SciTech Connect (OSTI)

    H. Carrasco; H. Sarper

    2006-06-30

    the system without requiring any equipment or process changes. (10) Although the above attempt failed, the plant is still interested in producing briquettes. (11) An economic analysis of investing in a production facility manufacturing such briquettes was conducted to determine the economic viability of the project. Such a project is estimated to have an internal rate of return of 14% and net present value of about $400,000. (12) An engineering independent study class (4 students) is now working on selecting a site near the power plant and determining the layout of the future plant that will produce briquettes.

  5. Tracking New Coal-Fired Power Plants

    U.S. Department of Energy (DOE) all webpages (Extended Search)

    ... Capacity (GW) Figure 10 Source: USA data - Ventyx - Velocity Suite (12132010) China data - Platts - UDI WEPPDB 2010 Online Year Results are Stacked 209 GW of Undetermined Dates ...

  6. Prestigious Coal-Fired Project of the Year Award Goes to Plant Demonstrating Innovative DOE-Funded Technology

    Energy.gov [DOE]

    An innovative project demonstrating DryFining™ technology, a more cost-effective way to control coal-based power plant emissions while improving fuel quality, has been named the 2010 Coal-Fired Project of the Year by the editors of Power Engineering magazine.

  7. Options for reducing a coal-fired plant's carbon footprint: Part. 1

    SciTech Connect (OSTI)

    Zachary, J.

    2008-06-15

    Caps on greenhouse gas emissions are imminent in the US and they will change how we design tomorrow's coal-fired power plants. Efforts are already under way to develop alternative capture and sequestration technologies, mainly for CO{sub 2}. Unfortunately, the proposed processes all consume lots of energy, reducing plants' net output and efficiency. In Part 1 of our look at these technologies, we list and quantify the impacts of post combustion removal of CO{sub 2} from a coal plant's flue gas. Next month, in Part. 2 we will do the same for four other CO{sub 2} reduction techniques: oxyfuel combustion, using higher-temperature and higher-pressure boilers, cofiring biomass, and replacing some coal-fired capacity with renewable capacity. 10 figs., 4 tabs.

  8. Parameters affecting nitrogen oxides in a Coal-Fired Flow Facility system

    SciTech Connect (OSTI)

    Lu, Xiaoliang

    1996-03-01

    The unusually high temperature in the primary combustor of the Coal-Fired Magnetohydrodynamics (MHD) power generation system causes much higher nitrogen oxides (NO{sub x}) to be produced than in a conventional coal fired generation system. In order to lower the NO{sub x} concentration to an acceptable level, it is important to know how parameters of the MM power generation system affect the NO{sub x} concentration. This thesis investigates those effects in the Coal-Fired Flow Facility (CFFF) at the University of Tennessee Space Institute under the contract of US Department Of Energy (DOE). With thermodynamic and kinetic computer codes, the theoretical studies were carried out on the parameters of the CFFF system. The results gathered from the computer codes were analyzed and compared with the experimental data collected during the LMF5J test. The thermodynamic and kinetic codes together modeled the NO.{sub x} behavior with reasonable accuracy while some inconsistencies happened at the secondary combustor inlet.

  9. Geology of coal fires: case studies from around the world

    SciTech Connect (OSTI)

    Glenn B. Stracher

    2008-01-15

    Coal fires are preserved globally in the rock record as burnt and volume-reduced coal seams and by pyrometamorphic rocks, explosion breccias, clinker, gas-vent-mineral assemblages, fire-induced faulting, ground fissures, slump blocks, and sinkholes. Coal fires are responsible for coronary and respiratory diseases and fatalities in humans, as well as arsenic and fluorine poisoning. Their heat energy, toxic fumes, and solid by-products of combustion destroy floral and faunal habitats while polluting the air, water, and soil. This volume includes chapters devoted to spontaneous combustion and greenhouse gases, gas-vent mineralogy and petrology, paralavas and combustion metamorphic rocks, geochronology and landforms, magnetic signatures and geophysical modeling, remote-sensing detection and fire-depth estimation of concealed fires, and coal fires and public policy.

  10. Advanced Development Of The Coal Fired Oxyfuel Process With CO2...

    Open Energy Information (Open El) [EERE & EIA]

    Development Of The Coal Fired Oxyfuel Process With CO2 Separation ADECOS Jump to: navigation, search Name: Advanced Development Of The Coal-Fired Oxyfuel Process With CO2...

  11. Steam Plant Replaces Outdated Coal-Fired System | Department of Energy

    Office of Energy Efficiency and Renewable Energy (EERE) (indexed site)

    Steam Plant Replaces Outdated Coal-Fired System Steam Plant Replaces Outdated Coal-Fired System September 1, 2012 - 12:00pm Addthis A new natural gas-fired steam plant will replace an older coal-fired steam plant shown here. The new plant has the capacity to heat buildings at the Portsmouth site much more efficiently than the old coal-fired steam plant. A new natural gas-fired steam plant will replace an older coal-fired steam plant shown here. The new plant has the capacity to heat buildings at

  12. Retrofit costs for SO sub 2 and NOx control options at 200 coal-fired plants

    SciTech Connect (OSTI)

    Not Available

    1990-11-01

    This 5-volume report gives the results of site-specific cost estimations for retrofitting six control technologies to coal-fired power plants. The six technologies were: lime/limestone flue gas desulfurization, lime spray drying, coal switching and cleaning, furnace and duct sorbent injection, low NOx combustion or natural gas reburning, and selective catalytic reduction. Volume 1 gives the methodology. The other four volumes each cover 5-7 specific states east of the Mississippi River. Maine, Vermont, Rhode Island, and Connecticut are not included.

  13. EVALUATION OF CARBON DIOXIDE CAPTURE FROM EXISTING COAL FIRED PLANTS BY HYBRID SORPTION USING SOLID SORBENTS

    SciTech Connect (OSTI)

    Benson, Steven; Browers, Bruce; Srinivasachar, Srivats; Laudal, Daniel

    2014-12-31

    Under contract DE-FE0007603, the University of North Dakota conducted the project Evaluation of Carbon Dioxide Capture from Existing Coal Fired Plants by Hybrid Sorption Using Solid Sorbents. As an important element of this effort, a Technical and Economic Feasibility Study was conducted by Barr Engineering Co. (Barr) in association with the University of North Dakota. The assessment developed a process flow diagram, major equipment list, heat balances for the SCPC power plant, capital cost estimate, operating cost estimate, levelized cost of electricity, cost of CO2 capture ($/ton) and three sensitivity cases for the CACHYS™ process.

  14. Retrofit costs for lime/limestone FGD and lime spray drying at coal-fired utility boilers

    SciTech Connect (OSTI)

    Emmel, T.E.; Jones, J.W.

    1990-01-01

    The paper gives results of a research program the objective of which was to significantly improve engineering cost estimates currently being used to evaluate the economic effects of applying SO2 controls to existing coal-fired utility boilers. The costs of retrofitting conventional lime/limestone wet flue gas desulfurization (L/LS FGD) and lime spray drying (LSD) FGD at 100-200 coal-fired power plants are being estimated under this program. The retrofit capital cost estimating procedures used for L/LS FGD and LSD FGD make two cost adjustments to current procedures used to estimate FGD costs: cost adders (for items not normally included in FGD system costs; e.g., demolition and relocation of existing facilities) and cost multipliers (to adjust capital costs for site access, congestion, and underground obstructions).

  15. Clean coal technology: selective catalytic reduction (SCR) technology for the control of nitrogen oxide emissions from coal-fired boilers

    SciTech Connect (OSTI)

    2005-05-01

    The report discusses a project carried out under the US Clean Coal Technology (CCT) Demonstration Program which demonstrated selective catalytic reduction (SCR) technology for the control of NOx emissions from high-sulphur coal-fired boilers under typical boilers conditions in the United States. The project was conducted by Southern Company Services, Inc., who served as a co-funder and as the host at Gulf Power Company's Plant Crist. The SCR process consists of injecting ammonia (NH{sub 3}) into boiler flue gas and passing the flue gas through a catalyst bed where the Nox and NH{sub 3} react to form nitrogen and water vapor. The results of the CCTDP project confirmed the applicability of SCR for US coal-fired power plants. In part as a result of the success of this project, a significant number of commercial SCR units have been installed and are operating successfully in the United States. By 2007, the total installed SCR capacity on US coal-fired units will number about 200, representing about 100,000 MWe of electric generating capacity. This report summarizes the status of SCR technology. 21 refs., 3 figs., 2 tabs., 10 photos.

  16. Total integrated NOx compliance for existing pulverized coal-fired units

    SciTech Connect (OSTI)

    Camody, G.; Lewis, R.; Cohen, M.B.; Buschmann, J.; Hilton, R.; Larsson, A.C.; Tobiasz, R.

    1999-07-01

    The EPA Title 1 NOx emission limits along with the corresponding OTR regulations are mandating coal-fired NOx emission levels below 0.15 lb/MBtu. For tangentially fired units, experience has shown that the technology is currently available to achieve these limits. The question for each unit owner-operator becomes; what is the most economical technology or combination of technologies to achieve the required results? This paper provides a brief overview of Combustion Engineering, Inc.'s (ABB C-E) latest NOx control technologies, both in-furnace and post-combustion, for tangential coal-fired steam generators. The paper further reviews options of both stand-alone and combined multiple technologies to achieve the most cost-effective NOx compliance, while maintaining the high levels of unit efficiency and performance that is required to by successful in their deregulated power industry. Current operational data of both in-furnace and SCR NOx reduction systems are presented, as well as the latest historical cost data for the systems.

  17. ULTRA LOW NOx INTEGRATED SYSTEM FOR NOx EMISSION CONTROL FROM COAL-FIRED BOILERS

    SciTech Connect (OSTI)

    Galen H. Richards; Charles Q. Maney; Richard W. Borio; Robert D. Lewis

    2002-12-30

    ALSTOM Power Inc.'s Power Plant Laboratories, working in concert with ALSTOM Power's Performance Projects Group, has teamed with the U.S. Department of Energy's National Energy Technology Laboratory (DOE NETL) to conduct a comprehensive study to develop/evaluate low-cost, efficient NOx control technologies for retrofit to pulverized coal fired utility boilers. The objective of this project was to develop retrofit NOx control technology to achieve less than 0.15 lb/MMBtu NOx (for bituminous coals) and 0.10 lb/MMBtu NOx (for subbituminous coals) from existing pulverized coal fired utility boilers at a cost which is at least 25% less than SCR technology. Efficient control of NOx is seen as an important, enabling step in keeping coal as a viable part of the national energy mix in this century, and beyond. Presently 57% of U.S. electrical generation is coal based, and the Energy Information Agency projects that coal will maintain a lead in U.S. power generation over all other fuel sources for decades (EIA 1998 Energy Forecast). Yet, coal-based power is being strongly challenged by society's ever-increasing desire for an improved environment and the resultant improvement in health and safety. The needs of the electric-utility industry are to improve environmental performance, while simultaneously improving overall plant economics. This means that emissions control technology is needed with very low capital and operating costs. This project has responded to the industry's need for low NOx emissions by evaluating ideas that can be adapted to present pulverized coal fired systems, be they conventional or low NOx firing systems. The TFS 2000{trademark} firing system has been the ALSTOM Power Inc. commercial offering producing the lowest NOx emission levels. In this project, the TFS 2000{trademark} firing system served as a basis for comparison to other low NOx systems evaluated and was the foundation upon which refinements were made to further improve NOx emissions and

  18. City of Mansfield, Georgia (Utility Company) | Open Energy Information

    Open Energy Information (Open El) [EERE & EIA]

    search Name: City of Mansfield Place: Georgia Website: www.mansfieldga.comutilities. Facebook: https:www.facebook.commansfieldga Outage Hotline: 770-710-8235 References: EIA...

  19. Mansfield Municipal Electric Department- Residential Energy Efficiency Rebate Program

    Energy.gov [DOE]

    Mansfield Municipal Electric Department encourages energy efficiency through the ENERGY STAR Appliance Rebate Incentive Program. Cash rebates are offered for ENERGY STAR central air conditioners,...

  20. Slag processing system for direct coal-fired gas turbines

    DOE Patents [OSTI]

    Pillsbury, Paul W.

    1990-01-01

    Direct coal-fired gas turbine systems and methods for their operation are provided by this invention. The systems include a primary combustion compartment coupled to an impact separator for removing molten slag from hot combustion gases. Quenching means are provided for solidifying the molten slag removed by the impact separator, and processing means are provided forming a slurry from the solidified slag for facilitating removal of the solidified slag from the system. The released hot combustion gases, substantially free of molten slag, are then ducted to a lean combustion compartment and then to an expander section of a gas turbine.

  1. Characterizing and Modelling Cycling Operations in Coal-fired Units

    U.S. Energy Information Administration (EIA) (indexed site)

    Driving Innovation ♦ Delivering Results National Energy Technology Laboratory Characterizing and Modeling Cycling Operations in Coal-fired Units June 2016 Chris Nichols Systems Engineering & Analysis Directorate EIA Modeling Meeting 2 National Energy Technology Laboratory 0 10 20 30 40 50 60 70 80 90 100 0 5 10 15 20 25 30 35 40 45 50 55 60 65 70 75 80 85 Average capacity factor (%) Unit age in years Average capacity factor by unit age for coal operations, 1998-2013 The "Over the

  2. Dine Power Authority (DPA)

    Office of Energy Efficiency and Renewable Energy (EERE) (indexed site)

    ... Use state-of-the-art technology, Highly efficient, environmentally-friendly, coal-fired power plant which meets applicable regulatory standards Efficient and optimum use of ...

  3. Life Cycle Greenhouse Gas Emissions of Coal-Fired Electricity Generation: Systematic Review and Harmonization

    SciTech Connect (OSTI)

    Whitaker, M.; Heath, G. A.; O'Donoughue, P.; Vorum, M.

    2012-04-01

    This systematic review and harmonization of life cycle assessments (LCAs) of utility-scale coal-fired electricity generation systems focuses on reducing variability and clarifying central tendencies in estimates of life cycle greenhouse gas (GHG) emissions. Screening 270 references for quality LCA methods, transparency, and completeness yielded 53 that reported 164 estimates of life cycle GHG emissions. These estimates for subcritical pulverized, integrated gasification combined cycle, fluidized bed, and supercritical pulverized coal combustion technologies vary from 675 to 1,689 grams CO{sub 2}-equivalent per kilowatt-hour (g CO{sub 2}-eq/kWh) (interquartile range [IQR]= 890-1,130 g CO{sub 2}-eq/kWh; median = 1,001) leading to confusion over reasonable estimates of life cycle GHG emissions from coal-fired electricity generation. By adjusting published estimates to common gross system boundaries and consistent values for key operational input parameters (most importantly, combustion carbon dioxide emission factor [CEF]), the meta-analytical process called harmonization clarifies the existing literature in ways useful for decision makers and analysts by significantly reducing the variability of estimates ({approx}53% in IQR magnitude) while maintaining a nearly constant central tendency ({approx}2.2% in median). Life cycle GHG emissions of a specific power plant depend on many factors and can differ from the generic estimates generated by the harmonization approach, but the tightness of distribution of harmonized estimates across several key coal combustion technologies implies, for some purposes, first-order estimates of life cycle GHG emissions could be based on knowledge of the technology type, coal mine emissions, thermal efficiency, and CEF alone without requiring full LCAs. Areas where new research is necessary to ensure accuracy are also discussed.

  4. Slag processing system for direct coal-fired gas turbines

    DOE Patents [OSTI]

    Pillsbury, Paul W.

    1990-01-01

    Direct coal-fired gas turbine systems and methods for their operation are provided by this invention. The gas turbine system includes a primary zone for burning coal in the presence of compressed air to produce hot combustion gases and debris, such as molten slag. The turbine system further includes a secondary combustion zone for the lean combustion of the hot combustion gases. The operation of the system is improved by the addition of a cyclone separator for removing debris from the hot combustion gases. The cyclone separator is disposed between the primary and secondary combustion zones and is in pressurized communication with these zones. In a novel aspect of the invention, the cyclone separator includes an integrally disposed impact separator for at least separating a portion of the molten slag from the hot combustion gases.

  5. Coal-fired boiler costs for industrial applications

    SciTech Connect (OSTI)

    Kurzius, S.C.; Barnes, R.W.

    1982-04-01

    Several of the current sources of information provide data on coal-fired steam boiler costs. As published, these data give widely varying and possibly inconsistent conclusions. This study was undertaken to determine the extent to which the differences in the various sets of published data bases could be resolved and, if possible, to arrive at more reliable cost correlations to be used in Oak Ridge Energy Demand Models. Our principal finding is that it is indeed possible to restate the costs within each data base on a more consistent basis. When this is done, reasonable engineering correlations of all the cost data versus steam plant capacity can be made over the 10,000 to 5000,000 lb/hr range.

  6. COAL-FIRED UTILITY BOILERS: SOLVING ASH DEPOSITION PROBLEMS

    SciTech Connect (OSTI)

    Christopher J. Zygarlicke; Donald P. McCollor; Steven A. Benson; Jay R. Gunderson

    2001-04-01

    The accumulation of slagging and fouling ash deposits in utility boilers has been a source of aggravation for coal-fired boiler operators for over a century. Many new developments in analytical, modeling, and combustion testing methods in the past 20 years have made it possible to identify root causes of ash deposition. A concise and comprehensive guidelines document has been assembled for solving ash deposition as related to coal-fired utility boilers. While this report accurately captures the current state of knowledge in ash deposition, note that substantial research and development is under way to more completely understand and mitigate slagging and fouling. Thus, while comprehensive, this document carries the title ''interim,'' with the idea that future work will provide additional insight. Primary target audiences include utility operators and engineers who face plant inefficiencies and significant operational and maintenance costs that are associated with ash deposition problems. Pulverized and cyclone-fired coal boilers are addressed specifically, although many of the diagnostics and solutions apply to other boiler types. Logic diagrams, ash deposit types, and boiler symptoms of ash deposition are used to aid the user in identifying an ash deposition problem, diagnosing and verifying root causes, determining remedial measures to alleviate or eliminate the problem, and then monitoring the situation to verify that the problem has been solved. In addition to a step-by-step method for identifying and remediating ash deposition problems, this guideline document (Appendix A) provides descriptions of analytical techniques for diagnostic testing and gives extensive fundamental and practical literature references and addresses of organizations that can provide help in alleviating ash deposition problems.

  7. Characterizing toxic emissions from a coal-fired power plant demonstrating the AFGD ICCT Project and a plant utilizing a dry scrubber/baghouse system: Bailly Station Units 7 and 8 and AFGD ICCT Project. Final report. Final report

    SciTech Connect (OSTI)

    Dismukes, E.B.

    1994-10-20

    This report describes results of assessment of the risk of emissions of hazardous air pollutants at one of the electric power stations, Bailly Station, which is also the site of a Clean Coal Technology project demonstrating the Pure Air Advanced Flue Gas Desulfurization process (wet limestone). This station represents the configuration of no NO{sub x} reduction, particulate control with electrostatic precipitators, and SO{sub 2} control with a wet scrubber. The test was conducted September 3--6, 1993. Sixteen trace metals were determined along with 5 major metals. Other inorganic substances and organic compounds were also determined.

  8. Quantitative Analysis of Variability and Uncertainty in Environmental Data and Models. Volume 2. Performance, Emissions, and Cost of Combustion-Based NOx Controls for Wall and Tangential Furnace Coal-Fired Power Plants

    SciTech Connect (OSTI)

    Frey, H. Christopher; Tran, Loan K.

    1999-04-30

    This is Volume 2 of a two-volume set of reports describing work conducted at North Carolina State University sponsored by Grant Number DE-FG05-95ER30250 by the U.S. Department of Energy. The title of the project is “Quantitative Analysis of Variability and Uncertainty in Acid Rain Assessments.” The work conducted under sponsorship of this grant pertains primarily to two main topics: (1) development of new methods for quantitative analysis of variability and uncertainty applicable to any type of model; and (2) analysis of variability and uncertainty in the performance, emissions, and cost of electric power plant combustion-based NOx control technologies. These two main topics are reported separately in Volumes 1 and 2.

  9. Engineering development of advanced coal-fired low-emissions boiler system. Phase II subsystem test design and plan - an addendum to the Phase II RD & T Plan

    SciTech Connect (OSTI)

    1995-05-01

    Shortly after the year 2000 it is expected that new generating plants will be needed to meet the growing demand for electricity and to replace the aging plants that are nearing the end of their useful service life. The plants of the future will need to be extremely clean, highly efficient and economical. Continuing concerns over acid rain, air toxics, global climate changes, ozone depletion and solid waste disposal are expected to further then regulations. In the late 1980`s it was commonly believed that coal-fired power plants of the future would incorporate either some form of Integrated Gasification Combined Cycle (IGCC) or first generation Pressurized Fluidized Bed Combustion (PFBS) technologies. However, recent advances In emission control techniques at reduced costs and auxiliary power requirements coupled with significant improvements In steam turbine and cycle design have clearly indicated that pulverized coal technology can continue to be competitive In both cost and performance. In recognition of the competitive potential for advanced pulverized coal-fired systems with other emerging advanced coal-fired technologies, DOE`s Pittsburgh Energy Technology Center (PETC) began a research and development initiative In late 1990 named, Combustion 2000, with the intention of preserving and expanding coal as a principal fuel In the Generation of electrical power. The project was designed for two stages of commercialization, the nearer-term Low Emission Boiler System (LEBS) program, and for the future, the High Performance Power System (HIPPS) program. B&W is participating In the LEBS program.

  10. EA-1183: Coal-fired Diesel Generator University of Alaska, Fairbanks, Alaska

    Energy.gov [DOE]

    This EA evaluates the environmental impacts for the proposal to provide funds to support the construction and operation of a coal-fired diesel generator at the University of Alaska, Fairbanks.

  11. Life Cycle Assessment of Coal-fired Power Production

    Office of Scientific and Technical Information (OSTI)

    case. It was found that the transportation distance has a significant effect on the oil consumption, a few of the systems emissions, and the energy consumption, whereas the...

  12. Development and Testing of Industrial Scale Coal Fired Combustion System, Phase 3

    SciTech Connect (OSTI)

    Bert Zauderer

    1998-09-30

    Coal Tech Corp's mission is to develop, license & sell innovative, lowest cost, solid fuel fired power systems & total emission control processes using proprietary and patented technology for domestic and international markets. The present project 'DEVELOPMENT & TESTING OF INDUSTRIAL SCALE, COAL FIRED COMBUSTION SYSTEM, PHASE 3' on DOE Contract DE-AC22-91PC91162 was a key element in achieving this objective. The project consisted of five tasks that were divided into three phases. The first phase, 'Optimization of First Generation 20 MMBtu/hr Air-Cooled Slagging Coal Tech Combustor', consisted of three tasks, which are detailed in Appendix 'A' of this report. They were implemented in 1992 and 1993 at the first generation, 20 MMBtu/hour, combustor-boiler test site in Williamsport, PA. It consisted of substantial combustor modifications and coal-fired tests designed to improve the combustor's wall cooling, slag and ash management, automating of its operation, and correcting severe deficiencies in the coal feeding to the combustor. The need for these changes was indicated during the prior 900-hour test effort on this combustor that was conducted as part of the DOE Clean Coal Program. A combination of combustor changes, auxiliary equipment changes, sophisticated multi-dimensional combustion analysis, computer controlled automation, and series of single and double day shift tests totaling about 300 hours, either resolved these operational issues or indicated that further corrective changes were needed in the combustor design. The key result from both analyses and tests was that the combustor must be substantially lengthened to maximize combustion efficiency and sharply increase slag retention in the combustor. A measure of the success of these modifications was realized in the third phase of this project, consisting of task 5 entitled: 'Site Demonstration with the Second Generation 20 MMBtu/hr Air-Cooled Slagging Coal Tech Combustor'. The details of the task 5 effort are

  13. Evaluation of activated carbon for control of mercury from coal-fired boilers

    SciTech Connect (OSTI)

    Miller, S.; Laudal, D.; Dunham, G.

    1995-11-01

    The ability to remove mercury from power plant flue gas may become important because of the Clean Air Act amendments` requirement that the U.S. Environmental Protection Agency (EPA) assess the health risks associated with these emissions. One approach for mercury removal, which may be relatively simple to retrofit, is the injection of sorbents, such as activated carbon, upstream of existing particulate control devices. Activated carbon has been reported to capture mercury when injected into flue gas upstream of a spray dryer baghouse system applied to waste incinerators or coal-fired boilers. However, the mercury capture ability of activated carbon injected upstream of an electrostatic precipitator (ESP) or baghouse operated at temperatures between 200{degrees} and 400{degrees}F is not well known. A study sponsored by the U.S. Department of Energy and the Electric power Research Institute is being conducted at the University of North Dakota Energy & Environmental Research Center (EERC) to evaluate whether mercury control with sorbents can be a cost-effective approach for large power plants. Initial results from the study were reported last year. This paper presents some of the recent project results. Variables of interest include coal type, sorbent type, sorbent addition rate, collection media, and temperature.

  14. A study of toxic emissions from a coal-fired gasification plant. Final report

    SciTech Connect (OSTI)

    1995-12-01

    Under the Fine Particulate Control/Air Toxics Program, the US Department of Energy (DOE) has been performing comprehensive assessments of toxic substance emissions from coal-fired electric utility units. An objective of this program is to provide information to the US Environmental Protection Agency (EPA) for use in evaluating hazardous air pollutant emissions as required by the Clean Air Act Amendments (CAAA) of 1990. The Electric Power Research Institute (EPRI) has also performed comprehensive assessments of emissions from many power plants and provided the information to the EPA. The DOE program was implemented in two. Phase 1 involved the characterization of eight utility units, with options to sample additional units in Phase 2. Radian was one of five contractors selected to perform these toxic emission assessments.Radian`s Phase 1 test site was at southern Company Service`s Plant Yates, Unit 1, which, as part of the DOE`s Clean Coal Technology Program, was demonstrating the CT-121 flue gas desulfurization technology. A commercial-scale prototype integrated gasification-combined cycle (IGCC) power plant was selected by DOE for Phase 2 testing. Funding for the Phase 2 effort was provided by DOE, with assistance from EPRI and the host site, the Louisiana Gasification Technology, Inc. (LGTI) project This document presents the results of that effort.

  15. Evaluation of Mercury Emissions from Coal-Fired Facilities with SCR and FGD Systems

    SciTech Connect (OSTI)

    J. A. Withum; J. E. Locke

    2006-02-01

    CONSOL Energy Inc., Research & Development (CONSOL), with support from the U.S. Department of Energy, National Energy Technology Laboratory (DOE) and the Electric Power Research Institute (EPRI), is evaluating the effects of selective catalytic reduction (SCR) on mercury (Hg) capture in coal-fired plants equipped with an electrostatic precipitator (ESP)--wet flue gas desulfurization (FGD) combination or a spray dyer absorber--fabric filter (SDA-FF) combination. In this program CONSOL is determining mercury speciation and removal at 10 coal-fired facilities. The principal purpose of this work is to develop a better understanding of the potential mercury removal ''co-benefits'' achieved by NO{sub x}, and SO{sub 2} control technologies. It is expected that this data will provide the basis for fundamental scientific insights into the nature of mercury chemistry in flue gas, the catalytic effect of SCR systems on mercury speciation and the efficacy of different FGD technologies for mercury capture. Ultimately, this insight could help to design and operate SCR and FGD systems to maximize mercury removal. The objectives are (1) to evaluate the effect of SCR on mercury capture in the ESP-FGD and SDA-FF combinations at coal-fired power plants, (2) evaluate the effect of SCR catalyst degradation on mercury capture; (3) evaluate the effect of low load operation on mercury capture in an SCR-FGD system, and (4) collect data that could provide the basis for fundamental scientific insights into the nature of mercury chemistry in flue gas, the catalytic effect of SCR systems on mercury speciation and the efficacy of different FGD technologies for mercury capture. This document, the tenth in a series of topical reports, describes the results and analysis of mercury sampling performed on two 468 MW units burning bituminous coal containing 1.3-1.7% sulfur. Unit 2 is equipped with an SCR, ESP, and wet FGD to control NO{sub x}, particulate, and SO{sub 2} emissions, respectively. Unit 1

  16. EVALUATION OF MERCURY EMISSIONS FROM COAL-FIRED FACILITIES WITH SCR AND FGD SYSTEMS

    SciTech Connect (OSTI)

    J.A. Withum; S.C. Tseng; J.E. Locke

    2005-11-01

    CONSOL Energy Inc., Research & Development (CONSOL), with support from the U.S. Department of Energy, National Energy Technology Laboratory (DOE) and the Electric Power Research Institute (EPRI), is evaluating the effects of selective catalytic reduction (SCR) on mercury (Hg) capture in coal-fired plants equipped with an electrostatic precipitator (ESP)--wet flue gas desulfurization (FGD) combination or a spray dryer absorber--fabric filter (SDA-FF) combination. In this program CONSOL is determining mercury speciation and removal at 10 coal-fired facilities. The objectives are (1) to evaluate the effect of SCR on mercury capture in the ESP-FGD and SDA-FF combinations at coal-fired power plants, (2) evaluate the effect of catalyst degradation on mercury capture; (3) evaluate the effect of low load operation on mercury capture in an SCR-FGD system, and (4) collect data that could provide the basis for fundamental scientific insights into the nature of mercury chemistry in flue gas, the catalytic effect of SCR systems on mercury speciation and the efficacy of different FGD technologies for mercury capture. This document, the seventh in a series of topical reports, describes the results and analysis of mercury sampling performed on a 1,300 MW unit burning a bituminous coal containing three percent sulfur. The unit was equipped with an ESP and a limestone-based wet FGD to control particulate and SO2 emissions, respectively. At the time of sampling an SCR was not installed on this unit. Four sampling tests were performed in September 2003. Flue gas mercury speciation and concentrations were determined at the ESP outlet (FGD inlet), and at the stack (FGD outlet) using the Ontario Hydro method. Process stream samples for a mercury balance were collected to coincide with the flue gas measurements. The results show that the FGD inlet flue gas oxidized:elemental mercury ratio was roughly 2:1, with 66% oxidized mercury and 34% elemental mercury. Mercury removal, on a coal

  17. Evaluation of Mercury Emissions from Coal-Fired Facilities with SCR and FGD Systems

    SciTech Connect (OSTI)

    J. A. Withum; S. C. Tseng; J. E. Locke

    2006-01-31

    CONSOL Energy Inc., Research & Development (CONSOL), with support from the U.S. Department of Energy, National Energy Technology Laboratory (DOE) and the Electric Power Research Institute (EPRI), is evaluating the effects of selective catalytic reduction (SCR) on mercury (Hg) capture in coal-fired plants equipped with an electrostatic precipitator (ESP)--wet flue gas desulfurization (FGD) combination or a spray dyer absorber--fabric filter (SDA-FF) combination. In this program CONSOL is determining mercury speciation and removal at 10 coal-fired facilities. The principal purpose of this work is to develop a better understanding of the potential mercury removal ''co-benefits'' achieved by NO{sub x}, and SO{sub 2} control technologies. It is expected that these data will provide the basis for fundamental scientific insights into the nature of mercury chemistry in flue gas, the catalytic effect of SCR systems on mercury speciation and the efficacy of different FGD technologies for mercury capture. Ultimately, this insight could help to design and operate SCR and FGD systems to maximize mercury removal. The objectives are (1) to evaluate the effect of SCR on mercury capture in the ESP-FGD and SDA-FF combinations at coal-fired power plants, (2) evaluate the effect of SCR catalyst degradation on mercury capture; (3) evaluate the effect of low load operation on mercury capture in an SCR-FGD system, and (4) collect data that could provide the basis for fundamental scientific insights into the nature of mercury chemistry in flue gas, the catalytic effect of SCR systems on mercury speciation and the efficacy of different FGD technologies for mercury capture. This document, the ninth in a series of topical reports, describes the results and analysis of mercury sampling performed on Unit 1 at Plant 7, a 566 MW unit burning a bituminous coal containing 3.6% sulfur. The unit is equipped with a SCR, ESP, and wet FGD to control NO{sub x}, particulate, and SO{sub 2} emissions

  18. The worldwide applicability of B and W`s advanced coal-fired low-emission boiler system

    SciTech Connect (OSTI)

    McDonald, D.K.; Madden, D.A.; Sivy, J.L.

    1996-12-31

    Babcock and Wilcox, under contract to the US Department of Energy (DOE), has been developing an advanced generating plant design in DOE`s Combustion 2000 program entitled, Engineering Development of Advanced Coal-Fired Low Emission Boiler System. The objective of the LEBS program is to develop an advanced pulverized coal (PC) fired power generation system for commercial application by the year 2000. Since concerns over acid rain, air toxics, global climate changes, ozone depletion and solid waste disposal are expected to further tighten regulations for new coal-fired plants, the system must achieve very low emissions and high cycle efficiency at a life cycle cost equivalent to a conventional PC plant meeting New Source Performance Standards (NSPS). B and W has coupled advanced environmental control technologies capable of achieving emissions or NO{sub x}, SO{sub x}, and particulate far below current NSPS with an advanced boiler equipped with improved combustion and heat transfer subsystems to meet this objective. The B and W LEBS plant uses conventional state-of-the-art equipment along with developing new technologies to meet the program goals. This combustion of new and proven technologies allows B and W to meet the current demands in the marketplace. This paper describes B and W`s advanced generating plant design and its relevance to both the foreign and domestic markets.

  19. NO{sub x} controls for coal-fired utility boilers in East Central Europe

    SciTech Connect (OSTI)

    Eskinazi, D.; Tavoulareas, E.S.

    1995-12-01

    Increasing environmental pressures worldwide, including East Central Europe are placing greater emphasis on NO{sub x} emission controls in utility power plants. Western Europe, Japan and the U.S. have significant experience in applying NO{sub x} controls, especially in boilers firing hard coal. Some countries in Europe (i.e., Germany and Austria), have gained experience in applying NO{sub x} controls in boilers firing low-rank coal. This experience can be applied to East Central European countries in providing the basis for planning NO{sub x} control projects, suggesting cost-effective solutions, and providing lessons learned. However, while the experience is generally applicable to East Central European countries, differences in boiler design, operation and coal characteristics also need to be considered. This paper begins with a comparison of the NO{sub x} regulations, identifies the key NO{sub x} control technologies and the worldwide experience with them, and discusses the achievable NO{sub x} reduction, O&M impacts, and retrofit costs for each technology. Emphasis is placed on retrofit applications for existing boilers, because new coal-fired power plants are not expected to be built for the next 5-10 years. This paper also focuses on technologies with relatively low cost and operational simplicity: combustion system tuning/optimization. low-NO{sub x} burners (LNB), overfire air (OFA), selective non-catalytic reduction (SNCR), and reburning.

  20. Characterization of Oxy-combustion Impacts in Existing Coal-fired Boilers

    SciTech Connect (OSTI)

    Bradley Adams; Andrew Fry; Constance Senior; Hong Shim; Huafeng Wang; Jost Wendt; Christopher Shaddix

    2009-06-30

    fouling mechanisms in coal-fired power plants to understand key issues influencing these deposition regimes and infer their behavior under oxy-fired conditions. Based on the results of this survey, an algorithm for integrating slagging predictions into CFD models was outlined. This method accounts for ash formation, particle impaction and sticking, deposit growth and physical properties and impact of the deposit on system flow and heat transfer. A model for fouling in the back pass has also been identified which includes vaporization of sodium, deposition of sodium sulfate on fly ash particles and tube surfaces, and deposit growth rate on tubes. In Year 1, REI has also performed a review of the literature describing corrosion in order to understand the behavior of oxidation, sulfidation, chloridation, and carburization mechanisms in air-fired and oxy-combustion systems. REI and Vattenfall have met and exchanged information concerning oxy-coal combustion mechanisms for CFD simulations currently used by Vattenfall. In preparation for Year 2 of this program, two coals (North Antelope PRB, Western bituminous) have been ordered, pulverized and delivered to the University of Utah and Sandia National Labs. Materials for the corrosion experiments have been identified, suppliers located, and a schedule for equipment fabrication and shakedown has been established. Finally, a flue gas recycle system has been designed and is being constructed for the OFC.

  1. EVALUATION OF MERCURY EMISSIONS FROM COAL-FIRED FACILITIES WITH SCR AND FGD SYSTEMS

    SciTech Connect (OSTI)

    J. A. Withum; S.C. Tseng; J. E. Locke

    2004-10-31

    CONSOL Energy Inc., Research & Development (CONSOL), with support from the U.S. Department of Energy, National Energy Technology Laboratory (DOE) is evaluating the effects of selective catalytic reduction (SCR) on mercury (Hg) capture in coal-fired plants equipped with an electrostatic precipitator (ESP) - wet flue gas desulfurization (FGD) combination or a spray dyer absorber--fabric filter (SDA-FF) combination. In this program CONSOL is determining mercury speciation and removal at 10 coal-fired facilities. The objectives are (1) to evaluate the effect of SCR on mercury capture in the ESP-FGD and SDA-FF combinations at coal-fired power plants, (2) evaluate the effect of catalyst degradation on mercury capture; (3) evaluate the effect of low load operation on mercury capture in an SCR-FGD system, and (4) collect data that could provide the basis for fundamental scientific insights into the nature of mercury chemistry in flue gas, the catalytic effect of SCR systems on Hg speciation and the efficacy of different FGD technologies for Hg capture. This document, the second in a series of topical reports, describes the results and analysis of mercury sampling performed on a 330 MW unit burning a bituminous coal containing 1.0% sulfur. The unit is equipped with a SCR system for NOx control and a spray dryer absorber for SO{sub 2} control followed by a baghouse unit for particulate emissions control. Four sampling tests were performed in March 2003. Flue gas mercury speciation and concentrations were determined at the SCR inlet, air heater outlet (ESP inlet), and at the stack (FGD outlet) using the Ontario Hydro method. Process stream samples for a mercury balance were collected to coincide with the flue gas measurements. Due to mechanical problems with the boiler feed water pumps, the actual gross output was between 195 and 221 MW during the tests. The results showed that the SCR/air heater combination oxidized nearly 95% of the elemental mercury. Mercury removal, on a

  2. New mineral occurrences and mineralization processes: Wuda coal-fire gas vents of Inner Mongolia

    SciTech Connect (OSTI)

    Stracher, G.B.; Prakash, A.; Schroeder, P.; McCormack, J.; Zhang, X.M.; Van Dijk, P.; Blake, D.

    2005-12-01

    Five unique mineral assemblages that include the sulfates millosevichite, alunogen, anhydrite, tschermigite, coquimbite, voltaite, and godovikovite, as well as the halide salammoniac and an unidentified phase, according to X-ray diffraction and EDS data, were found as encrustations on quartzofeldspathic sand and sandstone adjacent to coal-fire gas vents associated with underground coal fires in the Wuda coalfield of Inner Mongolia. The mineral assemblage of alunogen, coquimbite, voltaite, and the unidentified phase collected front the same gas vent, is documented for the first time. Observations suggest that the sulfates millosevichite, alunogen, coquimbite, voltaite, godovikovite, and the unidentified phase, crystallized in response to a complex sequence of processes that include condensation, hydrothermal alteration, crystallization from solution, fluctuating vent temperatures, boiling, and dehydration reactions, whereas the halide salammoniac crystallized during the sublimation of coal-fire gas. Tschermigite and anhydrite formed by the reaction of coal-fire gas with quartzofelds pathic rock or by hydrothermal alteration of this rock and crystallization from an acid-rich aqueous solution. These minerals have potentially important environmental significance and may be vectors for the transmission of toxins. Coal fires also provide insight for the recognition in the geologic record of preserved mineral assemblages that are diagnostic of ancient fires.

  3. Update of operating experience of B and W IR-CFB coal-fired boilers

    SciTech Connect (OSTI)

    Belin, F.; Kavidass, S.; Maryamchik, M.; Walker, D.J.; Mandal, A.K.; Price, C.E.

    1999-07-01

    This paper updates the operating experience of two Babcock and Wilcox (B and W) coal-fired, internal recirculation circulating fluidized-bed (IR-CFB) boilers. The first boiler is located at Southern Illinois University (SIU) in Carbondale, Illinois, USA, and is designed for 35 MW{sub th} output for cogeneration application, utilizing high sulfur, low ash Illinois coal. The second boiler is located at Kanoria Chemicals and Industries in Renukoot, India, and is designed for 81 MW{sub th} output for captive power requirement, firing high ash, low sulfur coal. This boiler was supplied by Thermax B and W Ltd., a joint venture company of B and W and Thermax of India. The choice of CFB technology was based on its fuel flexibility, cost effectiveness and environmental benefits for solid fuels. Based on the broad experience in designing utility and industrial boilers for operation worldwide, B and W has developed a cost effective and compact atmospheric pressure IR-CFB boiler. The B and W IR-CFB boiler design is distinctive in its use of U-beam particle separators. Worldwide, B and W offers IF-CFB boilers up to 175 MW{sub th}, both reheat and non-reheat, and is pursuing units up to 350 MW{sub th}. This paper reviews the general description of each IR-CFB boiler, design and performance aspects, as well as overall operating experiences. The boiler availabilities including maintenance aspects and emissions data will be presented.

  4. Multiplexed Optical Fiber Sensors for Coal Fired Advanced Fossil Energy Systems

    SciTech Connect (OSTI)

    Wang, Anbo; Pickrell, Gary

    2012-03-31

    This report summarizes technical progress on the program Multiplexed Optical Fiber Sensors for Coal Fired Advanced Fossil Energy Systems funded by the National Energy Technology Laboratory of the U.S. Department of Energy, and performed jointly by the Center for Photonics Technology of the Bradley Department of Electrical and Computer Engineering and the Department of Materials Science and Engineering at Virginia Tech. This three-year project started on October 1, 2008. In the project, a fiber optical sensing system based on intrinsic Fabry-Perot Interferometer (IFPI) was developed for strain and temperature measurements for Ultra Supercritical boiler condition assessment. Investigations were focused on sensor design, fabrication, attachment techniques and novel materials for high temperature and strain measurements. At the start of the project, the technical requirements for the sensing technology were determined together with our industrial partner Alstom Power. As is demonstrated in Chapter 4, all the technical requirements are successfully met. The success of the technology extended beyond laboratory test; its capability was further validated through the field test at DOE NETL, in which the sensors yielded distributed temperature mapping of a testing coupon installed in the turbine test rig. The measurement results agreed well with prior results generated with thermocouples. In this project, significant improvements were made to the IFPI sensor technology by splicing condition optimization, transmission loss reduction, sensor signal demodulation and sensor system design.

  5. MHD Coal-Fired Flow Facility. Quarterly/annual technical progress report, October-December 1979

    SciTech Connect (OSTI)

    Dicks, J. B.; Chapman, J. N.; Crawford, L. W.

    1980-02-01

    In this Fourth Quarterly/Annual Report submitted under DOE contracts EX-76-C-01-1760 and DE-AC02-79ET10815, the University of Tennessee Space Institute (UTSI) reports on significant activity, task status, planned research, testing, and development, and conclusions for the Magnetohydrodynamics (MHD) Coal-Fired Flow Facility (CFFF) and the Research and Development Laboratory. Work on the CFFF progressed with only minor problems. Total construction activity for all site work presently awarded is nearly 98% complete. Water analysis shows that Woods Reservoir baseline conditions are within EPA or Tennessee drinking water standards. For the primary combustor, the vitiation heater and primary combustor fabrication drawings were completed and the nozzle design was completed. The drum module for the radiant slagging furnace was awarded. On the MHD Power Generator, development continued in several areas of advanced analysis including development of time-dependent models for use with the one-dimensional code. For seed regeneration, the tentative determination is that the Tomlinson Tampella is the most economically viable method. With regard to capped electrode erosion, investigations have shown that the major degradation of the cladding still present is at the leading edge of the capped anode. To alleviate this, plans are to hot work the noble metal in the bending operation. In resolving another problem, a system employing the modified line-reversal method has been assembled and successfully tested to measure absolute plasma temperatures.

  6. December 2015 Most Viewed Documents for Power Generation And...

    Office of Scientific and Technical Information (OSTI)

    Wireless Sensor Network for Electric Transmission Line Monitoring Alphenaar, Bruce ... Filtration Methods in Coal-Fired Power Plant Cho, Young; Fridman, Alexander (2012) ...

  7. September 2015 Most Viewed Documents for Power Generation And...

    Office of Scientific and Technical Information (OSTI)

    Transmission Line Monitoring Alphenaar, Bruce (2009) 39 Application of Pulse Spark Discharges for Scale Prevention and Continuous Filtration Methods in Coal-Fired Power Plant ...

  8. A Sensor System Based on Semi-Conductor Metal Oxide Technology for In Situ Detection of Coal Fired Combustion Gases

    SciTech Connect (OSTI)

    Brent Marquis

    2007-05-31

    Sensor Research and Development Corporation (SRD) proposed a two-phase program to develop a robust, autonomous prototype analyzer for in situ, real-time detection, identification, and measurement of coal-fired combustion gases and perform field-testing at an approved power generation facility. SRD developed and selected sensor materials showing selective responses to carbon monoxide, carbon dioxide, nitric oxide, nitrogen dioxide, ammonia, sulfur dioxide and hydrogen chloride. Sensor support electronics were also developed to enable prototype to function in elevated temperatures without any issues. Field-testing at DOE approved facility showed the ability of the prototype to detect and estimate the concentration of combustion by-products accurately with relatively low false-alarm rates at very fast sampling intervals.

  9. Nitrogen oxides emission control options for coal-fired electric utility boilers

    SciTech Connect (OSTI)

    Ravi K. Srivastava; Robert E. Hall; Sikander Khan; Kevin Culligan; Bruce W. Lani

    2005-09-01

    Recent regulations have required reductions in emissions of nitrogen oxides (NOx) from electric utility boilers. To comply with these regulatory requirements, it is increasingly important to implement state-of-the-art NOx control technologies on coal-fired utility boilers. This paper reviews NOx control options for these boilers. It discusses the established commercial primary and secondary control technologies and examines what is being done to use them more effectively. Furthermore, the paper discusses recent developments in NOx controls. The popular primary control technologies in use in the United States are low-NOx burners and overfire air. Data reflect that average NOx reductions for specific primary controls have ranged from 35% to 63% from 1995 emissions levels. The secondary NOx control technologies applied on U.S. coal-fired utility boilers include reburning, selective noncatalytic reduction (SNCR), and selective catalytic reduction (SCR). Thirty-six U.S. coal-fired utility boilers have installed SNCR, and reported NOx reductions achieved at these applications ranged from 15% to 66%. Recently, SCR has been installed at 150 U.S. coal-fired utility boilers. Data on the performance of 20 SCR systems operating in the United States with low-NOx emissions reflect that in 2003, these units achieved NOx emission rates between 0.04 and 0.07 lb/106 Btu. 106 refs., 6 figs., 6 tabs.

  10. Defeat the dragon: coal fires between self ignition and fire fighting

    SciTech Connect (OSTI)

    Manfred W. Wuttke; Stefan Wessling; Winfried Kessels

    2007-01-15

    Spontaneous coal fires in near surface coal seams are a worldwide recognized problem. They are destroying coal resources and emit climate relevant gases both in considerable amounts. While the extinction of such fires is a most desirable goal, the estimation of the actual input of greenhouse gases into the atmosphere is of great interest especially in the context of the Kyoto protocol as such values are needed as baseline for the Clean Development Mechanism (CDM) policies. Under the framework of the Sino-German coal-fire research project we are developing numerical models of such coal fires for the operational use in fire fighting campaigns. Based on our understanding of the governing physical and chemical processes that are relevant for the whole combustion process we simulate the coal fire spreading along the seams for typical situations. From these scenario calculations we deduce information needed to support the CDM baseline estimation and to assess the progress of fire extinguishing efforts like water injection and surface covering to dissipate the heat and suffocate the fire. We present case studies using the finite-element-code ROCKFLOW applied to realistic geometries based on field observations in the Shenhua Group Coal Mining Area Wuda (Inner Mongolia, PR China).

  11. Coal-fired MHD test progress at the component development and integration facility

    SciTech Connect (OSTI)

    Hart, A.T.; Lofftus, D.

    1994-12-31

    The Component and Development and Integration Facility (CDIF) is a Department of Energy test facility operated by MSE, Inc. MSE personnel were responsible for the integration of topping cycle components for the national coal-fired magnetohydrodynamics development program. Initial facility checkout and baseline data generation testing at the CDIF used a 50-megawatt (MW{sub t}), oil-fired combustor (with ash injection to simulate coal slag carryover) coupled to the 1A{sub 1} supersonic channel. In the fall of 1984, a 50-MW{sub t}, pressurized, slag rejecting coal-fired combustor replaced the oil-fired combustor in the test train. In the spring of 1989, a coal-fired precombustor was added to the workhorse test hardware. In the spring of 1992, workhorse hardware was replaced with the prototypic coal-fired test train. Testing during the last year emphasized prototypic hardware testing targeted at longer duration testing, some intermediate checkout testing, and more reliable operation. These phases of testing and the associated facility modifications are discussed. Progress of the proof-of-concept testing, through the time of testing shutdown, is addressed.

  12. Coal-fired MHD test progress at the Component Development and Integration Facility

    SciTech Connect (OSTI)

    Hart, A.T.; Filius, K.D.; Micheletti, D.A.; Cashell, P.V.

    1993-12-31

    The Component Development and Integration Facility (CDIF) is a Department of Energy test facility operated by MSE, Inc. MSE personnel are responsible for integrated testing of topping cycle components for the national coal-fired magnetohydrodynamics (MHD) development program. Initial facility checkout and baseline data generation testing at the CDIF used a 50-MW{sub t}, oil-fired combustor (with ash injection to simulate coal slag carryover) coupled to the 1A{sub 1} supersonic workhorse channel. In the fall of 1984, a 50-MW{sub t}, pressurized, slag rejecting coal-fired workhorse combustor replaced the oil-fired combustor in the test train. In the spring of 1989, a coal-fired precombustor was added to the test hardware, and current controls were installed in the spring of 1990. In the fall of 1990, the slag rejector was installed. In the spring of 1992, a 50-MW{sub t} pressurized, slag rejecting coal-fired prototypical combustor replaced the workhorse combustor in the test train. A 1A{sub 4} supersonic prototypical channel replaced the 1A{sub 1} workhorse channel in the fall of 1993. This prototypical hardware is slated to be used for the proof-of-concept (POC) testing. Improved facility systems targeting longer duration testing and more reliable operation will be discussed, including the air emissions control and monitoring hardware, oxygen and nitrogen expansion, coal and seed system upgrades, A-Bay modifications, and new solid suspension injection equipment.

  13. National Lab Helping to Train Operators for Next Generation of Power Plants

    Office of Energy Efficiency and Renewable Energy (EERE)

    Students in West Virginia are receiving hands-on experience for careers at cleaner-burning coal-fired power plants.

  14. EVALUATION OF MERCURY EMISSIONS FROM COAL-FIRED FACILITIES WITH SCR AND FGD SYSTEMS

    SciTech Connect (OSTI)

    J.A. Withum

    2006-03-07

    CONSOL Energy Inc., Research & Development (CONSOL), with support from the U.S. Department of Energy, National Energy Technology Laboratory (DOE) and the Electric Power Research Institute (EPRI), evaluated the effects of selective catalytic reduction (SCR) on mercury (Hg) capture in coal-fired plants equipped with an electrostatic precipitator (ESP)-wet flue gas desulfurization (FGD) combination or a spray dyer absorber-fabric filter (SDA-FF) combination. In this program CONSOL determined mercury speciation and removal at 10 bituminous coal-fired facilities; at four of these facilities, additional tests were performed on units without SCR, or with the existing SCR bypassed. This project final report summarizes the results and discusses the findings of the body of work as a whole. Eleven Topical Reports were issued (prior to this report) that describe in great detail the sampling results at each of the ten power plants individually. The results showed that the SCR-FGD combination removed a substantial fraction of mercury from flue gas. The coal-to-stack mercury removals ranged from 65% to 97% for the units with SCR and from 53% to 87% for the units without SCR. There was no indication that any type of FGD system was more effective at mercury removal than others. The coal-to-stack mercury removal and the removal in the wet scrubber were both negatively correlated with the elemental mercury content of the flue gas and positively correlated with the scrubber liquid chloride concentration. The coal chlorine content was not a statistically significant factor in either case. Mercury removal in the ESP was positively correlated with the fly ash carbon content and negatively correlated with the flue gas temperature. At most of the units, a substantial fraction (>35%) of the flue gas mercury was in the elemental form at the boiler economizer outlet. After passing through the SCR-air heater combination very little of the total mercury (<10%) remained in the elemental form in

  15. Engineering development of advanced coal-fired low-emission boiler systems. Technical progress report No. 11, April 1995--June 1995

    SciTech Connect (OSTI)

    1995-08-30

    The Pittsburgh Energy Technology Center of the U.S. Department of Energy (DOE) has contracted with Combustion Engineering, Inc. (ABB CE) to perform work on the {open_quotes}Engineering Development of Advanced Coal-Fired Low-Emission Boiler Systems{close_quotes} Project and has authorized ABB CE to complete Phase I on a cost-reimbursable basis and Phases II and III on a cost-share basis. The overall objective of the Project is the expedited commercialization of advanced coal-fired low-emission boiler systems. The specified primary objectives are: (1) NO{sub x} emissions not greater than one-third NSPS. (2) SO{sub x} emissions not greater than one-third NSPS. (3) Particulate emissions not greater than one-half NSPS. The specific secondary objectives are: (1) Improved ash disposability and reduced waste generation. (2) Reduced air toxics emissions. (3) Increased generating efficiency. The final deliverables are a design data base that will allow future coal-fired power plants to meet the stated objectives and a preliminary design of a Commercial Generation Unit. The work in Phase I covered a 24-month period and included system analysis, RD&T Plan formulation, component definition, and preliminary Commercial Generating Unit (CGU) design. Phase II will cover a 15-month period and will include preliminary Proof-of-Concept Test Facility (POCTF) design and subsystem testing. Phase III will cover a 9-month period and will produce a revised CGU design and a revised POCTF design, cost estimate and a test plan. Phase IV, the final Phase, will cover a 36-month period and will include POCTF detailed design, construction, testing, and evaluation.

  16. TOXECON RETROFIT FOR MERCURY AND MULTI-POLLUTANT CONTROL ON THREE 90-MW COAL-FIRED BOILERS

    SciTech Connect (OSTI)

    Steven T. Derenne

    2006-04-28

    With the Nation's coal-burning utilities facing tighter controls on mercury pollutants, the U.S. Department of Energy is supporting projects that could offer power plant operators better ways to reduce these emissions at much lower costs. Sorbent injection technology represents one of the simplest and most mature approaches to controlling mercury emissions from coal-fired boilers. It involves injecting a solid material such as powdered activated carbon into the flue gas. The gas-phase mercury in the flue gas contacts the sorbent and attaches to its surface. The sorbent with the mercury attached is then collected by a particulate control device along with the other solid material, primarily fly ash. We Energies has over 3,200 MW of coal-fired generating capacity and supports an integrated multi-emission control strategy for SO{sub 2}, NO{sub x}, and mercury emissions while maintaining a varied fuel mix for electric supply. The primary goal of this project is to reduce mercury emissions from three 90-MW units that burn Powder River Basin coal at the We Energies Presque Isle Power Plant. Additional goals are to reduce nitrogen oxide (NO{sub x}), sulfur dioxide (SO{sub 2}), and particulate matter (PM) emissions, allow for reuse and sale of fly ash, demonstrate a reliable mercury continuous emission monitor (CEM) suitable for use in the power plant environment, and demonstrate a process to recover mercury captured in the sorbent. To achieve these goals, We Energies (the Participant) will design, install, and operate a TOXECON{trademark} system designed to clean the combined flue gases of Units 7, 8, and 9 at the Presque Isle Power Plant. TOXECON{trademark} is a patented process in which a fabric filter system (baghouse) installed downstream of an existing particle control device is used in conjunction with sorbent injection for removal of pollutants from combustion flue gas. For this project, the flue gas emissions will be controlled from the three units using a single

  17. Performance of composite coatings in a coal-fired boiler environment

    SciTech Connect (OSTI)

    Nava, J.C.

    2009-09-15

    Four samples of thermal spray coatings, each made from different core wire consumables by twin wire arc spray, were exposed for 18 months in a coal-fired boiler environment. The tests are described and the performance of each coating is evaluated. Results indicated that the four consumable wire alloys showed remarkable resistance to fly ash erosion and corrosion over the period of the test.

  18. Conceptual design of a coal-fired MHD retrofit. Final technical report

    SciTech Connect (OSTI)

    1994-06-01

    Coal-fired magnetohydrodynamics (MHD) technology is ready for its next level of development - an integrated demonstration at a commercial scale. The development and testing of MHD has shown its potential to be the most efficient, least costly, and cleanest way to burn coal. Test results have verified a greater than 99% removal of sulphur with a potential for greater than 60% efficiency. This development and testing, primarily funded by the U.S. Department of Energy (DOE), has progressed through the completion of its proof-of-concept (POC) phase at the 50 MWt Component Development and Integration Facility (CDIF) and 28 MWt Coal Fired Flow Facility (CFFF), thereby, providing the basis for demonstration and further commercial development and application of the technology. The conceptual design of a retrofit coal-fired MHD generating plant was originally completed by the MHD Development Corporation (MDC) under this Contract, DE-AC22-87PC79669. Thereafter, this concept was updated and changed to a stand-alone MHD demonstration facility and submitted by MDC to DOE in response to the fifth round of solicitations for Clean Coal Technology. Although not selected, that activity represents the major interest in commercialization by the developing industry and the type of demonstration that would be eventually necessary. This report updates the original executive summary of the conceptual design by incorporating the results of the POC program as well as MDC`s proposed Billings MHD Demonstration Project (BMDP) and outlines the steps necessary for commercialization.

  19. Natural gas beats coal in power generation

    Annual Energy Outlook

    Natural gas beats coal in power generation The amount of U.S. electricity generated by natural gas is expected to exceed the output from coal-fired power plants this year and in ...

  20. ADVANCED FLUE GAS CONDITIONING AS A RETROFIT UPGRADE TO ENHANCE PM COLLECTION FROM COAL-FIRED ELECTRIC UTILITY BOILERS

    SciTech Connect (OSTI)

    Kenneth E. Baldrey

    2002-05-01

    The U.S. Department of Energy and ADA Environmental Solutions are engaged in a project to develop commercial flue gas conditioning additives. The objective is to develop conditioning agents that can help improve particulate control performance of smaller or under-sized electrostatic precipitators on utility coal-fired boilers. The new chemicals will be used to control both the electrical resistivity and the adhesion or cohesivity of the fly ash. There is a need to provide cost-effective and safer alternatives to traditional flue gas conditioning with SO{sub 3} and ammonia. During this reporting quarter, performance testing of flue gas conditioning was underway at the PacifiCorp Jim Bridger Power Plant. The product tested, ADA-43, was a combination resistivity modifier with cohesivity polymers. This represents the first long-term full-scale testing of this class of products. Modifications to the flue gas conditioning system at Jim Bridger, including development of alternate injection lances, was also undertaken to improve chemical spray distribution and to avoid spray deposition to duct interior surfaces. Also in this quarter, a firm commitment was received for another long-term test of the cohesivity additives. This plant fires a bituminous coal and has opacity and particulate emissions performance issues related to fly ash re-entrainment. Ammonia conditioning is employed here on one unit, but there is interest in liquid cohesivity additives as a safer alternative.

  1. Full operating range robust hybrid control of a coal-fired boiler/turbine unit - article no. 041011

    SciTech Connect (OSTI)

    Zheng, K.; Bentsman, J.; Taft, C.W.

    2008-07-15

    Multi-input-multi-output robust controllers recently designed for the megawatt output/throttle pressure control in a coal-fired power plant boiler/turbine unit have demonstrated performance robustness noticeably superior to that of the currently employed nonlinear PID-based controller. These controllers, however, have been designed only for the range of 150-185 MW around the 185 MW nominal operating point, exhibiting a significant loss of performance in the lower range of 120-150 MW. Through system identification, the reason for this performance loss is demonstrated in the current work to be a pronounced dependence of the boiler/turbine unit steady state gains on the operating point. This problem is addressed via a hybrid control law consisting of two robust controllers and a robust switch between them activated by the set point change. The controllers are designed to cover the corresponding half-ranges of the full operating range. This permits attainment of the desired overall performance as well as reduction of modeling uncertainty induced by the operating point change to approximately 25% of that associated with the previous designs. Robust switching is accomplished through a novel hybrid mode of behavior-robustly controlled discrete transition.

  2. NOx Control Options and Integration for US Coal Fired Boilers

    SciTech Connect (OSTI)

    Mike Bockelie; Kevin Davis; Connie Senior; Darren Shino; Dave Swenson; Larry Baxter; Calvin Bartholomew; William Hecker; Stan Harding

    2005-03-31

    This is the nineteenth Quarterly Technical Report for DOE Cooperative Agreement No: DEFC26-00NT40753. The goal of the project is to develop cost effective analysis tools and techniques for demonstrating and evaluating low NO{sub x} control strategies and their possible impact on boiler performance for boilers firing US coals. The Electric Power Research Institute (EPRI) is providing co-funding for this program. Refurbished corrosion probes were installed at Plant Gavin and operated for approximately 1,300 hours. This quarterly report includes further results from the BYU catalyst characterization lab and the in-situ lab, and includes the first results from a model suitable for comprehensive simulation codes for describing catalyst performance. The SCR slipstream reactor at Plant Gadsden operated for approximately 100 hours during the quarter because of ash blockage in the inlet probe.

  3. NOx CONTROL OPTIONS AND INTEGRATION FOR US COAL FIRED BOILERS

    SciTech Connect (OSTI)

    Mike Bockelie; Marc Cremer; Kevin Davis; Connie Senior; Bob Hurt; Eric Suuberg; Eric Eddings; Larry Baxter

    2002-01-31

    This is the sixth Quarterly Technical Report for DOE Cooperative Agreement No: DE-FC26-00NT40753. The goal of the project is to develop cost effective analysis tools and techniques for demonstrating and evaluating low NOx control strategies and their possible impact on boiler performance for firing US coals. The Electric Power Research Institute (EPRI) is providing co-funding for this program. This program contains multiple tasks and good progress is being made on all fronts. Preliminary results from laboratory and field tests of a corrosion probe to predict waterwall wastage indicate good agreement between the electrochemical noise corrosion rates predicted by the probe and corrosion rates measured by a surface profilometer. Four commercial manufacturers agreed to provide catalyst samples to the program. BYU has prepared two V/Ti oxide catalysts (custom, powder form) containing commercially relevant concentrations of V oxide and one containing a W oxide promoter. Two pieces of experimental apparatus being built at BYU to carry out laboratory-scale investigations of SCR catalyst deactivation are nearly completed. A decision was made to carry out the testing at full-scale power plants using a slipstream of gas instead of at the University of Utah pilot-scale coal combustor as originally planned. Design of the multi-catalyst slipstream reactor was completed during this quarter. One utility has expressed interest in hosting a long-term test at one of their plants that co-fire wood with coal. Tests to study ammonia adsorption onto fly ash have clearly established that the only routes that can play a role in binding significant amounts of ammonia to the ash surface, under practical ammonia slip conditions, are those that must involve co-adsorbates.

  4. Characterization of Oxy-combustion Impacts in Existing Coal-fired Boilers

    SciTech Connect (OSTI)

    Adams, Bradley R.; Fry, Andrew R.; Senior, Constance L.; Shim, Hong Shig; Otten, Brydger Van; Wendt, Jost; Shaddix, Christopher; Tree, Dale

    2010-06-01

    This report summarizes Year 2 results of a research program designed to use multi-scale experimental studies and fundamental theoretical models to characterize and predict the impacts of retrofit of existing coal-fired utility boilers for oxy-combustion. Year 2 focused extensively on obtaining experimental data from the bench-scale, lab-scale and pilot-scale reactors. These data will be used to refine and validate submodels to be implemented in CFD simulations of full-scale boiler retrofits. Program tasks are on schedule for Year 3 completion. Both Year 2 milestones were completed on schedule and within budget.

  5. Fuel supply system and method for coal-fired prime mover

    DOE Patents [OSTI]

    Smith, William C.; Paulson, Leland E.

    1995-01-01

    A coal-fired gas turbine engine is provided with an on-site coal preparation and engine feeding arrangement. With this arrangement, relatively large dry particles of coal from an on-site coal supply are micro-pulverized and the resulting dry, micron-sized, coal particulates are conveyed by steam or air into the combustion chamber of the engine. Thermal energy introduced into the coal particulates during the micro-pulverizing step is substantially recovered since the so-heated coal particulates are fed directly from the micro-pulverizer into the combustion chamber.

  6. NOx CONTROL OPTIONS AND INTEGRATION FOR US COAL FIRED BOILERS

    SciTech Connect (OSTI)

    Mike Bockelie; Marc Cremer; Kevin Davis; Connie Senior; Bob Hurt; Eric Eddings; Larry Baxter

    2002-04-30

    This is the seventh Quarterly Technical Report for DOE Cooperative Agreement No: DE-FC26-00NT40753. The goal of the project is to develop cost effective analysis tools and techniques for demonstrating and evaluating low NOx control strategies and their possible impact on boiler performance for firing US coals. The Electric Power Research Institute (EPRI) is providing co-funding for this program. This program contains multiple tasks and good progress is being made on all fronts. A series of field tests for RRI at the Ameren Sioux Unit No.1 have demonstrated that RRI can provide up to 30% NOx reduction over the use of over fire air in large scale (480MW) cyclone fired utility boilers. The field tests and modeling results are in good agreement. Final data analysis has been completed for tests performed at Eastlake Power Station of a real-time waterwall corrosion monitoring system. The tests demonstrated that corrosion could be measured accurately in real-time in normal boiler operations, and an assessment of waterwall wastage could be made without impacting boiler availability. Detailed measurements of soot volume fraction have been performed for a coal burner in a pilot scale test furnace. The measured values are in good agreement with the expected trends for soot generation and destruction. Catalysts from four commercial manufacturers have been ordered and one of the samples was received this quarter. Several in situ analyses of vanadium-based SCR catalyst systems were completed at BYU. Results to date indicate that the system produces results that represent improvements compared to literature examples of similar experiments. Construction of the catalyst characterization system (CCS) reactor is nearly complete, with a few remaining details discussed in this report. A literature review originally commissioned from other parties is being updated and will be made available under separate cover as part of this investigation. Fabrication of the multi-catalyst slipstream

  7. NOx Control Options and Integration for US Coal Fired Boilers

    SciTech Connect (OSTI)

    Mike Bockelie; Kevin Davis; Connie Senior; Darren Shino; Dave Swenson; Larry Baxter; Calvin Bartholomew; William Hecker; Stan Harding

    2004-12-31

    This is the eighteenth Quarterly Technical Report for DOE Cooperative Agreement No: DEFC26-00NT40753. The goal of the project is to develop cost effective analysis tools and techniques for demonstrating and evaluating low NOx control strategies and their possible impact on boiler performance for boilers firing US coals. The Electric Power Research Institute (EPRI) is providing co-funding for this program. Safety equipment for ammonia for the SCR slipstream reactor at Plant Gadsden was installed. The slipstream reactor was started and operated for about 1400 hours during the last performance period. Laboratory analysis of exposed catalyst and investigations of the sulfation of fresh catalyst continued at BYU. Thicker end-caps for the ECN probes were designed and fabricated to prevent the warpage and failure that occurred at Gavin with the previous design. A refurbished ECN probe was successfully tested at the University of Utah combustion laboratory. Improvements were implemented to the software that controls the flow of cooling air to the ECN probes.

  8. NOx Control Options and Integration for US Coal Fired Boilers

    SciTech Connect (OSTI)

    Mike Bockelie; Kevin Davis; Connie Senior Darren Shino; Dave Swenson; Larry Baxter; Calvin Bartholomew; William Hecker; Stan Harding

    2004-09-30

    This is the seventeenth Quarterly Technical Report for DOE Cooperative Agreement No: DEFC26-00NT40753. The goal of the project is to develop cost effective analysis tools and techniques for demonstrating and evaluating low NOx control strategies and their possible impact on boiler performance for boilers firing US coals. The Electric Power Research Institute (EPRI) is providing co-funding for this program. The SCR slipstream reactor was assembled and installed at Plant Gadsden this quarter. Safety equipment for ammonia had not been installed at the end of the quarter, but will be installed at the beginning of next quarter. The reactor will be started up next quarter. Four ECN corrosion probes were reinstalled at Gavin and collected corrosion data for approximately one month. Two additional probes were installed and removed after about 30 hours for future profilometry analysis. Preliminary analysis of the ECN probes, the KEMA coupons and the CFD modeling results all agree with the ultrasonic tube test measurements gathered by AEP personnel.

  9. NOx CONTROL OPTIONS AND INTEGRATION FOR US COAL FIRED BOILERS

    SciTech Connect (OSTI)

    Mike Bockelie; Marc Cremer; Kevin Davis; Bob Hurt; Eric Eddings

    2001-07-27

    This is the third Quarterly Technical Report for DOE Cooperative Agreement No: DE-FC26-00NT40753. The goal of the project is to develop cost effective analysis tools and techniques for demonstrating and evaluating low NOx control strategies and their possible impact on boiler performance for firing US coals. The Electric Power Research Institute (EPRI) is providing cofunding for this program. This program contains multiple tasks and good progress is being made on all fronts. A Rich Reagent Injection (RRI) design has been developed for a cyclone fired utility boiler in which a field test of RRI will be performed later this year. Initial evaluations of RRI for PC fired boilers have been performed. Calibration tests have been developed for a corrosion probe to monitor waterwall wastage. Preliminary tests have been performed for a soot model within a boiler simulation program. Shakedown tests have been completed for test equipment and procedures that will be used to measure soot generation in a pilot scale test furnace. In addition, an initial set of controlled experiments for ammonia adsorption onto fly ash in the presence of sulfur have been performed that indicates the sulfur does enhance ammonia uptake.

  10. NOx Control Options and Integration for US Coal Fired Boilers

    SciTech Connect (OSTI)

    Mike Bockelie; Kevin Davis; Temi Linjewile; Connie Senior; Eric Eddings; Kevin Whitty; Larry Baxter; Calvin Bartholomew; William Hecker; Stan Harding

    2003-06-30

    This is the twelfth Quarterly Technical Report for DOE Cooperative Agreement No: DE-FC26-00NT40753. The goal of the project is to develop cost effective analysis tools and techniques for demonstrating and evaluating low NOx control strategies and their possible impact on boiler performance for boilers firing US coals. The Electric Power Research Institute (EPRI) is providing co-funding for this program. This program contains multiple tasks and good progress is being made on all fronts. During this quarter, a new effort was begun on the development of a corrosion management system for minimizing the impacts of low NOx combustion systems on waterwalls; a kickoff meeting was held at the host site, AEP's Gavin Plant, and work commenced on fabrication of the probes. FTIR experiments for SCR catalyst sulfation were finished at BYU and indicated no vanadium/vanadyl sulfate formation at reactor conditions. Improvements on the mass-spectrometer system at BYU have been made and work on the steady state reactor system shakedown neared completion. The slipstream reactor continued to operate at AEP's Rockport plant; at the end of the quarter, the catalysts had been exposed to flue gas for about 1000 hours. Some operational problems were addressed that enable the reactor to run without excessive downtime by the end of the quarter.

  11. The Power and Potential of Geothermal Energy | Department of...

    Office of Environmental Management (EM)

    which is equivalent to 16 large nuclear power plants or dozens of coal fired power plants. ... a 79 million loan guarantee for the Blue Mountain power plant in northeastern Nevada. ...

  12. NOx Control Options and Integration for US Coal Fired Boilers

    SciTech Connect (OSTI)

    Mike Bockelie; Kevin Davis; Temi Linjewile; Connie Senior; Eric Eddings; Kevin Whitty; Larry Baxter; Calvin Bartholomew; William Hecker; Stan Harding; Robert Hurt

    2003-12-31

    This is the fourteenth Quarterly Technical Report for DOE Cooperative Agreement No: DEFC26-00NT40753. The goal of the project is to develop cost effective analysis tools and techniques for demonstrating and evaluating low NOx control strategies and their possible impact on boiler performance for boilers firing US coals. The Electric Power Research Institute (EPRI) is providing co-funding for this program. Using the initial CFD baseline modeling of the Gavin Station and the plant corrosion maps, six boiler locations for the corrosion probes were identified and access ports have been installed. Preliminary corrosion data obtained appear consistent and believable. In situ, spectroscopic experiments at BYU reported in part last quarter were completed. New reactor tubes have been made for BYU's CCR that allow for testing smaller amounts of catalyst and thus increasing space velocity; monolith catalysts have been cut and a small reactor that can accommodate these pieces for testing is in its final stages of construction. A poisoning study on Ca-poisoned catalysts was begun this quarter. A possible site for a biomass co-firing test of the slipstream reactor was visited this quarter. The slipstream reactor at Rockport required repair and refurbishment, and will be re-started in the next quarter. This report describes the final results of an experimental project at Brown University on the fundamentals of ammonia / fly ash interactions with relevance to the operation of advanced NOx control technologies such as selective catalytic reduction. The Brown task focused on the measurement of ammonia adsorption isotherms on commercial fly ash samples subjected to a variety of treatments and on the chemistry of dry and semi-dry ammonia removal processes.

  13. NOx CONTROL OPTIONS AND INTEGRATION FOR US COAL FIRED BOILERS

    SciTech Connect (OSTI)

    Mike Bockelie; Marc Cremer; Kevin Davis; Temi Linjewile; Connie Senior; Hong-Shig Shim; Bob Hurt; Eric Eddings; Larry Baxter

    2003-01-30

    This is the tenth Quarterly Technical Report for DOE Cooperative Agreement No: DE-FC26-00NT40753. The goal of the project is to develop cost effective analysis tools and techniques for demonstrating and evaluating low NO{sub x} control strategies and their possible impact on boiler performance for firing US coals. The Electric Power Research Institute (EPRI) is providing cofunding for this program. This program contains multiple tasks and good progress is being made on all fronts. During this quarter, progress was made on the computational simulation of a full-scale boiler with the purpose of understanding the potential impacts of burner operating conditions on soot and NO{sub x} generation. Sulfation tests on both the titania support and vanadia/titania catalysts were completed using BYU's in situ spectroscopy reactor this quarter. These experiments focus on the extent to which vanadia and titania sulfate in an SO{sub 2}-laden, moist environment. Construction of the CCS reactor system is essentially complete and the control hardware and software are largely in place. A large batch of vanadia/titania catalyst in powder form has been prepared for use in poisoning tests. During this quarter, minor modifications were made to the multi-catalyst slipstream reactor and to the control system. The slipstream reactor was installed at AEP's Rockport plant at the end of November 2002. In this report, we describe the reactor system, particularly the control system, which was created by REI specifically for the reactor, as well as the installation at Rockport.

  14. NOx Control Options and Integration for US Coal Fired Boilers

    SciTech Connect (OSTI)

    Mike Bockelie; Kevin Davis; Temi Linjewile; Connie Senior; Eric Eddings; Kevin Whitty; Larry Baxter; Calvin Bartholomew; William Hecker; Stan Harding

    2004-03-31

    This is the fifteenth Quarterly Technical Report for DOE Cooperative Agreement No: DE-FC26-00NT40753. The goal of the project is to develop cost effective analysis tools and techniques for demonstrating and evaluating low NOx control strategies and their possible impact on boiler performance for boilers firing US coals. The Electric Power Research Institute (EPRI) is providing co-funding for this program. At AEP's Gavin Plant, data from the corrosion probes showed that corrosion rate increased as boiler load was increased. During an outage at the plant, the drop in boiler load, sensor temperature and corrosion rate could all be seen clearly. Restarting the boiler saw a resumption of corrosion activity. This behavior is consistent with previous observations made at a 600MWe utility boiler. More data are currently being examined for magnitudes of corrosion rates and changes in boiler operating conditions. Considerable progress was made this quarter in BYU's laboratory study of catalyst deactivation. Surface sulfation appears to partially suppress NO adsorption when the catalyst is not exposed to NH3; NH3 displaces surface-adsorbed NO on SCR catalysts and surface sulfation increases the amount of adsorbed NH3, as confirmed by both spectroscopy and TPD experiments. However, there is no indication of changes in catalyst activity despite changes in the amount of adsorbed NH3. A monolith test reactor (MTR), completed this quarter, provided the first comparative data for one of the fresh and field-exposed monolith SCR catalysts yet developed in this project. Measurements of activity on one of the field-exposed commercial monolith catalysts do not show significant changes in catalyst activity (within experimental error) as compared to the fresh catalyst. The exposed surface of the sample contains large amounts of Ca and Na, neither of which is present in the fresh sample, even after removal of visibly obvious fouling deposits. However, these fouling compounds do not

  15. NOx Control Options and Integration for US Coal Fired Boilers

    SciTech Connect (OSTI)

    Mike Bockelie; Marc Cremer; Kevin Davis; Martin Denison; Adel Sarofim; Connie Senior; Hong-Shig Shim; Dave Swenson; Bob Hurt; Eric Suuberg; Eric Eddings; Kevin Whitty; Larry Baxter; Calvin Bartholomew; William Hecker

    2006-06-30

    This is the Final Report for DOE Cooperative Agreement No: DE-FC26-00NT40753. The goal of the project was to develop cost-effective analysis tools and techniques for demonstrating and evaluating low-NOx control strategies and their possible impact on boiler performance for boilers firing US coals. The Electric Power Research Institute (EPRI) provided co-funding for this program. This project included research on: (1) In furnace NOx control; (2) Impacts of combustion modifications on boiler operation; (3) Selective Catalytic Reduction (SCR) catalyst testing and (4) Ammonia adsorption/removal on fly ash. Important accomplishments were achieved in all aspects of the project. Rich Reagent Injection (RRI), an in-furnace NOx reduction strategy based on injecting urea or anhydrous ammonia into fuel rich regions in the lower furnace, was evaluated for cyclone-barrel and PC fired utility boilers. Field tests successfully demonstrated the ability of the RRI process to significantly reduce NOx emissions from a staged cyclone-fired furnace operating with overfire air. The field tests also verified the accuracy of the Computational Fluid Dynamic (CFD) modeling used to develop the RRI design and highlighted the importance of using CFD modeling to properly locate and configure the reagent injectors within the furnace. Low NOx firing conditions can adversely impact boiler operation due to increased waterwall wastage (corrosion) and increased soot production. A corrosion monitoring system that uses electrochemical noise (ECN) corrosion probes to monitor, on a real-time basis, high temperature corrosion events within the boiler was evaluated. Field tests were successfully conducted at two plants. The Ohio Coal Development Office provided financial assistance to perform the field tests. To investigate soot behavior, an advanced model to predict soot production and destruction was implemented into an existing reacting CFD modeling tool. Comparisons between experimental data collected

  16. Economic analysis of coal-fired cogeneration plants for Air Force bases

    SciTech Connect (OSTI)

    Holcomb, R.S.; Griffin, F.P.

    1990-10-01

    The Defense Appropriations Act of 1986 requires the Department of Defense to use an additional 1,600,000 tons/year of coal at their US facilities by 1995 and also states that the most economical fuel should be used at each facility. In a previous study of Air Force heating plants burning gas or oil, Oak Ridge National Laboratory found that only a small fraction of this target 1,600,000 tons/year could be achieved by converting the plants where coal is economically viable. To identify projects that would use greater amounts of coal, the economic benefits of installing coal-fired cogeneration plants at 7 candidate Air Force bases were examined in this study. A life-cycle cost analysis was performed that included two types of financing (Air Force and private) and three levels of energy escalation for a total of six economic scenarios. Hill, McGuire, and Plattsburgh Air Force Bases were identified as the facilities with the best potential for coal-fired cogeneration, but the actual cost savings will depend strongly on how the projects are financed and to a lesser extent on future energy escalation rates. 10 refs., 11 figs., 27 tabs.

  17. Liquid ash corrosion, remaining life estimation and superheater/reheater replacement strategy in coal fired boilers

    SciTech Connect (OSTI)

    Alice, J.A.; Janiszewski, J.A.

    1985-01-01

    The liquid ash corrosion of superheater and reheater tubing in coal fired boilers is commonly accepted to be caused by the action of liquid sodium and potassium iron trisulfates Na/sub 3/Fe(SO/sub 4/) and K/sub 3/Fe(SO/sub 4/)/sub 3/. These species melt at temperatures between 1030/sup 0/F and 1160/sup 0/F (555-625/sup 0/C) depending on the relative amounts of sodium and potassium. Rapid tube wastage begins when the tube metal temperature reaches the trisulfate melting point. The key to improved availability in fossil boilers is to identify and replace, during a planned outage, tubes which are likely to fail before the next planned outage. The authors have developed a computerized method for estimating the remaining life of superheater/reheater tubes based on accelerated liquid ash corrosion. The scheme of analysis employs the following logic: (1) measurement of tube wastage from several removed samples, (2) estimation of tube metal temperature from I.D. scale thickness and thermocouple data, (3) estimation of trisulfate melting point from chemical analysis of the ash deposit and (4) using the computer model to calculate remaining life as a function of tube wastage rate metal temperature. The practical application of this strategy is presented for a coal fired boiler in the GPU system.

  18. High-temperature fireside corrosion monitoring in the superheater section of a pulverized-coal-fired boiler. Final report

    SciTech Connect (OSTI)

    Mok, W.Y.; Cox, W.M.

    1992-12-01

    The work described in this report was the first British in-plant application of continuous online electrochemical corrosion monitoring technology in pulverized coal-fired superheater environments. The work was conducted at Drax Power Station, National Power plc, UK. The investigation was to evaluate the relative corrosion performance of stainless steel Alloys 316 and 310. Two electrochemical sensor assemblies fabricated from the test alloys were attached to the end of a coupon exposure probe which was inserted into the superheater section of a 660MW boiler. The probe assemblies were exposed at a nominal temperature of 665{degrees}C (1229{degrees}F) during the trial. two series of short term temperature scanning tests were carried out. Alloy 310 performed comparatively better than Alloy 316. Minimal corrosion loss was sustained by Alloy 310 whilst a characteristic wastage flat was observed on Alloy 316. It was shown that variations in boiler operation could affect the minute-to-minute corrosion behavior of the test materials. The results of the brief temperature scan program indicated a trend of increasing corrosion with exposure temperature. No evidence was observed of the ``bell-shaped`` curve behavior reported in laboratory studies of molten salt corrosion. Metallographic examination of the sensors indicated that only small and discrete areas of internal sulfur enrichment beneath the surface scale. This is untypical of the morphology of sulfur enriched scale found in molten salt corrosion systems. The corrosion processes were predominately in the form of oxidation/sulfidation. The formation of a wastage flat was postulated to have been caused by an electrochemical mechanism similar to that of flow assisted corrosion in aqueous electrolytes. These results confirmed that continuous on-line electrochemical instrumentation could be used to investigate, monitor and characterize high temperature oxidation in power generation boiler superheaters.

  19. High-temperature fireside corrosion monitoring in the superheater section of a pulverized-coal-fired boiler

    SciTech Connect (OSTI)

    Mok, W.Y.; Cox, W.M. )

    1992-12-01

    The work described in this report was the first British in-plant application of continuous online electrochemical corrosion monitoring technology in pulverized coal-fired superheater environments. The work was conducted at Drax Power Station, National Power plc, UK. The investigation was to evaluate the relative corrosion performance of stainless steel Alloys 316 and 310. Two electrochemical sensor assemblies fabricated from the test alloys were attached to the end of a coupon exposure probe which was inserted into the superheater section of a 660MW boiler. The probe assemblies were exposed at a nominal temperature of 665[degrees]C (1229[degrees]F) during the trial. two series of short term temperature scanning tests were carried out. Alloy 310 performed comparatively better than Alloy 316. Minimal corrosion loss was sustained by Alloy 310 whilst a characteristic wastage flat was observed on Alloy 316. It was shown that variations in boiler operation could affect the minute-to-minute corrosion behavior of the test materials. The results of the brief temperature scan program indicated a trend of increasing corrosion with exposure temperature. No evidence was observed of the bell-shaped'' curve behavior reported in laboratory studies of molten salt corrosion. Metallographic examination of the sensors indicated that only small and discrete areas of internal sulfur enrichment beneath the surface scale. This is untypical of the morphology of sulfur enriched scale found in molten salt corrosion systems. The corrosion processes were predominately in the form of oxidation/sulfidation. The formation of a wastage flat was postulated to have been caused by an electrochemical mechanism similar to that of flow assisted corrosion in aqueous electrolytes. These results confirmed that continuous on-line electrochemical instrumentation could be used to investigate, monitor and characterize high temperature oxidation in power generation boiler superheaters.

  20. Transformations and affinities for sulfur of Chinese Shenmu coal ash in a pulverized coal-fired boiler

    SciTech Connect (OSTI)

    Cheng, J.; Zhou, J.H.; Liu, J.Z.; Cao, X.Y.; Cen, K.F.

    2009-07-01

    The self-desulfurization efficiency of Shenmu coal with a high initial Ca/S molar ratio of 2.02 was measured in a 1,025 t/h pulverized coal-fired boiler. It increases from 29% to 32% when the power capacity decreases from 100% to 70%. About 60% of the mineral matter and calcium element fed into the furnace is retained in the fly ash, while less than 10% is retained in the bottom ash. About 70% of the sulfur element fed into the furnace is emitted as SO{sub 2} in the flue gas, while less than 10% is retained in the fly ash and less than 1% is retained in the bottom ash. The mineralogical compositions of feed coal, fly ash, and bottom ash were obtained by X-ray diffraction analysis. It is found that the initial amorphous phase content is 91.17% and the initial CaCO{sub 3} phase content is 2.07% in Shenmu coal. The vitreous phase and sulfation product CaSO{sub 4} contents are, respectively, 70.47% and 3.36% in the fly ash obtained at full capacity, while the retained CaCO{sub 3} and CaO contents are, respectively, 4.73% and 2.15%. However, the vitreous phase content is only 25.68% and no CaSO{sub 4} is detected in the bottom ash obtained at full capacity. When the power capacity decreases from 100% to 70%, the vitreous phase content in fly ash decreases from 70.47% to 67.41% and that in bottom ash increases from 25.68% to 28.10%.

  1. Engineering development of advanced coal-fired low-emissions boiler systems. Quarterly report, April 1--June 30, 1997

    SciTech Connect (OSTI)

    1997-12-31

    This progress report is on the project by Babcock and Wilcox Company to develop an advanced coal-fired low-emissions boiler system. The topics of the report include project management, the NO{sub x} subsystem, the SO{sub 2}/particulate/air toxics/solid by-product subsystem, boiler subsystem, balance of plant subsystem, and controls and sensors subsystems.

  2. Estimation of radiative properties and temperature distributions in coal-fired boiler furnaces by a portable image processing system

    SciTech Connect (OSTI)

    Li, Wenhao; Lou, Chun; Sun, Yipeng; Zhou, Huaichun

    2011-02-15

    This paper presented an experimental investigation on the estimation of radiative properties and temperature distributions in a 670 t/h coal-fired boiler furnace by a portable imaging processing system. The portable system has been calibrated by a blackbody furnace. Flame temperatures and emissivities were measured by the portable system and equivalent blackbody temperatures were deduced. Comparing the equivalent blackbody temperatures measured by the portable system and the infrared pyrometer, the relative difference is less than 4%. The reconstructed pseudo-instantaneous 2-D temperature distributions in two cross-sections can disclose the combustion status inside the furnace. The measured radiative properties of particles in the furnace proved there is significant scattering in coal-fired boiler furnaces and it can provide useful information for the calculation of radiative heat transfer and numerical simulation of combustion in coal-fired boiler furnaces. The preliminary experimental results show this technology will be helpful for the combustion diagnosis in coal-fired boiler furnaces. (author)

  3. Power plant emissions verified remotely at Four Corners sites

    U.S. Department of Energy (DOE) all webpages (Extended Search)

    Power plant emissions verified remotely Power plant emissions verified remotely at Four Corners sites The study is the first to show that space-based techniques can successfully verify international regulations on fossil energy emissions. May 19, 2014 The Four Corners coal-fired power plant, near Farmington, N.M. is a major source of pollutants, with measurements confirmed by Los Alamos National Laboratory researchers. The Four Corners coal-fired power plant, near Farmington, N.M. is a major

  4. EVALUATION OF CARBON DIOXIDE CAPTURE FROM EXISTING COAL FIRED PLANTS BY HYBRID SORPTION USING SOLID SORBENTS

    SciTech Connect (OSTI)

    Benson, Steven; Palo, Daniel; Srinivasachar, Srivats; Laudal, Daniel

    2014-12-01

    Under contract DE-FE0007603, the University of North Dakota conducted the project Evaluation of Carbon Dioxide Capture from Existing Coal Fired Plants by Hybrid Sorption Using Solid Sorbents. As an important element of this effort, an Environmental Health and Safety (EH&S) Assessment was conducted by Barr Engineering Co. (Barr) in association with the University of North Dakota. The assessment addressed air and particulate emissions as well as solid and liquid waste streams. The magnitude of the emissions and waste streams was estimated for evaluation purposes. EH&S characteristics of materials used in the system are also described. This document contains data based on the mass balances from both the 40 kJ/mol CO2 and 80 kJ/mol CO2 desorption energy cases evaluated in the Final Technical and Economic Feasibility study also conducted by Barr Engineering.

  5. Novel Nanocrystalline Intermetallic Coatings for Metal Alloys in Coal-fired Environments

    SciTech Connect (OSTI)

    Z. Zak Fang; H. Y. Sohn

    2009-08-31

    Intermetallic coatings (iron aluminide and nickel aluminide) were prepared by a novel reaction process. In the process, the aluminide coating is formed by an in-situ reaction between the aluminum powder fed through a plasma transferred arc (PTA) torch and the metal substrate (steel or Ni-base alloy). Subjected to the high temperature within an argon plasma zone, aluminum powder and the surface of the substrate melt and react to form the aluminide coatings. The prepared coatings were found to be aluminide phases that are porosity-free and metallurgically bonded to the substrate. The coatings also exhibit excellent high-temperature corrosion resistance under the conditions which simulate the steam-side and fire-side environments in coal-fired boilers. It is expected that the principle demonstrated in this process can be applied to the preparation of other intermetallic and alloy coatings.

  6. Application of hybrid coal reburning/SNCR processes for NOx reduction in a coal-fired boiler

    SciTech Connect (OSTI)

    Yang, W.J.; Zhou, Z.J.; Zhou, J.H.; Hongkun, L.V.; Liu, J.Z.; Cen, K.F.

    2009-07-01

    Boilers in Beijing Thermal Power Plant of Zhongdian Guohua Co. in China are coal-fired with natural circulation and tangential fired method, and the economical continuous rate is 410 ton per hour of steam. Hybrid coal reburning/SNCR technology was applied and it successfully reduced NOx to about 170 mg/Nm{sup 3} from about 540 mg/Nm{sup 3}, meanwhile ammonia slip was lower than 10 ppm at 450-210 t/h load and the total reduction efficiency was about 70%. Normal fineness pulverized coal from the bin was chosen as the reburning fuel and the nozzles of the upper primary air were retrofitted to be used as the reburning fuel nozzles. The reducing agent of SNCR was an urea solution, and it was injected by the four layer injectors after online dilution. At 410 t/h load, NOx emission was about 300 mg/Nm{sup 3} when the ratio of reburning fuel to the total fuel was 25.9%-33.4%. Controlling the oxygen content of the gas in the reversal chamber to less than 3.4% resulted in not only low NOx emission but also high combustion efficiency. Ammonia slip distribution in the down gas pass was uneven and ammonia slip was higher in the front of the down gas pass than in the rear of the down gas pass. NSR and NOx reduction were proportional to each other and usually resulted in more ammonia slip with reduction in NOx. About 100 mg/Nm{sup 3} NOx emission could be achieved with about 40 ppm NH{sub 3} slip at 300-450 t/h, and ammonia slip from the SNCR reactions could be used as reducing agent of SCR, which was favorable for the future SCR retrofit.

  7. Engineering development of advanced coal-fired low emission boiler systems

    SciTech Connect (OSTI)

    Not Available

    1993-10-01

    Riley Stoker Corporation is leading an R&D program for the expedited development of a new generation of pulverized coal-fired boiler systems. The overall objective is to develop relatively near term technologies to produce Low-Emission coal-fired Boiler Systems (LEBS) ready for full scale commercial generating plants by the end of the decade. The specific goal is to develop a LEBS incorporating an advanced slagging system for improved ash management in addition to meeting the emission and performance goals. This Concept Selection Report documents an evaluation of subsystems and LEBS concepts. Priority was given to the evaluation of the boiler system, steam cycle, and advanced slagging combustor. Some findings are as follows: An ultra supercritical steam cycle is required to meet project efficiency goals. The cost of electricity (COE) for this cycle, at today`s fuel prices, and without externality costs, is slightly higher than a conventional subcritical cycle. The supercritical cycle includes a substantial contingency. Reduction of contingency, escalation of fuel cost, or inclusion of externalities all lead to a lower COE for the supercritical cycle compared to the subcritical cycle. The advanced cycle is selected for inclusion in the LEBS. The advanced slagging combustor (TVC), should it meet the projected performance goals, yields a lower COE than either a dry firing system or a more conventional slagger fitted with post combustion NO{sub x} controls. Verification and development of the advanced slagger performance is the primary focus of this project. A commercial slagging configuration know as U-firing is selected for parallel development and as a platform for adaptation to the TVC.

  8. Innovative Clean Coal Technology (ICCT): Demonstration of selective catalytic reduction (SCR) technology for the control of nitrogen oxide (NO{sub x}) emissions from high-sulfur coal-fired boilers. Technical progress report, third and fourth quarters 1994

    SciTech Connect (OSTI)

    1995-11-01

    The objective of this project is to demonstrate and evaluate commercially available selective catalytic reduction (SCR) catalysts from U.S., Japanese, and European catalyst suppliers on a high-sulfur U.S. Coal-fired boiler. SCR is a post-combustion nitrogen oxide (NO{sub x}) control technology that involves injecting ammonia into the flue gas generated from coal combustion in an electric utility boiler. The flue gas containing ammonia is then passed through a reactor that contains a specialized catalyst. In the presence of the catalyst, the ammonia reacts with NO{sub x} to form nitrogen and water vapor. Although SCR is widely practiced in Japan and European gas-, oil-, and low-sulfur coal-fired boilers, there are several technical uncertainties associated with applying SCR to U.S. coals. These uncertainties include: (1) potential catalyst deactivation due to poisoning by trace metal species present in U.S. coals that are not present in other fuels; (2) performance of the technology and effects on the balance-of-plant equipment in the presence of high amounts of SO{sub 2} and SO{sub 3}; performance of a wide variety of SCR catalyst compositions, geometries, and methods of manufacture under typical high-sulfur coal-fired utility operating conditions. These uncertainties are being explored by operating a series of small- scale SCR reactors and simultaneously exposing different SCR catalysts to flue gas derived from the combustion of high sulfur U.S. coal. The demonstration is being performed at Gulf Power Company`s Plant Crist Unit No. 5 (75 MW capacity) near Pensacola, Florida. The project is funded by the U.S. Department of Energy (DOE), Southern Company Services, Inc. (SCS on behalf of the entire Southern electric system), the Electric Power Research Institute (EPRI), and Ontario Hydro. SCS is the participant responsible for managing al aspects of this project. 1 ref., 69 figs., 45 tabs.

  9. Innovative Clean Coal Technology (ICCT): Demonstration of Selective Catalytic Reduction (SCR) technology for the control of nitrogen oxide (NO{sub x}) emissions from high-sulfur coal-fired boilers. Third quarterly technical progress report 1992

    SciTech Connect (OSTI)

    Not Available

    1992-11-01

    The objective of this project is to demonstrate and evaluate commercially available Selective Catalytic Reduction (SCR) catalysts from US, Japanese and European catalyst suppliers on a high-sulfur US coal-fired boiler. SCR is a post-combustion nitrogen oxide (NO{sub x}) control technology that involves injecting ammonia into the flue gas generated from coal combustion in an electric utility boiler. The flue gas containing ammonia is then passed through a reactor that contains a specialized catalyst. In the presence of the catalyst, the ammonia reacts with NO{sub x} to convert it to nitrogen and water vapor. Although SCR is widely practiced in Japan and Europe on gas-, oil-, and low-sulfur, coal-fired boilers, there are several technical uncertainties associated with applying SCR to US coals. These uncertainties include: (1) potential catalyst deactivation due to poisoning by trace metal species present in US coals that are not present in other fuels. (2) performance of the technology and effects on the balance-of-plant equipment in the presence of high amounts of SO{sub 2} and SO{sub 3} and (3) performance of a wide variety of SCR catalyst compositions, geometries and methods of manufacture under typical high-sulfur coal-fired utility operating conditions. These uncertainties will be explored by constructing a series of small- scale SCR reactors and simultaneously exposing different SCR catalysts to flue gas derived from the combustion of high-sulfur US coal. The demonstration will be performed at Gulf Power Company`s Plant Crist Unit No. 5 (75 MW capacity) near Pensacola, Florida.

  10. Innovative Clean Coal Technology (ICCT): Demonstration of Selective Catalytic Reduction (SCR) technology for the control of nitrogen oxide (NO[sub x]) emissions from high-sulfur coal-fired boilers

    SciTech Connect (OSTI)

    Not Available

    1992-11-01

    The objective of this project is to demonstrate and evaluate commercially available Selective Catalytic Reduction (SCR) catalysts from US, Japanese and European catalyst suppliers on a high-sulfur US coal-fired boiler. SCR is a post-combustion nitrogen oxide (NO[sub x]) control technology that involves injecting ammonia into the flue gas generated from coal combustion in an electric utility boiler. The flue gas containing ammonia is then passed through a reactor that contains a specialized catalyst. In the presence of the catalyst, the ammonia reacts with NO[sub x] to convert it to nitrogen and water vapor. Although SCR is widely practiced in Japan and Europe on gas-, oil-, and low-sulfur, coal-fired boilers, there are several technical uncertainties associated with applying SCR to US coals. These uncertainties include: (1) potential catalyst deactivation due to poisoning by trace metal species present in US coals that are not present in other fuels. (2) performance of the technology and effects on the balance-of-plant equipment in the presence of high amounts of SO[sub 2] and SO[sub 3] and (3) performance of a wide variety of SCR catalyst compositions, geometries and methods of manufacture under typical high-sulfur coal-fired utility operating conditions. These uncertainties will be explored by constructing a series of small- scale SCR reactors and simultaneously exposing different SCR catalysts to flue gas derived from the combustion of high-sulfur US coal. The demonstration will be performed at Gulf Power Company's Plant Crist Unit No. 5 (75 MW capacity) near Pensacola, Florida.

  11. Cermet composite thermal spray coatings for erosion and corrosion protection in combustion environments of advanced coal-fired boilers. Semi-annual technical progress report, February 1996--July 1996

    SciTech Connect (OSTI)

    Banovic, S.W.; Levin, B.F.; DuPont, J.N.; Marder, A.R.

    1996-08-01

    Present coal-fired boiler environments remain hostile to the materials of choice since corrosion and erosion can be a serious problem in certain regions of the boiler. Recently, the Clean Air Act Amendment is requiring electric power plants to reduce NO{sub x}, emissions to the environment. To reduce NO{sub x}, emissions, new low NO{sub x}, combustors are utilized which burn fuel with a substoichiometric amount of oxygen (i.e., low oxygen partial pressure). In these low NO{sub x} environments, H{sub 2}S gas is a major source of sulfur. Due to the sulfidation process, corrosion rates in reducing parts of boilers have increased significantly and existing boiler tube materials do not always provide adequate corrosion resistance. Combined attack due to corrosion and erosion is a concern because of the significantly increased operating costs which result in material failures. One method to combat corrosion and erosion in coal-fired boilers is to apply coatings to the components subjected to aggressive environments. Thermal spray coatings, a cermet composite comprised of hard ceramic phases of oxide and/or carbide in a metal binder, have been used with some success as a solution to the corrosion and erosion problems in boilers. However, little is known on the effect of the volume fraction, size, and shape of the hard ceramic phase on the erosion and corrosion resistance of the thermally sprayed coatings. It is the objective of this research to investigate metal matrix composite (cermet) coatings in order to determine the optimum ceramic/metal combination that will give the best erosion and corrosion resistance in new advanced coal-fired boilers.

  12. Fire in the hole - Paging in mines from Pennsylvania to China, coal fires threaten towns, poison air and water, and add to global warming

    SciTech Connect (OSTI)

    Krajick, K.

    2005-05-01

    China has the most coal fires, but India has the largest concentration of them. The effect of coal fires on the once thriving town of Centralia, Pennsylvania is described. There have been eight attempts to put the fire out using different methods (it has been burning for 43 years), but has now been left to burn. It could burn for another 205 years. The population of the town have mostly been relocated.

  13. Less electricity use this summer slightly offset by higher power...

    Annual Energy Outlook

    8% in their summer electricity bills. EIA forecasts that more electricity will be generated this year by natural gas, solar energy, and wind and less from coal-fired power plants.

  14. Diné Power Authority - Navajo Transmission Project and other...

    Energy.gov (indexed) [DOE]

    ... DREP 2004 Air Permit Application 0.06 Air Permit * Desert Rock submitted an application with the lowest emission rates for any pulverized coal fired power plant in the US to ...

  15. Micronized coal-fired retrofit system for SO{sub x} reduction - Krakow Clean Fossil Fuels and Energy Efficiency Program.

    SciTech Connect (OSTI)

    1996-09-30

    the project proposes to install a new TCS micronized coal-fired heating plant for the Produkcja I Hodowla Roslin Ogrodniczych (PHRO) Greenhouse Complex, Krzeszowice, Poland (about 20 miles west of Krakow). PHRO currently utilizes 14 heavy oil-fired boilers to produce heat for its greenhouse facilities and also home heating to several adjacent apartment housing complexes. The boilers currently burn a high-sulfur content heavy crude oil, called Mazute. The micronized coal fired boiler would (1) provide a significant portion of the heat for PHRO and a portion of the adjacent apartment housing complexes, (2) dramatically reduce sulfur dioxide air pollution emission, while satisfying new Polish air regulations, and (3) provide attractive savings to PHRO, based on the quantity of displaced oil.

  16. Field Test Program for Long-Term Operation of a COHPAC System for Removing Mercury from Coal-Fired Flue Gas

    SciTech Connect (OSTI)

    Jean Bustard; Charles Lindsey; Paul Brignac; Travis Starns; Sharon Sjostrom; Cindy Larson

    2005-07-14

    With the Nation's coal-burning utilities facing the possibility of tighter controls on mercury pollutants, the U.S. Department of Energy is funding projects that could offer power plant operators better ways to reduce these emissions at much lower costs. Sorbent injection technology represents one of the simplest and most mature approaches to controlling mercury emissions from coal-fired boilers. It involves injecting a solid material such as powdered activated carbon into the flue gas. The gas-phase mercury in the flue gas contacts the sorbent and attaches to its surface. The sorbent with the mercury attached is then collected by the existing particle control device along with the other solid material, primarily fly ash. During 2001, ADA Environmental Solutions (ADA-ES) conducted a full-scale demonstration of sorbent-based mercury control technology at the Alabama Power E.C. Gaston Station (Wilsonville, Alabama). This unit burns a low-sulfur bituminous coal and uses a hot-side electrostatic precipitator (ESP) in combination with a Compact Hybrid Particulate Collector (COHPAC{reg_sign}) baghouse to collect fly ash. The majority of the fly ash is collected in the ESP with the residual being collected in the COHPAC{reg_sign} baghouse. Activated carbon was injected between the ESP and COHPAC{reg_sign} units to collect the mercury. Short-term mercury removal levels in excess of 90% were achieved using the COHPAC{reg_sign} unit. The test also showed that activated carbon was effective in removing both forms of mercury-elemental and oxidized. However, a great deal of additional testing is required to further characterize the capabilities and limitations of this technology relative to use with baghouse systems such as COHPAC{reg_sign}. It is important to determine performance over an extended period of time to fully assess all operational parameters. The project described in this report focuses on fully demonstrating sorbent injection technology at a coal-fired power

  17. Field Test Program for Long-Term Operation of a COHPAC System for Removing Mercury from Coal-Fired Flue Gas

    SciTech Connect (OSTI)

    Jean Bustard; Charles Lindsey; Paul Brignac; Travis Starns; Sharon Sjostrom; Cindy Larson

    2006-01-27

    With the Nation's coal-burning utilities facing the possibility of tighter controls on mercury pollutants, the U.S. Department of Energy is funding projects that could offer power plant operators better ways to reduce these emissions at much lower costs. Sorbent injection technology represents one of the simplest and most mature approaches to controlling mercury emissions from coal-fired boilers. It involves injecting a solid material such as powdered activated carbon into the flue gas. The gas-phase mercury in the flue gas contacts the sorbent and attaches to its surface. The sorbent with the mercury attached is then collected by the existing particle control device along with the other solid material, primarily fly ash. During 2001, ADA Environmental Solutions (ADA-ES) conducted a full-scale demonstration of sorbent-based mercury control technology at the Alabama Power E.C. Gaston Station (Wilsonville, Alabama). This unit burns a low-sulfur bituminous coal and uses a hot-side electrostatic precipitator (ESP) in combination with a Compact Hybrid Particulate Collector (COHPAC{reg_sign}) baghouse to collect fly ash. The majority of the fly ash is collected in the ESP with the residual being collected in the COHPAC{reg_sign} baghouse. Activated carbon was injected between the ESP and COHPAC{reg_sign} units to collect the mercury. Short-term mercury removal levels in excess of 90% were achieved using the COHPAC{reg_sign} unit. The test also showed that activated carbon was effective in removing both forms of mercury-elemental and oxidized. However, a great deal of additional testing is required to further characterize the capabilities and limitations of this technology relative to use with baghouse systems such as COHPAC{reg_sign}. It is important to determine performance over an extended period of time to fully assess all operational parameters. The project described in this report focuses on fully demonstrating sorbent injection technology at a coal-fired power

  18. Field Test Program for Long-Term Operation of a COHPAC System for Removing Mercury from Coal-Fired Flue Gas

    SciTech Connect (OSTI)

    Jean Bustard; Charles Lindsey; Paul Brignac; Travis Starns; Sharon Sjostrom; Trent Taylor; Cindy Larson

    2004-08-06

    With the Nation's coal-burning utilities facing the possibility of tighter controls on mercury pollutants, the U.S. Department of Energy is funding projects that could offer power plant operators better ways to reduce these emissions at much lower costs. Sorbent injection technology represents one of the simplest and most mature approaches to controlling mercury emissions from coal-fired boilers. It involves injecting a solid material such as powdered activated carbon into the flue gas. The gas-phase mercury in the flue gas contacts the sorbent and attaches to its surface. The sorbent with the mercury attached is then collected by the existing particle control device along with the other solid material, primarily fly ash. During 2001, ADA Environmental Solutions (ADA-ES) conducted a full-scale demonstration of sorbent-based mercury control technology at the Alabama Power E.C. Gaston Station (Wilsonville, Alabama). This unit burns a low-sulfur bituminous coal and uses a hot-side electrostatic precipitator (ESP) in combination with a Compact Hybrid Particulate Collector (COHPAC{reg_sign}) baghouse to collect fly ash. The majority of the fly ash is collected in the ESP with the residual being collected in the COHPAC{reg_sign} baghouse. Activated carbon was injected between the ESP and COHPAC{reg_sign} units to collect the mercury. Short-term mercury removal levels in excess of 90% were achieved using the COHPAC{reg_sign} unit. The test also showed that activated carbon was effective in removing both forms of mercury-elemental and oxidized. However, a great deal of additional testing is required to further characterize the capabilities and limitations of this technology relative to use with baghouse systems such as COHPAC{reg_sign}. It is important to determine performance over an extended period of time to fully assess all operational parameters. The project described in this report focuses on fully demonstrating sorbent injection technology at a coal-fired power

  19. Field Test Program for Long-Term Operation of a COHPAC System for Removing Mercury from Coal-Fired Flue Gas

    SciTech Connect (OSTI)

    Jean Bustard; Charles Lindsey; Paul Brignac; Travis Starns; Sharon Sjostrom; Trent Taylor; Cindy Larson

    2004-06-04

    With the Nation's coal-burning utilities facing the possibility of tighter controls on mercury pollutants, the U.S. Department of Energy is funding projects that could offer power plant operators better ways to reduce these emissions at much lower costs. Sorbent injection technology represents one of the simplest and most mature approaches to controlling mercury emissions from coal-fired boilers. It involves injecting a solid material such as powdered activated carbon into the flue gas. The gas-phase mercury in the flue gas contacts the sorbent and attaches to its surface. The sorbent with the mercury attached is then collected by the existing particle control device along with the other solid material, primarily fly ash. During 2001, ADA Environmental Solutions (ADA-ES) conducted a full-scale demonstration of sorbent-based mercury control technology at the Alabama Power E.C. Gaston Station (Wilsonville, Alabama). This unit burns a low-sulfur bituminous coal and uses a hot-side electrostatic precipitator (ESP) in combination with a Compact Hybrid Particulate Collector (COHPAC{reg_sign}) baghouse to collect fly ash. The majority of the fly ash is collected in the ESP with the residual being collected in the COHPAC{reg_sign} baghouse. Activated carbon was injected between the ESP and COHPAC{reg_sign} units to collect the mercury. Short-term mercury removal levels in excess of 90% were achieved using the COHPAC{reg_sign} unit. The test also showed that activated carbon was effective in removing both forms of mercury-elemental and oxidized. However, a great deal of additional testing is required to further characterize the capabilities and limitations of this technology relative to use with baghouse systems such as COHPAC{reg_sign}. It is important to determine performance over an extended period of time to fully assess all operational parameters. The project described in this report focuses on fully demonstrating sorbent injection technology at a coal-fired power

  20. Field Test Program for Long-Term Operation of a COHPAC System for Removing Mercury from Coal-Fired Flue Gas

    SciTech Connect (OSTI)

    Jean Bustard; Charles Lindsey; Paul Brignac; Travis Starns; Sharon Sjostrom; Trent Taylor; Cindy Larson

    2004-10-25

    With the Nation's coal-burning utilities facing the possibility of tighter controls on mercury pollutants, the U.S. Department of Energy is funding projects that could offer power plant operators better ways to reduce these emissions at much lower costs. Sorbent injection technology represents one of the simplest and most mature approaches to controlling mercury emissions from coal-fired boilers. It involves injecting a solid material such as powdered activated carbon into the flue gas. The gas-phase mercury in the flue gas contacts the sorbent and attaches to its surface. The sorbent with the mercury attached is then collected by the existing particle control device along with the other solid material, primarily fly ash. During 2001, ADA Environmental Solutions (ADA-ES) conducted a full-scale demonstration of sorbent-based mercury control technology at the Alabama Power E.C. Gaston Station (Wilsonville, Alabama). This unit burns a low-sulfur bituminous coal and uses a hot-side electrostatic precipitator (ESP) in combination with a Compact Hybrid Particulate Collector (COHPAC{reg_sign}) baghouse to collect fly ash. The majority of the fly ash is collected in the ESP with the residual being collected in the COHPAC{reg_sign} baghouse. Activated carbon was injected between the ESP and COHPAC{reg_sign} units to collect the mercury. Short-term mercury removal levels in excess of 90% were achieved using the COHPAC{reg_sign} unit. The test also showed that activated carbon was effective in removing both forms of mercury-elemental and oxidized. However, a great deal of additional testing is required to further characterize the capabilities and limitations of this technology relative to use with baghouse systems such as COHPAC{reg_sign}. It is important to determine performance over an extended period of time to fully assess all operational parameters. The project described in this report focuses on fully demonstrating sorbent injection technology at a coal-fired power

  1. FIELD TEST PROGRAM FOR LONG-TERM OPERATION OF A COHPAC SYSTEM FOR REMOVING MERCURY FROM COAL-FIRED FLUE GAS

    SciTech Connect (OSTI)

    Jean Bustard; Charles Lindsey; Paul Brignac; Travis Starns; Sharon Sjostrom; Trent Taylor; Cindy Larson

    2004-01-29

    With the Nation's coal-burning utilities facing the possibility of tighter controls on mercury pollutants, the U.S. Department of Energy is funding projects that could offer power plant operators better ways to reduce these emissions at much lower costs. Sorbent injection technology represents one of the simplest and most mature approaches to controlling mercury emissions from coal-fired boilers. It involves injecting a solid material such as powdered activated carbon into the flue gas. The gas-phase mercury in the flue gas contacts the sorbent and attaches to its surface. The sorbent with the mercury attached is then collected by the existing particle control device along with the other solid material, primarily fly ash. During 2001, ADA Environmental Solutions (ADA-ES) conducted a full-scale demonstration of sorbent-based mercury control technology at the Alabama Power E.C. Gaston Station (Wilsonville, AL). This unit burns a low-sulfur bituminous coal and uses a hot-side electrostatic precipitator (ESP) in combination with a Compact Hybrid Particulate Collector (COHPAC{trademark}) baghouse to collect fly ash. The majority of the fly ash is collected in the ESP with the residual being collected in the COHPAC{trademark} baghouse. Activated carbon was injected between the ESP and COHPAC{trademark} units to collect the mercury. Short-term mercury removal levels in excess of 90% were achieved using the COHPAC{trademark} unit. The test also showed that activated carbon was effective in removing both forms of mercury--elemental and oxidized. However, a great deal of additional testing is required to further characterize the capabilities and limitations of this technology relative to use with baghouse systems such as COHPAC{trademark}. It is important to determine performance over an extended period of time to fully assess all operational parameters. The project described in this report focuses on fully demonstrating sorbent injection technology at a coal-fired power

  2. Field Test Program for Long-Term Operation of a COHPAC System for Removing Mercury from Coal-Fired Flue Gas

    SciTech Connect (OSTI)

    Jean Bustard; Charles Lindsey; Paul Brignac: Travis Starns; Sharon Sjostrom; Trent Taylor; Cindy Larson

    2005-04-28

    With the Nation's coal-burning utilities facing the possibility of tighter controls on mercury pollutants, the U.S. Department of Energy is funding projects that could offer power plant operators better ways to reduce these emissions at much lower costs. Sorbent injection technology represents one of the simplest and most mature approaches to controlling mercury emissions from coal-fired boilers. It involves injecting a solid material such as powdered activated carbon into the flue gas. The gas-phase mercury in the flue gas contacts the sorbent and attaches to its surface. The sorbent with the mercury attached is then collected by the existing particle control device along with the other solid material, primarily fly ash. During 2001, ADA Environmental Solutions (ADA-ES) conducted a full-scale demonstration of sorbent-based mercury control technology at the Alabama Power E.C. Gaston Station (Wilsonville, Alabama). This unit burns a low-sulfur bituminous coal and uses a hot-side electrostatic precipitator (ESP) in combination with a Compact Hybrid Particulate Collector (COHPAC{reg_sign}) baghouse to collect fly ash. The majority of the fly ash is collected in the ESP with the residual being collected in the COHPAC{reg_sign} baghouse. Activated carbon was injected between the ESP and COHPAC{reg_sign} units to collect the mercury. Short-term mercury removal levels in excess of 90% were achieved using the COHPAC{reg_sign} unit. The test also showed that activated carbon was effective in removing both forms of mercury-elemental and oxidized. However, a great deal of additional testing is required to further characterize the capabilities and limitations of this technology relative to use with baghouse systems such as COHPAC{reg_sign}. It is important to determine performance over an extended period of time to fully assess all operational parameters. The project described in this report focuses on fully demonstrating sorbent injection technology at a coal-fired power

  3. Field Test Program for Long-Term Operation of a COHPAC System for Removing Mercury from Coal-Fired Flue Gas

    SciTech Connect (OSTI)

    Jean Bustard; Charles Lindsey; Paul Brignac; Travis Starns; Sharon Sjostrom; Cindy Larson

    2006-04-24

    With the Nation's coal-burning utilities facing the possibility of tighter controls on mercury pollutants, the U.S. Department of Energy is funding projects that could offer power plant operators better ways to reduce these emissions at much lower costs. Sorbent injection technology represents one of the simplest and most mature approaches to controlling mercury emissions from coal-fired boilers. It involves injecting a solid material such as powdered activated carbon into the flue gas. The gas-phase mercury in the flue gas contacts the sorbent and attaches to its surface. The sorbent with the mercury attached is then collected by the existing particle control device along with the other solid material, primarily fly ash. During 2001, ADA Environmental Solutions (ADA-ES) conducted a full-scale demonstration of sorbent-based mercury control technology at the Alabama Power E.C. Gaston Station (Wilsonville, Alabama). This unit burns a low-sulfur bituminous coal and uses a hot-side electrostatic precipitator (ESP) in combination with a Compact Hybrid Particulate Collector (COHPAC{reg_sign}) baghouse to collect fly ash. The majority of the fly ash is collected in the ESP with the residual being collected in the COHPAC{reg_sign} baghouse. Activated carbon was injected between the ESP and COHPAC{reg_sign} units to collect the mercury. Short-term mercury removal levels in excess of 90% were achieved using the COHPAC{reg_sign} unit. The test also showed that activated carbon was effective in removing both forms of mercury-elemental and oxidized. However, a great deal of additional testing is required to further characterize the capabilities and limitations of this technology relative to use with baghouse systems such as COHPAC{reg_sign}. It is important to determine performance over an extended period of time to fully assess all operational parameters. The project described in this report focuses on fully demonstrating sorbent injection technology at a coal-fired power

  4. Field Test Program for Long-Term Operation of a COHPAC System for Removing Mercury from Coal-Fired Flue Gas

    SciTech Connect (OSTI)

    Jean Bustard; Charles Lindsey; Paul Brignac; Travis Starns; Sharon Sjostrom; Cindy Larson

    2005-10-24

    With the Nation's coal-burning utilities facing the possibility of tighter controls on mercury pollutants, the U.S. Department of Energy is funding projects that could offer power plant operators better ways to reduce these emissions at much lower costs. Sorbent injection technology represents one of the simplest and most mature approaches to controlling mercury emissions from coal-fired boilers. It involves injecting a solid material such as powdered activated carbon into the flue gas. The gas-phase mercury in the flue gas contacts the sorbent and attaches to its surface. The sorbent with the mercury attached is then collected by the existing particle control device along with the other solid material, primarily fly ash. During 2001, ADA Environmental Solutions (ADA-ES) conducted a full-scale demonstration of sorbent-based mercury control technology at the Alabama Power E.C. Gaston Station (Wilsonville, Alabama). This unit burns a low-sulfur bituminous coal and uses a hot-side electrostatic precipitator (ESP) in combination with a Compact Hybrid Particulate Collector (COHPAC{reg_sign}) baghouse to collect fly ash. The majority of the fly ash is collected in the ESP with the residual being collected in the COHPAC{reg_sign} baghouse. Activated carbon was injected between the ESP and COHPAC{reg_sign} units to collect the mercury. Short-term mercury removal levels in excess of 90% were achieved using the COHPAC{reg_sign} unit. The test also showed that activated carbon was effective in removing both forms of mercury-elemental and oxidized. However, a great deal of additional testing is required to further characterize the capabilities and limitations of this technology relative to use with baghouse systems such as COHPAC{reg_sign}. It is important to determine performance over an extended period of time to fully assess all operational parameters. The project described in this report focuses on fully demonstrating sorbent injection technology at a coal-fired power

  5. Field Test Program for Long-Term Operation of a COHPAC System for Removing Mercury from Coal-Fired Flue Gas

    SciTech Connect (OSTI)

    Jean Bustard; Charles Lindsey; Paul Brignac; Travis Starns; Sharon Sjostrom; Trent Taylor; Cindy Larson

    2005-01-24

    With the Nation's coal-burning utilities facing the possibility of tighter controls on mercury pollutants, the U.S. Department of Energy is funding projects that could offer power plant operators better ways to reduce these emissions at much lower costs. Sorbent injection technology represents one of the simplest and most mature approaches to controlling mercury emissions from coal-fired boilers. It involves injecting a solid material such as powdered activated carbon into the flue gas. The gas-phase mercury in the flue gas contacts the sorbent and attaches to its surface. The sorbent with the mercury attached is then collected by the existing particle control device along with the other solid material, primarily fly ash. During 2001, ADA Environmental Solutions (ADA-ES) conducted a full-scale demonstration of sorbent-based mercury control technology at the Alabama Power E.C. Gaston Station (Wilsonville, Alabama). This unit burns a low-sulfur bituminous coal and uses a hot-side electrostatic precipitator (ESP) in combination with a Compact Hybrid Particulate Collector (COHPAC{reg_sign}) baghouse to collect fly ash. The majority of the fly ash is collected in the ESP with the residual being collected in the COHPAC{reg_sign} baghouse. Activated carbon was injected between the ESP and COHPAC{reg_sign} units to collect the mercury. Short-term mercury removal levels in excess of 90% were achieved using the COHPAC{reg_sign} unit. The test also showed that activated carbon was effective in removing both forms of mercury-elemental and oxidized. However, a great deal of additional testing is required to further characterize the capabilities and limitations of this technology relative to use with baghouse systems such as COHPAC{reg_sign}. It is important to determine performance over an extended period of time to fully assess all operational parameters. The project described in this report focuses on fully demonstrating sorbent injection technology at a coal-fired power

  6. Conference on alternatives for pollution control from coal-fired low emission sources, Plzen, Czech Republic. Plzen Proceedings

    SciTech Connect (OSTI)

    Not Available

    1994-07-01

    The Conference on Alternatives for Pollution Control from Coal-Fired Emission Sources presented cost-effective approaches for pollution control of low emission sources (LES). It also identified policies and strategies for implementation of pollution control measures at the local level. Plzen, Czech Republic, was chosen as the conference site to show participants first hand the LES problems facing Eastern Europe today. Collectively, these Proceedings contain clear reports on: (a) methods for evaluating the cost effectiveness of alternative approaches to control pollution from small coal-fired boilers and furnaces; (b) cost-effective technologies for controlling pollution from coal-fired boilers and furnaces; (c) case studies of assessment of cost effective pollution control measures for selected cities in eastern Europe; and (d) approaches for actually implementing pollution control measures in cities in Eastern Europe. It is intended that the eastern/central European reader will find in these Proceedings useful measures that can be applied to control emissions and clean the air in his city or region. The conference was sponsored by the United States Agency for International Development (AID), the United States Department of Energy (DOE), and the Czech Ministry of Industry and Trade. Selected papers have been indexed separately for inclusion in the Energy Science and Technology Database.

  7. Preventing the self-destruction of the indirect coal firing system

    SciTech Connect (OSTI)

    Bush, C.W.; Rayner, C.C.

    1983-07-01

    The most widely used fuel in the cement industry is pulverized coal. The current trend is to burn coal through the use of an indirect firing system, as opposed to direct firing which was formerly standard for cement kilns. Indirect firing is favored for precalciners and to improve thermal efficiency, but the benefits are sometimes overshadowed by increased hazard potential. Thoughtful design and careful operating practices are essential for safe operation. The hazards are primarily a result of the explosive mixture of coal and air which can be formed in various parts of the system and the tendency for coal to self-heat and undergo spontaneous combustion. The systems for indirect coal firing are reviewed, with emphasis on the potential fire and explosion hazards. The effectiveness of various methods to extinguish a fire or suppress an explosion is discussed, together with their applicability and related operating problems. The available alarm systems are evaluated according to their ability to signal impending danger in time for corrective action. Some parameters of safe design and operating practices are outlined as a guide to avoiding the types of problems that have been experienced at some existing installations.

  8. Iron aluminide weld overlay coatings for boiler tube protection in coal-fired low NOx boilers

    SciTech Connect (OSTI)

    Banovic, S.W.; DuPont, J.N.; Marder, A.R.

    1997-12-01

    Iron aluminide weld overlay coatings are currently being considered for enhanced sulfidation resistance in coal-fired low NO{sub x} boilers. The use of these materials is currently limited due to hydrogen cracking susceptibility, which generally increases with an increase in aluminum concentration of the deposit. The overall objective of this program is to attain an optimum aluminum content with good weldability and improved sulfidation resistance with respect to conventional materials presently in use. Research has been initiated using Gas Tungsten Arc Welding (GTAW) in order to achieve this end. Under different sets of GTAW parameters (wire feed speed, current), both single and multiple pass overlays were produced. Characterization of all weldments was conducted using light optical microscopy, scanning electron microscopy, and electron probe microanalysis. Resultant deposits exhibited a wide range of aluminum contents (5--43 wt%). It was found that the GTAW overlays with aluminum contents above {approximately}10 wt% resulted in cracked coatings. Preliminary corrosion experiments of 5 to 10 wt% Al cast alloys in relatively simple H{sub 2}/H{sub 2}S gas mixtures exhibited corrosion rates lower than 304 stainless steel.

  9. Cost-effectiveness Analysis on Measures to Improve China's Coal-fired Industrial Boiler

    DOE PAGES-Beta [OSTI]

    Liu, Manzhi; Shen, Bo; Han, Yafeng; Price, Lynn; Xu, Mingchao

    2015-08-01

    Tackling coal-burning industrial boiler is becoming one of the key programs to solve the environmental problem in China. Assessing the economics of various options to address coal-fired boiler is essential to identify cost-effective solutions. This paper discusses our work in conducting a cost-effectiveness analysis on various types of improvement measures ranging from energy efficiency retrofits to switch from coal to other fuels in China. Sensitivity analysis was also performed in order to understand the impacts of some economic factors such as discount rate and energy price on the economics of boiler improvement options. The results show that nine out ofmore » 14 solutions are cost-effective, and a lower discount rate and higher energy price will result in more energy efficiency measures being cost-effective. Both monetary and non-monetary barriers to energy-efficiency improvement are discussed and policies to tackle these barriers are recommended. Our research aims at providing a methodology to assess cost-effective solutions to boiler problems.« less

  10. Cost-effectiveness Analysis on Measures to Improve China's Coal-fired Industrial Boiler

    SciTech Connect (OSTI)

    Liu, Manzhi; Shen, Bo; Han, Yafeng; Price, Lynn; Xu, Mingchao

    2015-08-01

    Tackling coal-burning industrial boiler is becoming one of the key programs to solve the environmental problem in China. Assessing the economics of various options to address coal-fired boiler is essential to identify cost-effective solutions. This paper discusses our work in conducting a cost-effectiveness analysis on various types of improvement measures ranging from energy efficiency retrofits to switch from coal to other fuels in China. Sensitivity analysis was also performed in order to understand the impacts of some economic factors such as discount rate and energy price on the economics of boiler improvement options. The results show that nine out of 14 solutions are cost-effective, and a lower discount rate and higher energy price will result in more energy efficiency measures being cost-effective. Both monetary and non-monetary barriers to energy-efficiency improvement are discussed and policies to tackle these barriers are recommended. Our research aims at providing a methodology to assess cost-effective solutions to boiler problems.

  11. Development of advanced NO[sub x] control concepts for coal-fired utility boilers

    SciTech Connect (OSTI)

    Evans, A.; Pont, J.N.; England, G.; Seeker, W.R.

    1993-03-04

    The complete CombiNO[sub x], process has now been demonstrated at a level that is believed to be representative of a full-scale boiler in terms of mixing capabilities. A summary of the results is displayedin Figure 5-1. While firing Illinois Coal on the Reburn Tower, Advanced Reburning was capable of reducing NO[sub x], by 83 percent. The injection of methanol oxidized 50--58 percent of the existing NO to N0[sub 2]. Assuming that 85 percent of the newly formed N0[sub 2] can be scrubbed in a liquor modified wet-limestone scrubber, the CombiNO[sub x], process has been shown capable of reducing NO[sub 2], by 90--91 percent in a large pilot-scale coal-fired furnace. There is still uncertainty regarding the fate of the N0[sub 2] formed with methanol injection. Tests should be conducted to determine whether the reconversion is thermodynamic or catalytic, and what steps can be taken (such as quench rate) to prevent it from happening.

  12. Subtask 4.27 - Evaluation of the Multielement Sorbent Trap (MEST) Method at an Illinois Coal-Fired Plant

    SciTech Connect (OSTI)

    Pavlish, John; Thompson, Jeffrey; Dunham, Grant

    2014-09-30

    that would interfere with accurate measurement at U.S. hazardous air pollutant emission limits for existing coal-fired power plant units. Longer sampling times employed during this test program did appear to improve comparative results for these metals. Although the sorbent contribution to the sample was reduced through improved trap design, additional research is still needed to explore lower-background materials before the MEST-M application can be considered as a potential alternative method for all of the trace metals. This subtask was funded through the EERC–U.S. Department of Energy Joint Program on Research and Development for Fossil Energy-Related Resources Cooperative Agreement No. DE-FC26-08NT43291. Nonfederal funding was provided by the Electric Power Research Institute, the Illinois Clean Coal Institute, Southern Illinois Power Company, and the Center for Air Toxic Metals Affiliates Program.

  13. Characterization of Oxy-combustion Impacts in Existing Coal-fired Boilers

    SciTech Connect (OSTI)

    Adams, Bradley; Davis, Kevin; Senior, Constance; Shim, Hong Shim; Otten, Brydger; Fry, Andrew; Wendt, Jost; Eddings, Eric; Paschedag, Alan; Shaddix, Christopher; Cox, William; Tree, Dale

    2013-09-30

    Reaction Engineering International (REI) managed a team of experts from University of Utah, Siemens Energy, Praxair, Vattenfall AB, Sandia National Laboratories, Brigham Young University (BYU) and Corrosion Management Ltd. to perform multi-scale experiments, coupled with mechanism development, process modeling and CFD modeling, for both applied and fundamental investigations. The primary objective of this program was to acquire data and develop tools to characterize and predict impacts of CO{sub 2} flue gas recycle and burner feed design on flame characteristics (burnout, NO{sub x}, SO{sub x}, mercury and fine particle emissions, heat transfer) and operational concerns (fouling, slagging and corrosion) inherent in the retrofit of existing coal-fired boilers for oxy-coal combustion. Experimental work was conducted at Sandia National Laboratories’ Entrained Flow Reactor, the University of Utah Industrial Combustion Research Facility, and Brigham Young University. Process modeling and computational fluid dynamics (CFD) modeling was performed at REI. Successful completion of the project objectives resulted in the following key deliverables: 1) Multi-scale test data from 0.1 kW bench-scale, 100 kW and 200 kW laboratory-scale, and 1 MW semi-industrial scale combustors that describe differences in flame characteristics, fouling, slagging and corrosion for coal combustion under air-firing and oxygen-firing conditions, including sensitivity to oxy-burner design and flue gas recycle composition. 2) Validated mechanisms developed from test data that describe fouling, slagging, waterwall corrosion, heat transfer, char burnout and sooting under coal oxy-combustion conditions. The mechanisms were presented in a form suitable for inclusion in CFD models or process models. 3) Principles to guide design of pilot-scale and full-scale coal oxy-firing systems and flue gas recycle configurations, such that boiler operational impacts from oxy-combustion retrofits are minimized. 4

  14. Wisconsin Public Service Corp's Weston 4 earns Power's highest honor

    SciTech Connect (OSTI)

    Peltier, R.

    2008-08-15

    Wisconsin Public Service Corp. placed its world-class Weston 4 into commercial service on June 30 and is now enjoying the benefits of coal-fired supercritical technology's inherently higher efficiency, operating flexibility and lower CO{sub 2} emissions. For its unequalled environmental protection credentials, well-integrated project team, and employing the most advanced coal-fired steam generation technology in the US today, Weston 4 is awarded Power magazine's 2008 Plant of the Year Award. 10 figs., 4 tabs.

  15. Gas cofiring in coal-fired stokers for emissions reduction and performance improvement

    SciTech Connect (OSTI)

    Mason, H.B.; Drennan, S.; Chan, I.; Kinney, W.L.; Borland, D.

    1996-12-31

    Adding gas burners above the grate of a coal-fired stoker can be an economical method of reducing gaseous and particulate emissions and improving efficiency and operational flexibility. With this cofiring configuration, the improved heat distribution and mixing with the stoker combustion products can give reduced opacity, reduced emissions of particulate, NO{sub x} and SO{sub 2}, improved carbon burnout and lower overall ash, reduced excess air, faster load response, cleaner and quicker lightoffs, improved turndown at both lower and upper capacity limits, and improved performance with problematic coals. To develop and validate the cofiring technology, three cofire field experiments have been conducted. A 165,000 lb/hr spreader stoker and mass feed chain grate stokers rated at 40,000 and 75,000 lb/hr have been retrofit with gas burners and tested in the field. The two larger units used dual, opposed burners, while the smaller unit was retrofit with a single burner. With the spreader stoker, the primary benefits of gas cofire was reduction in opacity episodes with coal quality variability and recovery of lost derate. With the larger chain grate unit, the primary benefit was reduction of NO{sub x} and SO{sub 2} to within Title V limits and elimination of opacity episodes during startup and load swings. With the smaller chain grate, the primary benefit was ability to operate at low loads without unacceptable opacity excursions which had previously required a backup boiler. In all cases, the economics justified the capital burner system retrofit cost and incremental fuel costs.

  16. Development of advanced NO[sub x] control concepts for coal-fired utility boilers

    SciTech Connect (OSTI)

    Evans, A.; Pont, J.N.; England, G.; Seeker, W.R.

    1992-09-15

    All three of the CombiNO[sub x] NO[sub x] control technologies were performed simultaneously for the first time. Tests were performed while firing coal as the primary fuel, and natural gas and coal as reburn fuels. The results for the complete CombiNO[sub x] process for coal firing and natural gas reburning are displayed in Figure 3-1. NO/NO[sub x] measurements were taken with the new sample system. The filter and line were cleaned periodically throughout testing to avoid ash build-up; ash has also been shown to convert NO[sub 2] to NO. Reduction due to natural gas reburning was 54% with burnout air injected at a downstream location of approximately 1600[degree]F. Advanced Gas Reburning produced a 79% reduction -- although it is suspected that better reduction would have been possible if injection resolution in the furnace allowed the urea to be injected at a more optimum temperature of 1850[degree]F. The methanol injection step converted 45% of the existing NO to NO[sub 2], achieving an overall CombiNO[sub x] NO reduction of 89%. The coal reburning CombiNO[sub x] test results are displayed in Figure 3-2. Results are similar to those obtained for natural gas reburning. Reduction due to urea injection was better while reburning with coal than for natural gas, probably due to the more optimum urea injection temperature. The methanol injection step converted 40% of the NO to NO[sub 2], similar to the 45% NO conversion that occurred for natural gas reburning. An overall CombiNO[sub x] NO reduction of 93% was achieved, resulting in a final NO concentration of 61 ppM at 3% O[sub 2].

  17. Optical Thin Films for Gas Sensing in Advanced Coal Fired Power Plants

    SciTech Connect (OSTI)

    Ohodnicki, Paul; Brown, Thomas; Baltrus John; Chorpening, Benjamin

    2012-08-09

    Even for existing coal based plants, the opportunity for sensors and controls to improve efficiency is great. A wide range of gas species are of interest for relevant applications. Functional sensor layers for embedded sensing must be compatible with extreme conditions (temperature, pressure, corrosive). Au incorporated metal oxides have been looked at by a number of other authors previously for gas sensing, but have often focused on temperatures below 500{degree}C. Au nanoparticle incorporated metal oxide thin films have shown enhanced gas sensing response. In prior work, we have demonstrated that material systems such as Au nanoparticle incorporated TiO{sub 2} films exhibit a potentially useful optical response to changing gas atmospheres at temperatures up to ~800-850{degree}C. Current work is focused on sputter-deposited Au/TiO{sub 2} films. Au and Ti are multi-layered sputter deposited, followed by a 950{degree}C oxidation step. Increasing Au layer thickness yields larger particles. Interband electronic transitions significantly modify the optical constants of Au as compared to the damped free electron theory. A high temperature oxidation (20%O{sub 2}/N{sub 2}) treatment was performed at 700{degree}C followed by a reduction (4%H{sub 2}/N{sub 2}) treatment to illustrate the shift in both absorption and scattering with exposure to reducing gases. Shift of localized surface plasmon resonance (LSPR) absorption peak in changing gas atmospheres is well documented, but shift in the peak associated with diffuse scattering is a new observation. Increasing Au layer-thickness results in an increase in LSPR absorption and a shift to longer wavelengths. Diffuse scattering associated with the LSPR resonance of Au shows a similar trend with increasing Au thickness. To model the temperature dependence of LSPR, the modification to the plasmon frequency, the damping frequency, and the dielectric constant of the oxide matrix must be accounted for. Thermal expansion of Au causes a decrease in free-carrier concentration and plasmon frequency with increasing temperature. Increased scattering of electrons with increasing temperatures results in an increased damping frequency for free carriers. The thermo-optic coefficient of TiO{sub 2} is assumed to be constant or decreasing with increasing temperature. A Custom Designed System Can Be Used to Monitor Optical Transmission and Reflection of Films at Elevated Temperatures and Upon Exposure to Changing Ambient Gas Atmospheres. The calculated extinction peak broadens and reduces peak height with increasing temperature. Extinction spectra measured using the elevated temperature system deviate from measurements performed with an integrating sphere. Modifications to measured transmittance and reflectance spectra are observed with increasing temperatures. Optical constants of Au nanoparticles were measured for elevated temperature. The thermo-optic coefficient of TiO{sub 2} strongly affects the shift in LSPR absorption peak. Peak broadening is dictated by the increased damping frequency of Au. In all cases of the theoretical modeling, we are assuming a particle of Au embedded in a TiO{sub 2} matrix without any interparticle interaction. Localized surface plasmon resonance in noble metal nanoparticles is associated with the free electrons. Surface charges create an internal field that acts as a restoring force on displaced charge carriers resulting in an oscillation with an associated resonance. An estimate of the sensitivity as a function of wavelength for sensing done using a single wavelength transmission measurement can be derived by focusing on the partial derivative of Q{sub abs} with respect to the material parameter that we assume is changing during the experiment. We focus on the free carrier density. However, other material parameters may also change in some cases. Peak sensitivity for transmission or absorption based sensing occurs on either side of the LSPR absorption peak maximum. Theoretically predicted wavelength dependence is consistent with the literature. The wavelength of LSPR absorption peak sensitivity shifts with increasing temperature due to broadening and peak shifting. The maximum sensitivity decreases with increasing temperature. The sensitivity should also depend on the mechanism responsible for the solid-gas interaction.

  18. Analysis of Heat Rate Improvement Potential at Coal-Fired Power...

    U.S. Energy Information Administration (EIA) (indexed site)

    ... Analysis Office of Electricity, Coal, Nuclear and Renewables Analysis Prepared by: ... 2008) using the RS Means Construction Facilities Cost Data - 28th annual edition ...

  19. ATMOSPHERIC AEROSOL SOURCE-RECEPTOR RELATIONSHIPS: THE ROLE OF COAL-FIRED POWER PLANTS

    SciTech Connect (OSTI)

    Allen L. Robinson; Spyros N. Pandis; Cliff I. Davidson

    2003-11-01

    This report describes the technical progress made on the Pittsburgh Air Quality Study (PAQS) during the period of March 2003 through August 2003. Significant progress was made this project period on the source characterization, source apportionment, and deterministic modeling activities. Major accomplishments included: Development of an emission profile for an integrated coke production facility and simulations using PMCAMx for a two week period during July 2001. The emissions from the coke facility are dominated by carbonaceous compounds. Forty seven percent of the organic carbon mass was identified on a compound level basis. Polycyclic aromatic hydrocarbons were the dominant organic compound class in the coke emissions. Initial comparisons with the data collected in Pittsburgh suggest good agreement between the model predictions and observations. Single particle composition data appear useful for identifying primary sources. An example of this unique approach is illustrated using the Fe and Ce particle class with appear associated with steel production.

  20. Coal fired fluid bed module for a single elevation style fluid bed power plant

    DOE Patents [OSTI]

    Waryasz, Richard E.

    1979-01-01

    A fluidized bed for the burning of pulverized fuel having a specific waterwall arrangement that comprises a structurally reinforced framework of wall tubes. The wall tubes are reversely bent from opposite sides and then bonded together to form tie rods that extend across the bed to support the lateral walls thereof.

  1. Analysis of Heat Rate Improvement Potential at Coal-Fired Power...

    Annual Energy Outlook

    The projections in the AEO2015 are produced by the National Energy Modeling System (NEMS), ... three primary functions - capacity planning, fuel dispatching, and finance and pricing. ...

  2. Portland cement for SO.sub.2 control in coal-fired power plants

    DOE Patents [OSTI]

    Steinberg, Meyer

    1985-01-01

    There is described a method of removing oxides of sulfur from the emissions of fossil fuel combustion by injecting portland cement into the boiler with the fuel, the combustion air, or downstream with the combustion gases. There is also described the cement products that result from this method.

  3. Portland cement for SO/sub 2/ control in coal-fired power plants

    DOE Patents [OSTI]

    Steinberg, M.

    1984-10-17

    A method is described for removing oxides of sulfur from the emissions of fossil fuel combustion by injecting portland cement into the boiler with the fuel, the combustion air, or downstream with the combustion gases. The cement products that result from this method is also described. 1 tab.

  4. ATMOSPHERIC AEROSOL SOURCE-RECEPTOR RELATIONSHIPS: THE ROLE OF COAL-FIRED POWER PLANTS

    SciTech Connect (OSTI)

    Allen L. Robinson; Spyros N. Pandis; Cliff I. Davidson

    2004-04-01

    This report describes the technical progress made on the Pittsburgh Air Quality Study (PAQS) during the period of September 2003 through February 2004. Significant progress was made this project period on the analysis of ambient data, source apportionment, and deterministic modeling activities. Results highlighted in this report include chemical fractionation of the organic fraction to quantify the ratio of organic mass to organic carbon (OM/OC). The average OM/OC ratio for the 31 samples analyzed so far is 1.89, ranging between 1.62 and 2.53, which is consistent with expectations for an atmospherically processed regional aerosol. Analysis of the single particle data reveals that a on a particles in Pittsburgh consist of complex mixture of primary and secondary components. Approximately 79% of all particles measured with the instrument containing some form of carbon, with Carbonaceous Ammonium Nitrate (54.43%) being the dominant particle class. PMCAMx predictions were compared with data from more than 50 sites of the STN network located throughout the Eastern United States for the July 2001 period. OC and sulfate concentrations predicted by PMCAMx are within {+-}30% of the observed concentration at most of these sites. Spherical Aluminum Silicate particle concentrations (SAS) were used to estimate the contribution of primary coal emissions to fine particle levels at the central monitoring site. Primary emissions from coal combustion contribute on average 0.44 {+-} 0.3 {micro}g/m{sup 3} to PM{sub 2.5} at the site or 1.4 {+-} 1.3% of the total PM{sub 2.5} mass. Chemical mass balance analysis was performed to apportion the primary organic aerosol. About 70% of the primary OC emissions are from vehicular sources, with the gasoline contribution being on average three times greater than the diesel emissions in the summer.

  5. Determinants of contract duration: further evidence from coal-fired power plants

    SciTech Connect (OSTI)

    Kozhevnikova, M.; Lange, I.

    2009-05-15

    Transactions cost theory predicts that the availability of alternatives is one of the determinants of contract duration. Over the last 20 years, the coal market has seen many regulatory changes that have generally increased the number of alternatives in the process of procuring coal. In this paper data from long-term coal contracts for electricity generation signed before 1999 are used to estimate the effect of increasing alternatives on contract duration. Empirical results tend to match transactions cost theory that increased alternatives reduces contract duration.

  6. Coal-fired high performance power generating system. Quarterly progress report, October 1--December 31, 1992

    SciTech Connect (OSTI)

    Not Available

    1992-12-31

    Our team has outlined a research plan based on an optimized analysis of a 250 MWe combined cycle system applicable to both frame type and aeroderivative gas turbines. Under the constraints of the cycle analysis we have designed a high temperature advanced furnace (FUTAF) which integrates several combustor and air heater designs with appropriate ash management procedures. The Cycle Optimization effort under Task 2 outlines the evolution of our designs. The basic combined cycle approach now includes exhaust gas recirculation to quench the flue gas before it enters the convective air heater. By selecting the quench gas from a downstream location it will be clean enough and cool enough (ca. 300F) to be driven by a commercially available fan and still minimize the volume of the convective air heater. Further modeling studies on the long axial flame, under Task 3, have demonstrated that this configuration is capable of providing the necessary energy flux to the radiant air panels. This flame with its controlled mixing constrains the combustion to take place in a fuel rich environment, thus minimizing the NO{sub x} production. Recent calculations indicate that the NO{sub x} produced is low enough that the SNCR section can further reduce it to within the DOE goal of 0. 15 lbs/MBTU of fuel input. Also under Task 3 the air heater design optimization continued.

  7. Proof-of-concept tests of the magnetohydrodynamic steam-bottoming system at the DOE Coal-Fired Flow Facility. Final report

    SciTech Connect (OSTI)

    Attig, R.C.

    1996-10-09

    The development of coal-fired magnetohydrodynamic (MHD) power can be viewed as consisting of two parts; the topping cycle and the bottoming cycle. The topping cycle consists of the coal combustor, MHD generator and associated components. The bottoming cycle consists of the heat recovery, steam generation, seed recovery/regeneration, emissions control (gas and particulate), ash handling and deposition, and materials evaluation. The report concentrates on the bottoming cycle, for which much of the technology was developed at the University of Tennessee Space Institute (UTSI). Because of the complexity of the required technology, a number of issues required investigation. Of specific concern regarding the bottoming cycle, was the design of the steam cycle components and emissions control. First, the high combustion temperatures and the use of large quantities of potassium in the MHD combustor results in a difference in the composition of the gases entering the bottoming cycle compared to conventional systems. Secondly, a major goal of the UTSI effort was to use a variety of coals in the MHD system, especially the large reserves of high-sulfur coals available in the United States.

  8. A summary of SNCR applications to two coal-fired wet bottom boilers

    SciTech Connect (OSTI)

    Himes, R.; Hubbard, D.; West, Z.

    1996-01-01

    In response to NO{sub x} reductions mandated under Title I of the 1990 Clean Air Act Amendments (CAAA), Public Service Electric & Gas and Atlantic Electric of New Jersey evaluated Selective Non-Catalytic Reduction (SNCR) for NO{sub x} control under separate programs at Mercer Station and B.L. England Station, respectively. Mercer Station is comprised of twin 321 MW Foster Wheeler coal-fired wet bottom boilers, with natural gas capability up to 100% load. B.L. England Station has three units, two of which are cyclone boilers of 136 MW and 163 MW. These furnace designs are of particular interest in that nominally 23,000 MW of cyclone boiler capacity and 6,900 MW of wall- or turbo-fired wet bottom boiler capacity will be faced with NO{sub x} reductions to be mandated under Title IV - Phase II for Group II boilers. Both stations evaluated Nalco Fuel Tech`s SNCR system using a portable test skid, with urea as the reducing chemical. The Mercer Unit 2 demonstration was performed with a low sulfur coal (nominally 0.8%), while the B.L. England Unit 1 demonstration utilized a medium sulfur coal (nominally 2.4%), and also re-injects fly ash back into the cyclones for ultimate collection and removal as slag. To address concerns over potential Ljungstrom air heater fouling, due to reactions between ammonia and SO{sub 3} in the air heater, and fly ash salability at Mercer Station, both sites targeted no greater than 5-10 ppmv ammonia emissions at the economizer exit. At Mercer Unit 2, air heater fouling was only experienced during system start-up when the ammonia emissions at the economizer exit were estimated at levels approaching 60 ppmv. B.L. England Unit 1, however, experienced frequent fouling of the air heater. NO{sub x} reductions achieved at both sites ranged between 30%-40% from nominal baseline NO{sub x} levels of 1.1-1.6 lb/MMBtu. Each site is currently undergoing installation of commercial SNCR systems.

  9. Characterization of open-cycle coal-fired MHD generators. 16th quarterly technical progress report, December 16, 1980-March 31, 1981

    SciTech Connect (OSTI)

    Wormhoudt, J.; Yousefian, V.; Weinberg, M.; Kolb, C.; Martinez-Sanchez, M.; Cheng, W.; Dvore, D.; Freedman, A.; Stanton, A.; Stewart, G.

    1981-05-01

    The successful design of full-scale, open-cycle, coal-fired MHD generators for baseload electrical production requires a detailed understanding of the plasma chemical and plasma dynamic characteristics of anticipated combustor and channel fluids. Progress in efforts to model the efficiency of an open-cycle, coal-fired MHD channel based on the characterization of the channel flow as well as laboratory experiments to validate the modeling effort is reported. In addition, studies related to understanding arcing and corrosion phenomena in the vicinity of an anode are reported.

  10. Characterization of open-cycle coal-fired MHD generators. 14th/15th quarterly technical progress report, February 1-July 31, 1980

    SciTech Connect (OSTI)

    Wormhoudt, J.; Yousefian, V.; Weinberg, M.; Kolb, C.; Martinez-Sanchez, M.; Cheng, W.; Bien, F.; Dvore, D.; Unkel, W.; Stewart, G.

    1980-09-01

    The successful design of full-scale, open-cycle, coal-fired MHD generators for baseload electrical production requires a detailed understanding of the plasma chemical and plasma dynamic characteristics of anticipated combustor and channel fluids. Progress in efforts to model the efficiency of an open-cycle, coal-fired MHD channel based on the characterization of the channel flow as well as laboratory experiments to validate the modeling effort as detailed. In addition, studies related to understanding arcing phenomena in the vicinity of an anode are reported.

  11. TS Power Plant, Eureka County, Nevada

    SciTech Connect (OSTI)

    Peltier, R.

    2008-10-15

    Not all coal-fired power plants are constructed by investor-owned utilities or independent power producers selling to wholesale markets. When Newmont Mining Corp. recognised that local power supplies were inadequate and too expensive to meet long-term electricity needs for its major gold- and copper-mining operations in northern Nevada, it built its own generation. What is more, Newmont's privately owned 200-MW net coal-fired plant features power plant technologies that will surely become industry standards. Newmont's investment in power and technology is also golden: the capital cost will be paid back in about eight years. 4 figs.

  12. Innovative Clean Coal Technology (ICCT): 500 MW demonstration of advanced wall-fired combustion techniques for the reduction of nitrogen oxide (NO{sub x}) emissions from coal-fired boilers. Phase 2, Overfire air tests

    SciTech Connect (OSTI)

    Smith, L.L.; Hooper, M.P.

    1992-07-13

    This Phase 2 Test Report summarizes the testing activities and results for the second testing phase of an Innovative Clean Coal Technology (ICCT) demonstration of advanced wall-fired combustion techniques for the reduction of nitrogen oxide (NO{sub x}) emissions from coal-fired boilers. The second phase demonstrates the Advanced Overfire Air (AOFA) retrofit with existing Foster Wheeler (FWEC) burners. The project is being conducted at Georgia Power Company`s Plant Hammond Unit 4 located near Rome, Georgia. The primary goal of this project is the characterization of the low NO{sub x} combustion equipment through the collection and analysis of long-term emissions data supported by short-term characterization data. Ultimately a fifty percent NO{sub x} reduction target using combinations of combustion modifications has been established for this project.

  13. Innovative Clean Coal Technology (ICCT): 500 MW demonstration of advanced wall-fired combustion techniques for the reduction of nitrogen oxide (NO[sub x]) emissions from coal-fired boilers

    SciTech Connect (OSTI)

    Smith, L.L.; Hooper, M.P. )

    1992-07-13

    This Phase 2 Test Report summarizes the testing activities and results for the second testing phase of an Innovative Clean Coal Technology (ICCT) demonstration of advanced wall-fired combustion techniques for the reduction of nitrogen oxide (NO[sub x]) emissions from coal-fired boilers. The second phase demonstrates the Advanced Overfire Air (AOFA) retrofit with existing Foster Wheeler (FWEC) burners. The project is being conducted at Georgia Power Company's Plant Hammond Unit 4 located near Rome, Georgia. The primary goal of this project is the characterization of the low NO[sub x] combustion equipment through the collection and analysis of long-term emissions data supported by short-term characterization data. Ultimately a fifty percent NO[sub x] reduction target using combinations of combustion modifications has been established for this project.

  14. Novel polymer membrane process for pre-combustion CO{sub 2} capture from coal-fired syngas

    SciTech Connect (OSTI)

    Merkel, Tim

    2011-09-14

    This final report describes work conducted for the Department of Energy (DOE NETL) on development of a novel polymer membrane process for pre-combustion CO{sub 2} capture from coalfired syngas (award number DE-FE0001124). The work was conducted by Membrane Technology and Research, Inc. (MTR) from September 15, 2009, through December 14, 2011. Tetramer Technologies, LLC (Tetramer) was our subcontract partner on this project. The National Carbon Capture Center (NCCC) at Wilsonville, AL, provided access to syngas gasifier test facilities. The main objective of this project was to develop a cost-effective membrane process that could be used in the relatively near-term to capture CO{sub 2} from shifted syngas generated by a coal-fired Integrated Gasification Combined Cycle (IGCC) power plant. In this project, novel polymeric membranes (designated as Proteus™ membranes) with separation properties superior to conventional polymeric membranes were developed. Hydrogen permeance of up to 800 gpu and H{sub 2}/CO{sub 2} selectivity of >12 was achieved using a simulated syngas mixture at 150°C and 50 psig, which exceeds the original project targets of 200 gpu for hydrogen permeance and 10 for H{sub 2}/CO{sub 2} selectivity. Lab-scale Proteus membrane modules (with a membrane area of 0.13 m{sup 2}) were also developed using scaled-up Proteus membranes and high temperature stable module components identified during this project. A mixed-gas hydrogen permeance of about 160 gpu and H{sub 2}/CO{sub 2} selectivity of >12 was achieved using a simulated syngas mixture at 150°C and 100 psig. We believe that a significant improvement in the membrane and module performance is likely with additional development work. Both Proteus membranes and lab-scale Proteus membrane modules were further evaluated using coal-derived syngas streams at the National Carbon Capture Center (NCCC). The results indicate that all module components, including the Proteus membrane, were stable under the field

  15. MINIMIZATION OF NO EMISSIONS FROM MULTI-BURNER COAL-FIRED BOILERS

    SciTech Connect (OSTI)

    E.G. Eddings; A. Molina; D.W. Pershing; A.F. Sarofim; T.H. Fletcher; H. Zhang; K.A. Davis; M. Denison; H. Shim

    2002-01-01

    The focus of this program is to provide insight into the formation and minimization of NO{sub x} in multi-burner arrays, such as those that would be found in a typical utility boiler. Most detailed studies are performed in single-burner test facilities, and may not capture significant burner-to-burner interactions that could influence NO{sub x} emissions. Thus, investigations of such interactions were made by performing a combination of single and multiple burner experiments in a pilot-scale coal-fired test facility at the University of Utah, and by the use of computational combustion simulations to evaluate full-scale utility boilers. In addition, fundamental studies on nitrogen release from coal were performed to develop greater understanding of the physical processes that control NO formation in pulverized coal flames--particularly under low NO{sub x} conditions. A CO/H{sub 2}/O{sub 2}/N{sub 2} flame was operated under fuel-rich conditions in a flat flame reactor to provide a high temperature, oxygen-free post-flame environment to study secondary reactions of coal volatiles. Effects of temperature, residence time and coal rank on nitrogen evolution and soot formation were examined. Elemental compositions of the char, tar and soot were determined by elemental analysis, gas species distributions were determined using FTIR, and the chemical structure of the tar and soot was analyzed by solid-state {sup 13}C NMR spectroscopy. A laminar flow drop tube furnace was used to study char nitrogen conversion to NO. The experimental evidence and simulation results indicated that some of the nitrogen present in the char is converted to nitric oxide after direct attack of oxygen on the particle, while another portion of the nitrogen, present in more labile functionalities, is released as HCN and further reacts in the bulk gas. The reaction of HCN with NO in the bulk gas has a strong influence on the overall conversion of char-nitrogen to nitric oxide; therefore, any model that

  16. Proceedings of the joint contractors meeting: FE/EE Advanced Turbine Systems conference FE fuel cells and coal-fired heat engines conference

    SciTech Connect (OSTI)

    Geiling, D.W.

    1993-08-01

    The joint contractors meeting: FE/EE Advanced Turbine Systems conference FEE fuel cells and coal-fired heat engines conference; was sponsored by the US Department of Energy Office of Fossil Energy and held at the Morgantown Energy Technology Center, P.O. Box 880, Morgantown, West Virginia 26507-0880, August 3--5, 1993. Individual papers have been entered separately.

  17. [Engineering development of advanced coal-fired low-emission boiler systems]. Technical progress report, October--December 1995

    SciTech Connect (OSTI)

    Wesnor, J.D.; Bakke, E.; Bender, D.J.; Kaminski, R.S.

    1995-12-31

    The overall objective of the Project is the expedited commercialization of advanced coal-fired low-emisssion boiler systems. The primary objectives are: NO{sub x} emissions, lb/million Btu; SO{sub 2} emissions, lb/million Btu; particulate emissions, lb/million Btu; and net plant efficiency, not less than 42%. The secondary objectives are: improved ash disposability; reduced waste generation; and reduced air toxics emissions. Accomplishments to date are summarized for the following tasks: task 1, project planning and management; task 7, component development and optimization; task 8, preliminary POC test facility design; task 9, subsystem test design and plan; task 10, subsystem test unit construction; and task 11, subsystem test operation and evaluation.

  18. Demonstration of advanced tangentially-fired combustion techniques for the reduction of nitrogen oxide emissions from coal-fired boilers

    SciTech Connect (OSTI)

    Hardman, R.R.; Wilson, S.M. ); Smith, L.L.; Larsen, L. )

    1991-01-01

    This paper discusses the progress of a US Department of Energy Innovative Clean Coal Technology Project demonstrating advanced tangentially fired combustion techniques for the reduction of nitrogen oxide (NO{sub x}) emissions from coal-fired boilers. The primary objective of the demonstration is to determine the performance of four low NO{sub x} combustion technologies applied in a stepwise fashion to a 180 MW boiler. A target of achieving fifty percent NO{sub x} reduction has been established for the project. Details of the required instrumentation including acoustic pyrometers and continuous emissions and monitoring systems are given. Results from a 1/12 scale model of the demonstration boiler outfitted with the retrofit technology are presented. Finally, preliminary baseline results are presented. 4 figs.

  19. Feasibility study of burning waste paper in coal-fired boilers on Air Force installations. Master's thesis

    SciTech Connect (OSTI)

    Smith, K.P.

    1993-09-01

    This thesis examined the feasibility of using waste paper derived fuel in coal-fired boilers on Air Force installations in an attempt to help solve air pollution and solid waste disposal problems. The implementation of waste paper derived fuel was examined from both a technical acceptability and an economic feasibility viewpoint. The majority of data for this study was obtained through literature reviews and personal interviews. Waste paper was found to be technically acceptable for use as fuel. However, waste paper has certain characteristics that may create problems during combustion and therefore further research is required. These problems included the possibility of increased nitrous oxide emissions, increased volatile emissions, dioxin and furan emissions, formation of hydrochloric acid, and the presence of heavy metals in emissions and ash.

  20. ADVANCED FLUE GAS CONDITIONING AS A RETROFIT UPGRADE TO ENHANCE PM COLLECTION FROM COAL-FIRED ELECTRIC UTILITY BOILERS

    SciTech Connect (OSTI)

    C. Jean Bustard; Kenneth E. Baldrey; Richard Schlager

    2000-04-01

    The U.S. Department of Energy and ADA Environmental Solutions has begun a project to develop commercial flue gas conditioning additives. The objective is to develop conditioning agents that can help improve particulate control performance of smaller or under-sized electrostatic precipitators on utility coal-fired boilers. The new chemicals will be used to control both the electrical resistivity and the adhesion or cohesivity of the flyash. There is a need to provide cost-effective and safer alternatives to traditional flue gas conditioning with SO{sub 3} and ammonia. Preliminary testing has identified a class of common deliquescent salts that effectively control flyash resistivity on a variety of coals. A method to evaluate cohesive properties of flyash in the laboratory has been selected and construction of an electrostatic tensiometer test fixture is underway. Preliminary selection of a variety of chemicals that will be screened for effect on flyash cohesion has been completed.

  1. Evaluation of Carbon Dioxide Capture From Existing Coal Fired Plants by Hybrid Sorption Using Solid Sorbents

    SciTech Connect (OSTI)

    Benson, Steven; Srinivasachar, Srivats; Laudal, Daniel; Browers, Bruce

    2014-12-31

    A novel hybrid solid sorbent technology for CO₂ capture and separation from coal combustion-derived flue gas was evaluated. The technology – Capture of CO₂ by Hybrid Sorption (CACHYS™) – is a solid sorbent technology based on the following ideas: 1) reduction of energy for sorbent regeneration, 2) utilization of novel process chemistry, 3) contactor conditions that minimize sorbent-CO₂ heat of reaction and promote fast CO₂ capture, and 4) low-cost method of heat management. This report provides key information developed during the course of the project that includes sorbent performance, energy for sorbent regeneration, physical properties of the sorbent, the integration of process components, sizing of equipment, and overall capital and operational cost of the integrated CACHYS™ system. Seven sorbent formulations were prepared and evaluated at the lab-scale for energy requirements and CO₂ capture performance. Sorbent heat of regeneration ranged from 30-80 kJ/mol CO₂ and was found to be dependent on process conditions. Two sorbent formulations (designated HCK-4 & HCK-7) were down-selected for additional fixed-bed testing. Additional testing involved subjecting the sorbents to 100 continuous cycles in the fixed-bed reactor to determine performance as a function of time. The working capacity achieved for HCK-4 sorbent ranged from 5.5-8.0 g CO₂/100 g sorbent, while the HCK-7 typically ranged from 8.0-10.0 g CO₂/100 g sorbent. Overall, there was no deterioration in capacity with continuous cycling for either sorbent. The CACHYS™ bench-scale testing system designed and fabricated under this award consists of a dual circulating fluidized-bed adsorber and a moving-bed regenerator. The system takes a flue gas slipstream from the University of North Dakota’s coal-fired steam plant. Prior to being sent to the adsorber, the flue gas is scrubbed to remove SO₂ and particulate. During parametric testing of the adsorber, CO₂ capture achieved using

  2. Evaluation of BOC'S Lotox Process for the Oxidation of Elemental Mercury in Flue Gas from a Coal-Fired Boiler

    SciTech Connect (OSTI)

    Khalid Omar

    2008-04-30

    Linde's Low Temperature Oxidation (LoTOx{trademark}) process has been demonstrated successfully to remove more than 90% of the NOx emitted from coal-fired boilers. Preliminary findings have shown that the LoTOx{trademark} process can be as effective for mercury emissions control as well. In the LoTOx{trademark} system, ozone is injected into a reaction duct, where NO and NO{sub 2} in the flue gas are selectively oxidized at relatively low temperatures and converted to higher nitrogen oxides, which are highly water soluble. Elemental mercury in the flue gas also reacts with ozone to form oxidized mercury, which unlike elemental mercury is water-soluble. Nitrogen oxides and oxidized mercury in the reaction duct and residual ozone, if any, are effectively removed in a wet scrubber. Thus, LoTOx{trademark} appears to be a viable technology for multi-pollutant emission control. To prove the feasibility of mercury oxidation with ozone in support of marketing LoTOx{trademark} for multi-pollutant emission control, Linde has performed a series of bench-scale tests with simulated flue gas streams. However, in order to enable Linde to evaluate the performance of the process with a flue gas stream that is more representative of a coal-fired boiler; one of Linde's bench-scale LoTOx{trademark} units was installed at WRI's combustion test facility (CTF), where a slipstream of flue gas from the CTF was treated. The degree of mercury and NOx oxidation taking place in the LoTOx{trademark} unit was quantified as a function of ozone injection rates, reactor temperatures, residence time, and ranks of coals. The overall conclusions from these tests are: (1) over 80% reduction in elemental mercury and over 90% reduction of NOx can be achieved with an O{sub 3}/NO{sub X} molar ratio of less than two, (2) in most of the cases, a lower reactor temperature is preferred over a higher temperature due to ozone dissociation, however, the combination of both low residence time and high temperature

  3. Compliance testing of Grissom AFB Central Heating Plant coal-fired boilers 3 and 5, Grissom AFB, Indiana. Final report, 4-14 March 1988

    SciTech Connect (OSTI)

    Garrison, J.A.

    1988-06-01

    At the request of HQ SAC/SGPB, compliance testing (particulate emissions) of coal-fired boilers 3 and 5 in the Grissom AFB Central Heating Plant was performed on 4-14 Mar 1988. The survey was conducted to determine compliance with Indiana Administrative Code, Title 325--Air Pollution Control Board, Articles 5 and 6. Results indicate that boilers 3 and 5 to met particulate standards while exhausting through the bypass stack.

  4. The commercialization of magnetohydrodynamic electric power plants

    SciTech Connect (OSTI)

    Weinstein, R.E.

    1993-12-31

    The successful development of Magnetohydrodynamics (MHD) will provide an ultra clean, highly efficient alternative to other methods of coal-fired electric Power generation. A development path that could bring coal-fired MHD electric power plants to competitive commercial status is described in this paper. The paper discusses the scale-ups, the timing, and technical hurdles that face this technology as it progresses from its present status of small-scale demonstrations and begins its competition for electric utility acceptance. Coal-fired MHD power has at least four major markets: (1) New utility generation. (2) Utility retrofit/repowering applications. (3) New independent power production (IPP). (4) Large industrial cogeneration application. Of these, the largest market for MHD is expected to be the new electric utility/IPP generation market, those new units required to supply growth in power demand and to replace retired capacity. This market sector is the focus of this discussion. This paper describes the commercial pressures and inertias that motivate the entry of any new technology into the generation supply market. It then shows a development path that could bring coal-fired MHD electric power plants to competitive commercial status in the electric power industry.

  5. Projections of air toxic emissions from coal-fired utility combustion: Input for hazardous air pollutant regulators

    SciTech Connect (OSTI)

    Szpunar, C.B.

    1993-08-01

    The US Environmental Protection Agency (EPA) is required by the 1990 CAAA to promulgate rules for all ``major`` sources of any of these HAPs. According to the HAPs section of the new Title III, any stationary source emitting 10 tons per year (TPY) of one HAP or 25 TPY of a combination of HAPs will be considered and designated a major source. In contrast to the original National Emission Standards for Hazardous Air Pollutants (NESHAP), which were designed to protect public health to ``an ample margin of safety,`` the new Title III, in its first phase, will regulate by industrial category those sources emitting HAPs in excess of the 10/25-TPY threshold levels, regardless of health risks. The trace elements normally associated with coal mineral matter and the various compounds formed during coal combustion have the potential to produce hazardous air toxic emissions from coal-fired electric utilities. Under Title III, the EPA is required to perform certain studies, prior to any regulation of electric utilities; these studies are currently underway. Also, the US Department of Energy (DOE) maintains a vested interest in addressing those energy policy questions affecting electric utility generation, coal mining, and steel producing critical to this country`s economic well-being, where balancing the costs to the producers and users of energy with the benefits of environmental protection to the workers and the general populace remains of significant concern.

  6. Integrating low-NO{sub x} burners, overfire air, and selective non-catalytic reduction on a utility coal-fired boiler

    SciTech Connect (OSTI)

    Hunt, T.; Muzio, L.; Smith, R.

    1995-05-01

    Public Service Company of Colorado (PSCo), in cooperation with the US Department of Energy (DOE) and the Electric Power Research Institute (EPRI), is testing the Integrated Dry NO{sub x}/SO{sub 2} Emissions Control system. This system combines low-NO{sub x} burners, overfire air, selective non-catalytic reduction (SNCR), and dry sorbent injection with humidification to reduce by up to 70% both NO{sub x} and SO{sub 2} emissions from a 100 MW coal-fired utility boiler. The project is being conducted at PSCo`s Arapahoe Unit 4 located in Denver, Colorado as part of the DOE`s Clean Coal Technology Round 3 program. The urea-based SNCR system, supplied by Noell, Inc., was installed in late 1991 and was tested with the unmodified boiler in 1992. At full load, it reduced NO{sub x} emissions by about 35% with an associated ammonia slip limit of 10 ppm. Babcock & Wilcox XLS{reg_sign} burners and a dual-zone overfire air system were retrofit to the top-fired boiler in mid-1992 and demonstrated a NO{sub x} reduction of nearly 70% across the load range. Integrated testing of the combustion modifications and the SNCR system were conducted in 1993 and showed that the SNCR system could reduce NO{sub x} emissions by an additional 45% while maintaining 10 ppm of ammonia slip limit at full load. Lower than expect4ed flue-gas temperatures caused low-load operation to be less effective than at high loads. NO{sub x} reduction decreased to as low as 11% at 60 MWe at an ammonia slip limit of 10 ppm. An ammonia conversion system was installed to improve performance at low loads. Other improvements to increase NO{sub x} removal at low-loads are planned. The combined system of combustion modifications and SNCR reduced NO{sub x} emissions by over 80% from the original full-load baseline. 11 figs.

  7. Materials performance in coal-fired fluidized-bed combustion environments

    SciTech Connect (OSTI)

    Natesan, K.

    1993-07-01

    Development of cogeneration systems that involve combustion of coal in a fluidized bed for the generation of electricity and process heat has been in progress for a number of years. This paper addresses some of the key components in these systems, materials requirements/performance, and areas where additional effort is needed to improve the viability of these concepts for electric power generation.

  8. Characterization of air toxics from a laboratory coal-fired combustor

    SciTech Connect (OSTI)

    1995-04-03

    Emissions of hazardous air pollutants from coal combustion were studied in a laboratory-scale combustion facility, with emphasis on fine particles in three size ranges of less than 7.5 {mu}m diameter. Vapors were also measured. Substances under study included organic compounds, anions, elements, and radionuclides. Fly ash was generated by firing a bituminous coal in a combuster for 40 h at each of two coal feed rates. Flue gas was sampled under two conditions. Results for organic compounds, anions, and elements show a dependence on particle size consistent with published power plant data. Accumulation of material onto surface layers was inferred from differences in chemical composition between the plume simulating dilution sampler and hot flue samples. Extracts of organic particulate material were fractionated into different polarity fractions and analyzed by GC/MS. In Phase II, these laboratory results will be compared to emissions from a full-scale power plant burning the same coal.

  9. Initial operating results of coal-fired steam generators converted to 100% refuse-derived fuel

    SciTech Connect (OSTI)

    Barsin, J.A. ); Graika, P.K. ); Gonyeau, J.A. ); Bloomer, T.M. )

    1988-01-01

    The conversion of Northern States Power Company's (NSP) Red Wing and Wilmarth steam generators to fire refuse-derived fuel (RDF) is discussed. The use of the existing plant with the necessary modifications to the boilers has allowed NSP to effectively incinerate the fuel as required by Washington and Ramsey Counties. This paper covers the six-month start-up of Red Wing No. 1, commencing in May 1987, and the operating results since the plant went commercial in July 1987.

  10. Characterization and analysis of metal wastage in coal-fired fluidized-bed combustors. Statistical analysis plan

    SciTech Connect (OSTI)

    Nazemi, A.H.; Smith, E.P.

    1985-11-01

    Metal loss from in-bed heat exchangers has been a persistent problem in FBC systems. As part of its program in FBC technology development, the US Department of Energy/Morgantown Energy Technology Center (DOE/METC) supports a number of projects directed toward providing both theoretical and experimental results which will guide solutions to the metal loss problem. As a part of this effort, METC and The MITRE Corporation began a project in 1984 to collect and analyze metal loss data from various experimental, pilot-scale, and full-scale coal-fired FBC systems worldwide. The specific objective of this effort is to investigate the effects of unit design parameters and operating conditions on metal loss through the use of regression and analysis of variance techniques. To date, forty-one FBC systems worldwide have been identified and most of the data sets which characterize the metal loss occurrences in those units have been developed. The results of MITRE's effort to date were reported earlier (Interim Report No. DOE/MC/21351-1930, August 1985). This report describes the statistical procedures that MITRE will follow to analyze FBC metal loss data. The data will be analyzed using several regression techniques to find variables related to metal loss. Correlation and single variable regressions will be used to indicate important relationships. The joint relationships between the explanatory variables and metal loss will be examined by building multiple regression models. In order to prevent erroneous conclusions, diagnostics will be performed based on partial residual plots, residual analysis, and multicollinearity statistics. 7 refs.

  11. Fossil-fuel power plants and power generation: Economic analysis. (Latest citations from the NTIS data base). Published Search

    SciTech Connect (OSTI)

    Not Available

    1992-06-01

    The bibliography contains citations concerning economic analyses and evaluations of utility and industrial fossil-fuel power generation. Coal-fired, oil-fired, and natural gas-fired electric power generating systems are discussed. Specific technologies, experiences, and locations are also considered. (Contains 250 citations and includes a subject term index and title list.)

  12. Fossil-fuel power plants and power generation: Economic analysis. (Latest citations from the NTIS bibliographic database). Published Search

    SciTech Connect (OSTI)

    1995-10-01

    The bibliography contains citations concerning economic analyses and evaluations of utility and industrial fossil-fuel power generation. Coal-fired, oil-fired, and natural gas-fired electric power generating systems are discussed. Specific technologies, experiences, and locations are also considered. (Contains 50-250 citations and includes a subject term index and title list.) (Copyright NERAC, Inc. 1995)

  13. Fossil-fuel power plants and power generation: Economic analysis. (Latest citations from the NTIS Bibliographic database). Published Search

    SciTech Connect (OSTI)

    Not Available

    1993-12-01

    The bibliography contains citations concerning economic analyses and evaluations of utility and industrial fossil-fuel power generation. Coal-fired, oil-fired, and natural gas-fired electric power generating systems are discussed. Specific technologies, experiences, and locations are also considered. (Contains 250 citations and includes a subject term index and title list.)

  14. Fossil-fuel power plants and power generation: Economic analysis. (Latest citations from the NTIS bibliographic database). Published Search

    SciTech Connect (OSTI)

    Not Available

    1994-12-01

    The bibliography contains citations concerning economic analyses and evaluations of utility and industrial fossil-fuel power generation. Coal-fired, oil-fired, and natural gas-fired electric power generating systems are discussed. Specific technologies, experiences, and locations are also considered. (Contains 250 citations and includes a subject term index and title list.)

  15. Fossil-fuel power plants and power generation: Economic analysis. (Latest citations from the NTIS Bibliographic database). Published Search

    SciTech Connect (OSTI)

    1993-09-01

    The bibliography contains citations concerning economic analyses and evaluations of utility and industrial fossil-fuel power generation. Coal-fired, oil-fired, and natural gas-fired electric power generating systems are discussed. Specific technologies, experiences, and locations are also considered. (Contains 250 citations and includes a subject term index and title list.)

  16. Fossil-fuel power plants and power generation: Economic analysis. (Latest citations from the NTIS bibliographic database). Published Search

    SciTech Connect (OSTI)

    1997-02-01

    The bibliography contains citations concerning economic analyses and evaluations of utility and industrial fossil-fuel power generation. Coal-fired, oil-fired, and natural gas-fired electric power generating systems are discussed. Specific technologies, experiences, and locations are also considered. (Contains 50-250 citations and includes a subject term index and title list.) (Copyright NERAC, Inc. 1995)

  17. Innovative Clean Coal Technology (ICCT): 500 MW demonstration of advanced wall-fired combustion techniques for the reduction of nitrogen oxide (NO{sub x}) emissions from coal-fired boilers. Technical progress report, third quarter 1991

    SciTech Connect (OSTI)

    Not Available

    1992-02-03

    This quarterly report discusses the technical progress of an Innovative Clean Coal Technology (ICCT) demonstration of advanced wall-fired combustion techniques for the reduction of nitrogen oxide (NO{sub x}) emissions from coal-fired boilers. The project is being conducted at Georgia Power Company`s Plant Hammond Unit 4 located near Rome, Georgia. The primary goal of this project is the characterization of the low NO{sub x} combustion equipment through the collection and analysis of long-term emissions data. A target of achieving fifty percent NO{sub x} reduction using combustion modifications has been established for the project. The project provides a stepwise retrofit of an Advanced Overfire Air (AOFA) system followed by Low NO{sub x} Burners (LNB). During each test phase of the project, diagnostic, performance, long-term, and verification testing will be performed. These tests are used to quantify the NO{sub x} reductions of each technology and evaluate the effects of those reductions on other combustion parameters such as particulate characteristics and boiler efficiency.

  18. Innovative Clean Coal Technology (ICCT): 500 MW demonstration of advanced wall-fired combustion techniques for the reduction of nitrogen oxide (NO sub x ) emissions from coal-fired boilers

    SciTech Connect (OSTI)

    Not Available

    1992-02-03

    This quarterly report discusses the technical progress of an Innovative Clean Coal Technology (ICCT) demonstration of advanced wall-fired combustion techniques for the reduction of nitrogen oxide (NO{sub x}) emissions from coal-fired boilers. The project is being conducted at Georgia Power Company's Plant Hammond Unit 4 located near Rome, Georgia. The primary goal of this project is the characterization of the low NO{sub x} combustion equipment through the collection and analysis of long-term emissions data. A target of achieving fifty percent NO{sub x} reduction using combustion modifications has been established for the project. The project provides a stepwise retrofit of an Advanced Overfire Air (AOFA) system followed by Low NO{sub x} Burners (LNB). During each test phase of the project, diagnostic, performance, long-term, and verification testing will be performed. These tests are used to quantify the NO{sub x} reductions of each technology and evaluate the effects of those reductions on other combustion parameters such as particulate characteristics and boiler efficiency.

  19. Coal-fired boiler houses in Cracow present state and possibilities to improve their efficiency

    SciTech Connect (OSTI)

    Cyklis, P.; Butcher, T.A.

    1995-12-31

    A significant amount of heat energy both for heating and process purposes is generated in Cracow, Poland in small-and medium size local boiler houses. The operating procedure of these boiler houses is most often economically and ecologically ineffective because of the bad condition of boilers and lack of funds to install automation, control and measurement equipment. Within the Polish-American Program of Elimination of Low Emission Sources financed by the US Department of Energy, the ENERGOEKSPERT Co., Ltd. investigated chosen boiler houses in Cracow, commissioned by the Cracow Development Office. The results of these investigations were subject of engineering analysis carried out at the Institute of Industrial Equipment and Power Engineering, Technical University, Cracow. The analysis proved that the low-cost improvement of economic efficiency and reduction of air pollutant emission is feasible for combustion of coal fuels.

  20. Capacity mapping for optimum utilization of pulverizers for coal fired boilers - article no. 032201

    SciTech Connect (OSTI)

    Bhattacharya, C.

    2008-09-15

    Capacity mapping is a process of comparison of standard inputs with actual fired inputs to assess the available standard output capacity of a pulverizer. The base capacity is a function of grindability; fineness requirement may vary depending on the volatile matter (VM) content of the coal and the input coal size. The quantity and the inlet will change depending on the quality of raw coal and output requirement. It should be sufficient to dry pulverized coal (PC). Drying capacity is also limited by utmost PA fan power to supply air. The PA temperature is limited by air preheater (APH) inlet flue gas temperature; an increase in this will result in efficiency loss of the boiler. The higher PA inlet temperature can be attained through the economizer gas bypass, the steam coiled APH, and the partial flue gas recirculation. The PS/coal ratioincreases with a decrease in grindability or pulverizer output and decreases with a decrease in VM. The flammability of mixture has to be monitored on explosion limit. Through calibration, the PA flow and efficiency of conveyance can be verified. The velocities of coal/air mixture to prevent fallout or to avoid erosion in the coal carrier pipe are dependent on the PC particle size distribution. Metal loss of grinding elements inversely depends on the YGP index of coal. Variations of dynamic loading and wearing of grinding elements affect the available milling capacity and percentage rejects. Therefore, capacity mapping in necessary to ensure the available pulverizer capacity to avoid overcapacity or undercapacity running of the pulverizing system, optimizing auxiliary power consumption. This will provide a guideline on the distribution of raw coal feeding in different pulverizers of a boiler to maximize system efficiency and control, resulting in a more cost effective heat rate.

  1. Compliance testing of Grissom AFB central-heating-plant coal-fired boilers 3 and 4, Grissom AFB Indiana. Final report, 18-23 November 1987

    SciTech Connect (OSTI)

    Garrison, J.A.

    1988-03-01

    At the request of HQ SAC/SGPB, compliance testing (particulate emissions) of coal-fired boilers 3 and 4 in the Grissom AFB central heating plant was performed on 18-23 Nov 1987. The survey was conducted to determine compliance with Indiana Administrative Code, Title 325--Air Pollution Control Board, Articles 5 and 6. Results indicate Boiler 3 met particulate standards while exhausting through the bypass stack, but failed to meet standards when exhausting through the scrubber stack. Boiler 4 met particulate standards when exhausting through both the bypass the scrubber stacks.

  2. Levelized Power Generation Cost Codes

    Energy Science and Technology Software Center (OSTI)

    1996-04-30

    LPGC is a set of nine microcomputer programs for estimating power generation costs for large steam-electric power plants. These programs permit rapid evaluation using various sets of economic and technical ground rules. The levelized power generation costs calculated may be used to compare the relative economics of nuclear and coal-fired plants based on life-cycle costs. Cost calculations include capital investment cost, operation and maintenance cost, fuel cycle cost, decommissioning cost, and total levelized power generationmore » cost. These programs can be used for quick analyses of power generation costs using alternative economic parameters, such as interest rate, escalation rate, inflation rate, plant lead times, capacity factor, fuel prices, etc. The two major types of electric generating plants considered are pressurized water reactor (PWR) and pulverized coal-fired plants. Data are also provided for the Large Scale Prototype Breeder (LSPB) type liquid metal reactor.« less

  3. Computer Aided Design of Advanced Turbine Airfoil Alloys for Industrial Gas Turbines in Coal Fired Environments

    SciTech Connect (OSTI)

    G.E. Fuchs

    2007-12-31

    Recent initiatives for fuel flexibility, increased efficiency and decreased emissions in power generating industrial gas turbines (IGT's), have highlighted the need for the development of techniques to produce large single crystal or columnar grained, directionally solidified Ni-base superalloy turbine blades and vanes. In order to address the technical difficulties of producing large single crystal components, a program has been initiated to, using computational materials science, better understand how alloy composition in potential IGT alloys and solidification conditions during processing, effect castability, defect formation and environmental resistance. This program will help to identify potential routes for the development of high strength, corrosion resistant airfoil/vane alloys, which would be a benefit to all IGT's, including small IGT's and even aerospace gas turbines. During the first year, collaboration with Siemens Power Corporation (SPC), Rolls-Royce, Howmet and Solar Turbines has identified and evaluated about 50 alloy compositions that are of interest for this potential application. In addition, alloy modifications to an existing alloy (CMSX-4) were also evaluated. Collaborating with SPC and using computational software at SPC to evaluate about 50 alloy compositions identified 5 candidate alloys for experimental evaluation. The results obtained from the experimentally determined phase transformation temperatures did not compare well to the calculated values in many cases. The effects of small additions of boundary strengtheners (i.e., C, B and N) to CMSX-4 were also examined. The calculated phase transformation temperatures were somewhat closer to the experimentally determined values than for the 5 candidate alloys, discussed above. The calculated partitioning coefficients were similar for all of the CMSX-4 alloys, similar to the experimentally determined segregation behavior. In general, it appears that computational materials science has become a

  4. Healy Clean Coal Project: Healy coal firing at TRW Cleveland Test Facility. Final report

    SciTech Connect (OSTI)

    Koyama, T.; Petrill, E.; Sheppard, D.

    1991-08-01

    A test burn of two Alaskan coals was conducted at TRW`s Cleveland test facility in support of the Healy Clean Coal Project, as part of Clean Coal Technology III Program in which a new power plant will be constructed using a TRW Coal Combustion System. This system features ash slagging technology combined with NO{sub x} and SO{sub x} control. The tests, funded by the Alaska Industrial Development and Export Authority (AIDEA) and TRW, were conducted to verify that the candidate Healy station coals could be successfully fired in the TRW coal combustor, to provide data required for scale-up to the utility project size requirements, and to produce sufficient flash-calcined material (FCM) for spray dryer tests to be conducted by Joy/NIRO. The tests demonstrated that both coals are viable candidates for the project, provided the data required for scale-up, and produced the FCM material. This report describes the modifications to the test facility which were required for the test burn, the tests run, and the results of the tests.

  5. Healy Clean Coal Project: Healy coal firing at TRW Cleveland Test Facility

    SciTech Connect (OSTI)

    Koyama, T.; Petrill, E.; Sheppard, D.

    1991-08-01

    A test burn of two Alaskan coals was conducted at TRW's Cleveland test facility in support of the Healy Clean Coal Project, as part of Clean Coal Technology III Program in which a new power plant will be constructed using a TRW Coal Combustion System. This system features ash slagging technology combined with NO{sub x} and SO{sub x} control. The tests, funded by the Alaska Industrial Development and Export Authority (AIDEA) and TRW, were conducted to verify that the candidate Healy station coals could be successfully fired in the TRW coal combustor, to provide data required for scale-up to the utility project size requirements, and to produce sufficient flash-calcined material (FCM) for spray dryer tests to be conducted by Joy/NIRO. The tests demonstrated that both coals are viable candidates for the project, provided the data required for scale-up, and produced the FCM material. This report describes the modifications to the test facility which were required for the test burn, the tests run, and the results of the tests.

  6. NO{sub x} CONTROL OPTIONS AND INTEGRATION FOR US COAL FIRED BOILERS

    SciTech Connect (OSTI)

    Mike Bockelie; Temi Linjewile; Connie Senior; Eric Eddings; Larry Baxter

    2003-04-29

    This is the eleventh Quarterly Technical Report for DOE Cooperative Agreement No: DE-FC26-00NT40753. The goal of the project is to develop cost effective analysis tools and techniques for demonstrating and evaluating low NO{sub x} control strategies and their possible impact on boiler performance for boilers firing US coals. The Electric Power Research Institute (EPRI) is providing co-funding for this program. This program contains multiple tasks and good progress is being made on all fronts. During this quarter, FTIR experiments for SCR catalyst sulfation were finished at BYU and indicated no vanadium/vanadyl sulfate formation at reactor conditions. Poisoned catalysts were prepared and tested in the CCS. Poisoning with sodium produced a noticeable drop in activity, which was larger at higher space velocity. A computer code was written at BYU to predict conversion along a cylindrical monolithic reactor. This code may be useful for monolith samples that will be tested in the laboratory. Shakedown of the slipstream reactor was completed at AEP's Rockport plant. Ammonia was connected to the reactor. The measurement of O{sub 2} and NO{sub x} made by the CEMs corresponded to values measured by the plant at the economizer outlet. Excellent NO{sub x} reduction was observed in preliminary tests of the reactor. Some operational problems were noted and these will be addressed next quarter.

  7. PowerPoint Presentation

    Office of Energy Efficiency and Renewable Energy (EERE) (indexed site)

    * Renewable energy portfolios * Land near existing transmission * Land near Central Arizona Project Pumps * Movement toward unified Western Grid Dispatch * Ability to partner with Federal Agencies * Combination with community development Coal Fired Power Plants in Arizona, New Mexico, Colorado, Utah, Nevada, and Navajo Nation: Apache Craig* Desert Basin Hayden Cholla* Drake Coronado Nucla* Sundt* Pawnee Navajo* Rawhide Springerville Nixon Four Corners* Trigen (steam plant) Plains Escalante

  8. Laboratory-scale evaluation of various sampling and analytical methods for determining mercury emissions from coal-fired power plants

    SciTech Connect (OSTI)

    Agbede, R.O.; Bochan, A.J.; Clements, J.L.

    1995-11-01

    Comparative bench-scale mercury sampling method tests were performed at the Advanced Technology Systems, Inc. (ATS) laboratories for EPA Method 101A, EPA Method 29 and the Ontario Hydro Method. Both blank and impinger spiking experiments were performed. The experimental results show that the ambient level of mercury in the ATS laboratory is at or below the detection limit (10 ng Hg) as measured by a cold vapor atomic absorption spectrophotometer (CVAAS) which was used to analyze the mercury samples. From the mercury spike studies, the following observations and findings were made. (a) The recovery of mercury spikes using EPA Method 101A was 104%. (b) The Ontario Hydro Method retains about 90% of mercury spikes in the first absorbing solution but has a total spike retention of 106%. As a result, the test data shows possible migration of spiked mercury from the first impinger solution (KCI) to the permanganate impingers. (c) For the EPA Method 29 solutions, when only the peroxide impingers were spiked, mercury recoveries were 65.6% for the peroxide impingers, 0.1% for the knockout impinger and 32.8% for the permanganate impingers with an average total mercury recovery of 98.4%. At press time, data was still being obtained for both the peroxide and permanganate impinger solution spikes. This and other data will be available at the presentation.

  9. Application of Pulse Spark Discharges for Scale Prevention and Continuous Filtration Methods in Coal-Fired Power Plant

    SciTech Connect (OSTI)

    Cho, Young; Fridman, Alexander

    2012-06-30

    The overall objective of the present work was to develop a new scale-prevention technology by continuously precipitating and removing dissolved mineral ions (such as calcium and magnesium) in cooling water while the COC could be doubled from the present standard value of 3.5. The hypothesis of the present study was that if we could successfully precipitate and remove the excess calcium ions in cooling water, we could prevent condenser-tube fouling and at the same time double the COC. The approach in the study was to utilize pulse spark discharges directly in water to precipitate dissolved mineral ions in recirculating cooling water into relatively large suspended particles, which could be removed by a self-cleaning filter. The present study began with a basic scientific research to better understand the mechanism of pulse spark discharges in water and conducted a series of validation experiments using hard water in a laboratory cooling tower. Task 1 of the present work was to demonstrate if the spark discharge could precipitate the mineral ions in water. Task 2 was to demonstrate if the selfcleaning filter could continuously remove these precipitated calcium particles such that the blowdown could be eliminated or significantly reduced. Task 3 was to demonstrate if the scale could be prevented or minimized at condenser tubes with a COC of 8 or (almost) zero blowdown. In Task 1, we successfully completed the validation study that confirmed the precipitation of dissolved calcium ions in cooling water with the supporting data of calcium hardness over time as measured by a calcium ion probe. In Task 2, we confirmed through experimental tests that the self-cleaning filter could continuously remove precipitated calcium particles in a simulated laboratory cooling tower such that the blowdown could be eliminated or significantly reduced. In addition, chemical water analysis data were obtained which were used to confirm the COC calculation. In Task 3, we conducted a series of heat transfer fouling tests using a condenser heat exchanger in the laboratory cooling tower, from which we confirmed that the plasma water treatment technology could prevent or significantly mitigate mineral foulings in condenser tubes when compared with the no-treatment case. With the completion of the present work, a cooling water treatment technology using pulse spark discharges is currently ready for field-validation tests. The plasma water treatment technology is a true mechanical water softener with almost no maintenance, which continuously converts hard water to soft water spending a relatively small amount of energy. Such a mechanical water softener could find wide-spread applications to solve hard water problems both in industry and at home.

  10. Demonstration of selective catalytic reduction (SCR) technology for the control of nitrogen oxide (NO[sub x]) emissions from high-sulfur coal-fired boilers

    SciTech Connect (OSTI)

    Not Available

    1992-08-01

    The objective of this project is to demonstrate and evaluate commercially available Selective Catalytic Reduction (SCR) catalysts from US, Japanese and European catalyst suppliers on a high-sulfur US coal-fired boiler. SCR is a post-combustion nitrogen oxide (NO[sub x]) control technology that involves injecting ammonia into the flue gas generated from coal combustion in an electric utility boiler. The flue gas containing ammonia is then passed through a reactor that contains a specialized catalyst. In the presence of the catalyst, the ammonia reacts with NO[sub x] to convert it to nitrogen and water vapor. Although SCR is widely practiced in Japan and Europe, there are numerous technical uncertainties associated with applying SCR to US coals. These uncertainties include: (1) potential catalyst deactivation due to poisoning by trace metal species present in US coals that are not present in other fuels. (2) performance of the technology and effects on the balance-of-plant equipment in the presence of high amounts of SO[sub 2] and SO[sub 3]. (3) performance of a wide variety of SCR catalyst compositions, geometries and methods of manufacture under typical high-sulfur coal-fired utility operating conditions. These uncertainties will be explored by constructing a series of small-scale SCR reactors and simultaneously exposing different SCR catalysts to flue gas derived from the combustion of high sulfur U. S. coal.

  11. Micronized coal-fired retrofit system for SO{sub x} reduction Krakow clean fossil fuels and energy efficiency program. Final report

    SciTech Connect (OSTI)

    1997-04-01

    This report describes results of a technical, financial and environmental assessment study for a project, which would have included a new TCS micronized coal-fired heating plant for the Produkcja I Hodowla Roslin Ogrodniczych (PHRO) Greenhouse Complex; Krzeszowice, Poland. Project site is about 20 miles west of Krakow, Poland. During the project study period, PHRO utilized 14 heavy oil-fired boilers to produce heat for its greenhouse facilities and also home heating to several adjacent apartment housing complexes. The boilers burn a high-sulfur content heavy crude oil, called mazute, The project study was conducted during a period extended from March 1996 through February 1997. For size orientation, the PHRO Greenhouse complex grows a variety of vegetables and flowers for the Southern Poland marketplace. The greenhouse area under glass is very large and equivalent to approximately 50 football fields, The new micronized coal fired boiler would have: (1) provided a significant portion of the heat for PHRO and a portion of the adjacent apartment housing complexes, (2) dramatically reduced sulfur dioxide air pollution emissions, while satisfying new Polish air regulations, and (3) provided attractive savings to PHRO, based on the quantity of displaced oil.

  12. Field Test Program for Long-Term Operation of a COHPAC System for Removing Mercury from Coal-Fired Flue Gas

    SciTech Connect (OSTI)

    C. Jean Bustard; Charles Lindsey; Paul Brignac

    2006-05-01

    This document provides a summary of the full-scale demonstration efforts involved in the project ''Field Test Program for Long-Term Operation of a COHPAC{reg_sign} System for Removing Mercury from Coal-Fired Flue Gas''. The project took place at Alabama Power's Plant Gaston Unit 3 and involved the injection of sorbent between an existing particulate collector (hot-side electrostatic precipitators) and a COHPAC{reg_sign} fabric filter (baghouse) downstream. Although the COHPAC{reg_sign} baghouse was designed originally for polishing the flue gas, when activated carbon injection was added, the test was actually evaluating the EPRI TOXECON{reg_sign} configuration. The results from the baseline tests with no carbon injection showed that the cleaning frequency in the COHPAC{reg_sign} unit was much higher than expected, and was above the target maximum cleaning frequency of 1.5 pulses/bag/hour (p/b/h), which was used during the Phase I test in 2001. There were times when the baghouse was cleaning continuously at 4.4 p/b/h. In the 2001 tests, there was virtually no mercury removal at baseline conditions. In this second round of tests, mercury removal varied between 0 and 90%, and was dependent on inlet mass loading. There was a much higher amount of ash exiting the electrostatic precipitators (ESP), creating an inlet loading greater than the design conditions for the COHPAC{reg_sign} baghouse. Tests were performed to try to determine the cause of the high ash loading. The LOI of the ash in the 2001 baseline tests was 11%, while the second baseline tests showed an LOI of 17.4%. The LOI is an indication of the carbon content in the ash, which can affect the native mercury uptake, and can also adversely affect the performance of ESPs, allowing more ash particles to escape the unit. To overcome this, an injection scheme was implemented that balanced the need to decrease carbon injection during times when inlet loading to the baghouse was high and increase carbon injection

  13. Health-hazard evaluation report HETA 84-066-1883, Artesian Industries, Mansfield, Ohio

    SciTech Connect (OSTI)

    Crandall, M.S.; Singal, M.; Anastas, M.Y.

    1988-03-01

    In response to a request from workers at Artesian Industries, Mansfield, Ohio, an investigation was made of possible hazardous working conditions. Workers were experiencing lightheadedness, shortness of breath, fainting, lung problems, and skin rashes. For 86 air samples taken, respirable crystalline silica personal exposures averaged 0.12 mg/cu m (NIOSH Recommended Exposure Limit (REL) for respirable crystalline silica, 0.05 mg/cu m); 38 of the samples exceeded the REL. All samples from the slip houses exceeded the NIOSH REL. The 18 samples taken in the casting area indicated that the average exposure limit was 0.06 mg/cu m, with eight samples exceeding the NIOSH REL. In the dry-finishing area 18 samples showed an average respirable silica concentration of 0.11 mg/cu m. Exposure to talc averaged 2.7 mg/cu m in the casting areas for 38 samples. Symptoms of chronic cough were noted in 20%, chronic bronchitis in 5%, and shortness of breath in 31% of the workers. Of 196 chest x-rays examined, 18 exhibited evidence of asbestos or talc exposure; five had symptoms of silicosis. The authors conclude that there is a serious, extensive problem regarding exposures to respirable silica and respirable talc dust.

  14. 500 MW demonstration of advanced wall-fired combustion techniques for the reduction of nitrogen oxide emissions from coal-fired boilers

    SciTech Connect (OSTI)

    Sorge, J.N.; Larrimore, C.L.; Slatsky, M.D.; Menzies, W.R.; Smouse, S.M.; Stallings, J.W.

    1997-12-31

    This paper discusses the technical progress of a US Department of Energy Innovative Clean Coal Technology project demonstrating advanced wall-fired combustion techniques for the reduction of nitrogen oxide (NOx) emissions from coal-fired boilers. The primary objectives of the demonstration is to determine the long-term NOx reduction performance of advanced overfire air (AOFA), low NOx burners (LNB), and advanced digital control optimization methodologies applied in a stepwise fashion to a 500 MW boiler. The focus of this paper is to report (1) on the installation of three on-line carbon-in-ash monitors and (2) the design and results to date from the advanced digital control/optimization phase of the project.

  15. Development and testing of an industrial scale coal fired slagging combustion system, Phase 3. Task 2.1, Preliminary systems test plan

    SciTech Connect (OSTI)

    Not Available

    1992-09-11

    The planned effort for the task 2 tests has four major objectives. They are computer controlled combustor operation, optimization of SO2 reduction, combustor materials durability, and testing focused on application to industrial coal fired boilers. Several major advances in the combustor development have occurred since this original plan was proposed in 1991. Some of these advances occurred in tests performed in a project that was completed in June 1992, while others occurred during the design and shakedown tests of equipment that was installed in task I of this project. Therefore, the present test plan is based on the current status of the combustor technology, and it differs somewhat from the preliminary test plan that was prepared in April 1992. Depending on the results in the early tests in this task, further test plan modifications may be required. However, the general objectives will most probably remain unchanged.

  16. Innovative clean coal technology: 500 MW demonstration of advanced wall-fired combustion techniques for the reduction of nitrogen oxide (NOx) emissions from coal-fired boilers. Final report, Phases 1 - 3B

    SciTech Connect (OSTI)

    1998-01-01

    This report presents the results of a U.S. Department of Energy (DOE) Innovative Clean Coal Technology (ICCT) project demonstrating advanced wall-fired combustion techniques for the reduction of nitrogen oxide (NOx) emissions from coal-fired boilers. The project was conducted at Georgia Power Company`s Plant Hammond Unit 4 located near Rome, Georgia. The technologies demonstrated at this site include Foster Wheeler Energy Corporation`s advanced overfire air system and Controlled Flow/Split Flame low NOx burner. The primary objective of the demonstration at Hammond Unit 4 was to determine the long-term effects of commercially available wall-fired low NOx combustion technologies on NOx emissions and boiler performance. Short-term tests of each technology were also performed to provide engineering information about emissions and performance trends. A target of achieving fifty percent NOx reduction using combustion modifications was established for the project. Short-term and long-term baseline testing was conducted in an {open_quotes}as-found{close_quotes} condition from November 1989 through March 1990. Following retrofit of the AOFA system during a four-week outage in spring 1990, the AOFA configuration was tested from August 1990 through March 1991. The FWEC CF/SF low NOx burners were then installed during a seven-week outage starting on March 8, 1991 and continuing to May 5, 1991. Following optimization of the LNBs and ancillary combustion equipment by FWEC personnel, LNB testing commenced during July 1991 and continued until January 1992. Testing in the LNB+AOFA configuration was completed during August 1993. This report provides documentation on the design criteria used in the performance of this project as it pertains to the scope involved with the low NOx burners and advanced overfire systems.

  17. Use of plasma fuel systems at thermal power plants in Russia, Kazakhstan, China, and Turkey

    SciTech Connect (OSTI)

    Karpenko, E.I.; Karpenko, Y.E.; Messerle, V.E.; Ustimenko, A.B.

    2009-05-15

    The technology of plasma ignition of solid fuels is described, as well as its creation and development steps, the technoeconomic characteristics of plasma igniter systems, schemes of their installation in pulverized-coal boilers, and results of their application at pulverized coal-fired power plants.

  18. Savannah River Site Retires Coal-Fired D-Area Powerhouse after Nearly 60 Years of Service

    Energy.gov [DOE]

    AIKEN, S.C. – The Savannah River Site (SRS) has shut down the massive, coal-powered D-Area powerhouse as the site turns to new, clean and highly efficient power generation technology.

  19. Engineering development of advanced coal-fired low-emission boiler systems: Technical progress report No. 16, July-September 1996

    SciTech Connect (OSTI)

    Barcikowski, G.F.; Borio, R.W.; Bozzuto, C.R.; Burr, D.H.; Cellilli, L.; Fox, J.D.; Gibbons, T.B.; Hargrove, M.J.; Jukkola, G.D.; King, A.M.

    1996-11-27

    The overall objective of the Project is the expedited commercialization of advanced coal-fired low-emission boiler systems. The Project is under budget and generally on schedule. The current status is shown in the Milestone Schedule Status Report included as Appendix A. Under Task 7--Component development and optimization, the CeraMem filter testing was completed. Due to an unacceptably high flue gas draft loss, which will not be resolved in the POCTF timeframe, a decision was made to change the design of the flue gas cleaning system from Hot SNO{sub x}{sup {trademark}} to an advanced dry scrubber called New Integrated Desulfurization (NID). However, it is recognized that the CeraMem filter still has the potential to be viable in pulverized coal systems. In Task 8-- Preliminary POCTF design, integrating and optimizing the performance and design of the boiler, turbine/generator and heat exchangers of the Kalina cycle as well as the balance of plant design were completed. Licensing activities continued. A NID system was substituted for the SNO{sub x} Hot Process.

  20. Cermet composite thermal spray coatings for erosion and corrosion protection in combustion environments of advanced coal-fired boilers. Semiannual technical report, January 14, 1997--August 14, 1997

    SciTech Connect (OSTI)

    Schorr, B.S.; Levin, B.F.; DuPont, J.N.; Marder, A.R.

    1997-08-31

    Research is presently being conducted to determine the optimum ceramic/metal combination in thermally sprayed metal matrix composite coatings for erosion and corrosion resistance in new coal-fired boilers. The research will be accomplished by producing model cermet composites using powder metallurgy and electrodeposition methods in which the effect of ceramic/metal combination for the erosion and corrosion resistance will be determined. These results will provide the basis for determining the optimum hard phase constituent size and volume percent in thermal spray coatings. Thermal spray coatings will be applied by our industrial sponsor and tested in our erosion and corrosion laboratories. Bulk powder processed Ni-Al{sub 2}O{sub 3} composites were produced at Idaho National Engineering Laboratory. The composite samples contained 0, 21, 27, 37, and 45 volume percent Al{sub 2}O{sub 3} with an average particle size of 12 um. Also, to deposit model Ni-Al{sub 2}O{sub 3} coatings, an electrodeposition technique was developed and coatings with various volume fractions (0-35%) of Al{sub 2}O{sub 3} were produced. The powder and electrodeposition processing of Ni-Al{sub 2}O{sub 3} Composites provide the ability to produce two phase microstructure without changing the microstructure of the matrix material. Therefore, the effect of hard second phase particles size and volume fraction on erosion resistance could be analyzed.

  1. Development of a coal-fired combustion system for industrial process heating applications. Phase 3 final report, November 1992--December 1994

    SciTech Connect (OSTI)

    1995-09-26

    A three phase research and development program has resulted in the development and commercialization of a Cyclone Melting System (CMS{trademark}), capable of being fueled by pulverized coal, natural gas, and other solid, gaseous, or liquid fuels, for the vitrification of industrial wastes. The Phase 3 research effort focused on the development of a process heater system to be used for producing value added glass products from the vitrification of boiler/incinerator ashes and industrial wastes. The primary objective of the Phase 3 project was to develop and integrate all the system components, from fuel through total system controls, and then test the complete system in order to evaluate its potential for successful commercialization. The demonstration test consisted of one test run with a duration of 105 hours, approximately one-half (46 hours) performed with coal as the primary fuel source (70% to 100%), the other half with natural gas. Approximately 50 hours of melting operation were performed vitrifying approximately 50,000 lbs of coal-fired utility boiler flyash/dolomite mixture, producing a fully-reacted vitrified product.

  2. Development of advanced NO{sub x} control concepts for coal-fired utility boilers. Quarterly technical progress report No. 8, July 1, 1992--September 30, 1992

    SciTech Connect (OSTI)

    Evans, A.; Pont, J.N.; England, G.; Seeker, W.R.

    1993-03-04

    The complete CombiNO{sub x}, process has now been demonstrated at a level that is believed to be representative of a full-scale boiler in terms of mixing capabilities. A summary of the results is displayed in Figure 5-1. While firing Illinois Coal on the Reburn Tower, Advanced Reburning was capable of reducing NO{sub x}, by 83 percent. The injection of methanol oxidized 50--58 percent of the existing NO to N0{sub 2}. Assuming that 85 percent of the newly formed N0{sub 2} can be scrubbed in a liquor modified wet-limestone scrubber, the CombiNO{sub x}, process has been shown capable of reducing NO{sub 2}, by 90--91 percent in a large pilot-scale coal-fired furnace. There is still uncertainty regarding the fate of the N0{sub 2} formed with methanol injection. Tests should be conducted to determine whether the reconversion is thermodynamic or catalytic, and what steps can be taken (such as quench rate) to prevent it from happening.

  3. Toxecon Retrofit for Mercury and Mulit-Pollutant Control on Three 90-MW Coal-Fired Boilers

    SciTech Connect (OSTI)

    Steven Derenne; Robin Stewart

    2009-09-30

    This U.S. Department of Energy (DOE) Clean Coal Power Initiative (CCPI) project was based on a cooperative agreement between We Energies and the DOE Office of Fossil Energy's National Energy Technology Laboratory (NETL) to design, install, evaluate, and demonstrate the EPRI-patented TOXECON{trademark} air pollution control process. Project partners included Cummins & Barnard, ADA-ES, and the Electric Power Research Institute (EPRI). The primary goal of this project was to reduce mercury emissions from three 90-MW units that burn Powder River Basin coal at the We Energies Presque Isle Power Plant in Marquette, Michigan. Additional goals were to reduce nitrogen oxide (NO{sub x}), sulfur dioxide (SO{sub 2}), and particulate matter emissions; allow reuse and sale of fly ash; advance commercialization of the technology; demonstrate a reliable mercury continuous emission monitor (CEM) suitable for use at power plants; and demonstrate recovery of mercury from the sorbent. Mercury was controlled by injection of activated carbon upstream of the TOXECON{trademark} baghouse, which achieved more than 90% removal on average over a 44-month period. During a two-week test involving trona injection, SO{sub 2} emissions were reduced by 70%, although no coincident removal of NOx was achieved. The TOXECON{trademark} baghouse also provided enhanced particulate control, particularly during startup of the boilers. On this project, mercury CEMs were developed and tested in collaboration with Thermo Fisher Scientific, resulting in a reliable CEM that could be used in the power plant environment and that could measure mercury as low as 0.1 {micro}g/m{sup 3}. Sorbents were injected downstream of the primary particulate collection device, allowing for continued sale and beneficial use of captured fly ash. Two methods for recovering mercury using thermal desorption on the TOXECON{trademark} PAC/ash mixture were successfully tested during this program. Two methods for using the TOXECON

  4. Development of advanced NO{sub x} control concepts for coal-fired utility boilers. Quarterly technical progress report no. 6, January 1, 1992--March 31, 1992

    SciTech Connect (OSTI)

    Evans, A.; Pont, J.N.; England, G.; Seeker, W.R.

    1992-09-15

    All three of the CombiNO{sub x} NO{sub x} control technologies were performed simultaneously for the first time. Tests were performed while firing coal as the primary fuel, and natural gas and coal as reburn fuels. The results for the complete CombiNO{sub x} process for coal firing and natural gas reburning are displayed in Figure 3-1. NO/NO{sub x} measurements were taken with the new sample system. The filter and line were cleaned periodically throughout testing to avoid ash build-up; ash has also been shown to convert NO{sub 2} to NO. Reduction due to natural gas reburning was 54% with burnout air injected at a downstream location of approximately 1600{degree}F. Advanced Gas Reburning produced a 79% reduction -- although it is suspected that better reduction would have been possible if injection resolution in the furnace allowed the urea to be injected at a more optimum temperature of 1850{degree}F. The methanol injection step converted 45% of the existing NO to NO{sub 2}, achieving an overall CombiNO{sub x} NO reduction of 89%. The coal reburning CombiNO{sub x} test results are displayed in Figure 3-2. Results are similar to those obtained for natural gas reburning. Reduction due to urea injection was better while reburning with coal than for natural gas, probably due to the more optimum urea injection temperature. The methanol injection step converted 40% of the NO to NO{sub 2}, similar to the 45% NO conversion that occurred for natural gas reburning. An overall CombiNO{sub x} NO reduction of 93% was achieved, resulting in a final NO concentration of 61 ppM at 3% O{sub 2}.

  5. Demonstration of SCR technology for the control of NOx emissions from high-sulfur coal-fired utility boilers

    SciTech Connect (OSTI)

    Hinton, W.S.; Maxwell, J.D.; Healy, E.C.; Hardman, R.R.; Baldwin, A.L.

    1997-12-31

    This paper describes the completed Innovative Clean Coal Technology project which demonstrated SCR technology for reduction of flue gas NO{sub x} emissions from a utility boiler burning US high-sulfur coal. The project was sponsored by the US Department of Energy, managed and co-funded by Southern Company Services, Inc. on behalf of the Southern Company, and also co-funded by the Electric Power Research Institute and Ontario Hydro. The project was located at Gulf Power Company`s Plant Crist Unit 5 (a 75 MW tangentially-fired boiler burning US coals that had a sulfur content ranging from 2.5--2.9%), near Pensacola, Florida. The test program was conducted for approximately two years to evaluate catalyst deactivation and other SCR operational effects. The SCR test facility had nine reactors: three 2.5 MW (5,000 scfm), and operated on low-dust flue gas. The reactors operated in parallel with commercially available SCR catalysts obtained from suppliers throughout the world. Long-term performance testing began in July 1993 and was completed in July 1995. A brief test facility description and the results of the project are presented in this paper.

  6. Innovative Clean Coal Technology (ICCT). Demonstration of Selective Catalytic Reduction (SCR) technology for the control of nitrogen oxide (NO{sub x}) emissions from high-sulfur coal-fired boilers: Volume 1. Final report

    SciTech Connect (OSTI)

    1996-10-01

    The objective of this project is to demonstrate and evaluate commercially available Selective Catalytic Reduction (SCR) catalysts from U.S., Japanese and European catalyst suppliers on a high-sulfur U.S. coal-fired boiler. SCR is a post-combustion nitrogen oxide (NO.) control technology that involves injecting ammonia into the flue gas generated from coal combustion in an electric utility boiler. The flue gas containing ammonia is then passed through a reactor that contains a specialized catalyst. In the presence of the catalyst, the ammonia reacts with NO. to convert it to nitrogen and water vapor. Although SCR is widely practiced in Japan and Europe on gas-, oil-, and low-sulfur coal- fired boilers, there are several technical uncertainties associated with applying SCR to U.S. coals. These uncertainties include: 1) potential catalyst deactivation due to poisoning by trace metal species present in U.S. coals that are not present in other fuels. 2) performance of the technology and effects on the balance-of- plant equipment in the presence of high amounts of SO{sub 2} and SO{sub 3}. 3) performance of a wide variety of SCR catalyst compositions, geometries and methods of manufacturer under typical high-sulfur coal-fired utility operating conditions. These uncertainties were explored by operating nine small-scale SCR reactors and simultaneously exposing different SCR catalysts to flue gas derived from the combustion of high sulfur U.S. coal. In addition, the test facility operating experience provided a basis for an economic study investigating the implementation of SCR technology.

  7. ADVANCED FLUE GAS CONDITIONING AS A RETROFIT UPGRADE TO ENHANCE PM COLLECTION FROM COAL-FIRED ELECTRIC UTILITY BOILERS

    SciTech Connect (OSTI)

    C. Jean Bustard

    2003-12-01

    ADA Environmental Solutions (ADA-ES) has successfully completed a research and development program granted by the Department of Energy National Energy Technology Laboratory (NETL) to develop a family of non-toxic flue gas conditioning agents to provide utilities and industries with a cost-effective means of complying with environmental regulations on particulate emissions and opacity. An extensive laboratory screening of potential additives was completed followed by full-scale trials at four utility power plants. The developed cohesivity additives have been demonstrated on a 175 MW utility boiler that exhibited poor collection of unburned carbon in the electrostatic precipitator. With cohesivity conditioning, opacity spiking caused by rapping reentrainment was reduced and total particulate emissions were reduced by more than 30%. Ammonia conditioning was also successful in reducing reentrainment on the same unit. Conditioned fly ash from the process is expected to be suitable for dry or wet disposal and for concrete admixture.

  8. Innovative Clean Coal Technology (ICCT). Demonstration of Selective Catalytic Reduction (SCR) technology for the control of Nitrogen Oxide (NO{sub x}) emissions from high-sulfur coal-fired boilers. Technical progress report, third and fourth quarters 1995

    SciTech Connect (OSTI)

    1996-05-01

    The objective of this project is to demonstrate and evaluate commercially available Selective Catalytic Reduction (SCR) catalysts from U.S., Japanese, and European catalyst suppliers on a high-sulfur U.S. coal-fired boiler. SCR is a post-combustion nitrogen oxide (NO{sub x}) control technology that involves injecting ammonia into the flue gas generated from coal combustion in an electric utility boiler. The flue gas containing ammonia is then passed through a reactor that contains a specialized catalyst. In the presence of the catalyst, the ammonia reacts with NO{sub x} to convert it to nitrogen and water vapor.

  9. Systems simulation of cotton gin waste as a supplemental fuel in a coal powered generating plant

    SciTech Connect (OSTI)

    Parnell, C.B.; Grubaugh, E.K.; Johnston, M.T.; Ladd, K.L.

    1981-01-01

    A systems simulation model of gin trash use at a Lamb County, Texas, power plant was developed. The model is being used to study gin trash supply, both quantity and transportation, fixed and variable cost, and economic benefit/costs of gin trash utilization. Preliminary results indicate the positive feasibility of using gin trash as a supplemental fuel in a coal fired power plant. (MHR)

  10. Demonstration of selective catalytic reduction (SCR) technology for the control of nitrogen oxide (NO{sub x}) emissions from high-sulfur coal-fired boilers. Quarterly report No. 8, April--June, 1992

    SciTech Connect (OSTI)

    Not Available

    1992-08-01

    The objective of this project is to demonstrate and evaluate commercially available Selective Catalytic Reduction (SCR) catalysts from US, Japanese and European catalyst suppliers on a high-sulfur US coal-fired boiler. SCR is a post-combustion nitrogen oxide (NO{sub x}) control technology that involves injecting ammonia into the flue gas generated from coal combustion in an electric utility boiler. The flue gas containing ammonia is then passed through a reactor that contains a specialized catalyst. In the presence of the catalyst, the ammonia reacts with NO{sub x} to convert it to nitrogen and water vapor. Although SCR is widely practiced in Japan and Europe, there are numerous technical uncertainties associated with applying SCR to US coals. These uncertainties include: (1) potential catalyst deactivation due to poisoning by trace metal species present in US coals that are not present in other fuels. (2) performance of the technology and effects on the balance-of-plant equipment in the presence of high amounts of SO{sub 2} and SO{sub 3}. (3) performance of a wide variety of SCR catalyst compositions, geometries and methods of manufacture under typical high-sulfur coal-fired utility operating conditions. These uncertainties will be explored by constructing a series of small-scale SCR reactors and simultaneously exposing different SCR catalysts to flue gas derived from the combustion of high sulfur U. S. coal.

  11. Task 3.14 - demonstration of technologies for remote power generation in Alaska. Semi-annual report, July 1, 1996--December 31, 1996

    SciTech Connect (OSTI)

    Jones, M.L.

    1998-12-31

    This paper very briefly summarizes progress in the demonstration of a small (up to 6 MWe), environmentally acceptable electric generating system fueled by indigenous fuels and waste materials to serve power distribution systems typical of Alaskan Native communities. Two detailed appendices supplement the report. The project is focused on two primary technologies: (1) atmospheric fluidized bed combustion (AFBC), and (2) coalbed methane and coal-fired diesel technologies. Two sites have been selected as possible locations for an AFBC demonstration, and bid proposals are under review. The transfer of a coal-fired diesel clean coal demonstration project from Maryland to Fairbanks, Alaska was approved, and the environmental assessment has been initiated. Federal support for a fuel cell using coalbed methane is also being pursued. The appendices included in the report provide: (1) the status of the conceptual design study for a 600-kWe coal-fired cogeneration plant in McGrath, Alaska; and (2) a global market assessment of coalbed methane, fluidized-bed combustion, and coal-fired diesel technologies in remote applications.

  12. PARTICULATE CHARACTERIZATION AND ULTRA LOW-NOx BURNER FOR THE CONTROL OF NO{sub x} AND PM{sub 2.5} FOR COAL FIRED BOILERS

    SciTech Connect (OSTI)

    Ralph Bailey; Hamid Sarv; Jim Warchol; Debi Yurchison

    2001-09-30

    In response to the serious challenge facing coal-fired electric utilities with regards to curbing their NO{sub x} and fine particulate emissions, Babcock and Wilcox and McDermott Technology, Inc. conducted a project entitled, ''Particulate Characterization and Ultra Low-NO{sub x} Burner for the Control of NO{sub x} and PM{sub 2.5} for Coal Fired Boilers.'' The project included pilot-scale demonstration and characterization of technologies for removal of NO{sub x} and primary PM{sub 2.5} emissions. Burner development and PM{sub 2.5} characterization efforts were based on utilizing innovative concepts in combination with sound scientific and fundamental engineering principles and a state-of-the-art test facility. Approximately 1540 metric tonnes (1700 tons) of high-volatile Ohio bituminous coal were fired. Particulate sampling for PM{sub 2.5} emissions characterization was conducted in conjunction with burner testing. Based on modeling recommendations, a prototype ultra low-NO{sub x} burner was fabricated and tested at 100 million Btu/hr in the Babcock and Wilcox Clean Environment Development Facility. Firing the unstaged burner with a high-volatile bituminous Pittsburgh 8 coal at 100 million Btu/hr and 17% excess air achieved a NO{sub x} goal of 0.20 lb NO{sub 2}/million Btu with a fly ash loss on ignition (LOI) of 3.19% and burner pressure drop of 4.7 in H{sub 2}O for staged combustion. With the burner stoichiometry set at 0.88 and the overall combustion stoichiometry at 1.17, average NO{sub x} and LOI values were 0.14 lb NO{sub 2}/million Btu and 4.64% respectively. The burner was also tested with a high-volatile Mahoning 7 coal. Based on the results of this work, commercial demonstration is being pursued. Size classified fly ash samples representative of commercial low-NO{sub x} and ultra low-NO{sub x} combustion of Pittsburgh 8 coal were collected at the inlet and outlet of an ESP. The mass of size classified fly ash at the ESP outlet was sufficient to evaluate

  13. Techno-economic analysis of using corn stover to supply heat and power to a corn ethanol plant - Part 2: Cost of heat and power generation systems

    SciTech Connect (OSTI)

    Mani, Sudhagar; Sokhansanj, Shahabaddine; Togore, Sam; Turhollow Jr, Anthony F

    2010-03-01

    This paper presents a techno-economic analysis of corn stover fired process heating (PH) and the combined heat and power (CHP) generation systems for a typical corn ethanol plant (ethanol production capacity of 170 dam3). Discounted cash flow method was used to estimate both the capital and operating costs of each system and compared with the existing natural gas fired heating system. Environmental impact assessment of using corn stover, coal and natural gas in the heat and/or power generation systems was also evaluated. Coal fired process heating (PH) system had the lowest annual operating cost due to the low fuel cost, but had the highest environmental and human toxicity impacts. The proposed combined heat and power (CHP) generation system required about 137 Gg of corn stover to generate 9.5 MW of electricity and 52.3 MW of process heat with an overall CHP efficiency of 83.3%. Stover fired CHP system would generate an annual savings of 3.6 M$ with an payback period of 6 y. Economics of the coal fired CHP system was very attractive compared to the stover fired CHP system due to lower fuel cost. But the greenhouse gas emissions per Mg of fuel for the coal fired CHP system was 32 times higher than that of stover fired CHP system. Corn stover fired heat and power generation system for a corn ethanol plant can improve the net energy balance and add environmental benefits to the corn to ethanol biorefinery.

  14. Discussion on 'characteristics of fly ashes from full-scale coal-fired power plants and their relationship to mercury adsorption' by Lu et al.

    SciTech Connect (OSTI)

    James C. Hower; Bruno Valentim; Irena J. Kostova; Kevin R. Henke

    2008-03-15

    Mercury capture by coal-combustion fly ash is a function of the amount of Hg in the feed coal, the amount of carbon in the fly ash, the type of carbon in the fly ash (including variables introduced by the rank of the feed coal), and the flue gas temperature at the point of ash collection. In their discussion of fly ash and Hg adsorption, Lu et al. (Energy Fuels 2007, 21, 2112-2120) had some fundamental flaws in their techniques, which, in turn, impact the validity of analyzed parameters. First, they used mechanical sieving to segregate fly ash size fractions. Mechanical sieving does not produce representative size fractions, particularly for the finest sizes. If the study samples were not obtained correctly, the subsequent analyses of fly ash carbon and Hg cannot accurately represent the size fractions. In the analysis of carbon forms, it is not possible to accurately determine the forms with scanning electron microscopy. The complexity of the whole particles is overlooked when just examining the outer particle surface. Examination of elements such as Hg, present in very trace quantities in most fly ashes, requires careful attention to the analytical techniques. 36 refs., 3 figs., 1 tab.

  15. Power Systems Development Facility

    SciTech Connect (OSTI)

    Southern Company Services

    2009-01-31

    In support of technology development to utilize coal for efficient, affordable, and environmentally clean power generation, the Power Systems Development Facility (PSDF), located in Wilsonville, Alabama, has routinely demonstrated gasification technologies using various types of coals. The PSDF is an engineering scale demonstration of key features of advanced coal-fired power systems, including a Transport Gasifier, a hot gas particulate control device, advanced syngas cleanup systems, and high-pressure solids handling systems. This final report summarizes the results of the technology development work conducted at the PSDF through January 31, 2009. Twenty-one major gasification test campaigns were completed, for a total of more than 11,000 hours of gasification operation. This operational experience has led to significant advancements in gasification technologies.

  16. Development of a Dry Sorbent-based Post-Combustion CO2 Capture Technology for Retrofit in Existing Power Plants

    SciTech Connect (OSTI)

    Nelson, Thomas; Coleman, Luke; Anderson, Matthew; Gupta, Raghubir; Herr, Joshua; Kalluri, Ranjeeth; Pavani, Maruthi

    2009-12-31

    The objective of this research and development (R&D) project was to further the development of a solid sorbent-based CO2 capture process based on sodium carbonate (i.e. the Dry Carbonate Process) that is capable of capturing>90% of the CO2 as a nearly pure stream from coal-fired power plant flue gas with <35% increase in the cost of electrictiy (ICOE).

  17. Pumping test and fluid sampling report, Mansfield No. 1 well, Palo Duro Basin: Report of the Geologic Project Manager, Permian Basin

    SciTech Connect (OSTI)

    Not Available

    1983-07-01

    This report describes pumping test and fluid sampling activities performed at the Mansfield No. 1 well in Oldham County about 10 miles north of Vega, Texas. The well site was selected by TBEG and is located along the northern margin of the Palo Duro Basin in an area of active dissolution with the Permian salt sections. The objectives of the pumping test and fluid sampling program were to collect data to determine the hydrologic characteristics (formation pressure and permeability) of deep water bearing formations, and to obtain formation fluid samples for analyses (gas and fluid chemistry) in order to evaluate fluid migration and age relationships in the Permian Basin. 4 refs., 8 figs., 2 tabs.

  18. Deputy Secretary Sherwood-Randall Announces New Bilateral Energy...

    Energy Savers

    gas emissions from coal-fired electricity generation, through advanced coal-fired power plant computational modeling, the development and testing of advanced sensors and ...

  19. Cermet composite thermal spray coatings for erosion and corrosion protection in combustion environments of advanced coal-fired boilers. Semiannual technical progress report, August 14, 1996--January 14, 1997

    SciTech Connect (OSTI)

    Levin, B.F.; DuPont, J.N.; Marder, A.R.

    1997-02-01

    Research is presently being conducted to determine the optimum ceramic/metal combination in thermally sprayed metal matrix composite coatings for erosion and corrosion resistance in new coal-fired boilers. The research will be accomplished by producing model cermet composites using powder metallurgy and electrodeposition methods in which the effect of ceramic/metal combination for the erosion and corrosion resistance will be determined. These results will provide the basis for determining the optimum hard phase constituent size and volume percent in thermal spray coatings. Thermal spray coatings will be applied by our industrial sponsor and tested in our erosion and corrosion laboratories. In the first six months of this project, bulk powder processed Ni-Al{sub 2}O{sub 3} composites were produced at Idaho National Engineering Laboratory. The results of microstructural characterization of these alloys were presented in the first semiannual report. The composite samples contained 0, 21, 27, 37, and 45 volume percent Al{sub 2}O{sub 3} with an average particle size of 12 um. An increase in the volume fraction of alumina in the nickel matrix from 0 to 45% led to a significant increase in hardness of these composites.

  20. 180 MW demonstration of advanced tangentially-fired combustion techniques for the reduction of nitrogen oxide (NO{sub x}) emissions from coal-fired boilers. Final report

    SciTech Connect (OSTI)

    Tavoulareas, E.S.; Hardman, R.; Eskinazi, D.; Smith, L.

    1994-02-01

    This report provides the key findings of the Innovative Clean Coal Technology (ICCT) demonstration project at Gulf Power`s Lansing Smith Unit No. 2 and the implications for other tangentially-fired boilers. L. Smith Unit No. 2 is a 180 MW tangentially-fired boiler burning Eastern Bituminous coal, which was retrofitted with Asea Brown Boveri/Combustion Engineering Services` (ABB/CE) LNCFS I, II, and III technologies. An extensive test program was carried-out with US Department of Energy, Southern Company and Electric Power Research Institute (EPRI) funding. The LNCFS I, II, and III achieved 37 percent, 37 percent, and 45 percent average long-term NO{sub x} emission reduction at full load, respectively (see following table). Similar NO{sub x} reduction was achieved within the control range (100--200 MW). However, below the control point (100 MW), NO{sub x} emissions with the LNCFS technologies increased significantly, reaching pre-retrofit levels at 70 MW. Short-term testing proved that low load NO{sub x} emissions could be reduced further by using lower excess O{sub 2} and burner tilt, but with adversed impacts on unit performance, such as lower steam outlet temperatures and, potentially, higher CO emissions and LOI.

  1. Boryeong Thermal Power Complex, Boryeong-Si, Chungcheongnam-do Province, South Korea

    SciTech Connect (OSTI)

    Neville, J.D.

    2008-10-15

    From tall skyscrapers and flashing neon signs to Buddhist temples and pagodas, South Korea is a mixture of the new and old Asia. Doing its part to help modernise this country, the Boryeong thermal power complex operates six coal-fired 500-MW units that provide electricity to power South Korea's economic growth. One of the important reasons for this facility's overall success is its operational reliability. An example of this is Boryeong Unit 3's outstanding achievement of 3,000 days of trouble-free operation. The Complex also has a dozen 150 MW combined cycle units burning imported liquefied natural gas for electrical system peaking. 4 photos.

  2. Research on fundamental aspects of inorganic particle deposition on coal-fired equipment. Final technical report, 6 September 1990--31 October 1994

    SciTech Connect (OSTI)

    Rosner, D.E.

    1995-01-01

    We review results of our recent DOE-PETC research program on the deposition dynamics of combustion-generated particles in power production technologies. We outline and illustrate the results of recently developed methods to predict total surface deposition rates and associated convective heat transfer reductions for targets exposed to a distribution of particles suspended in a mainstream. Our methods combine the essential features of recently developed single particle sticking probability laws with correlations of the inertial impaction of particles on targets in high Reynolds number cross-flow, to develop formulae and ``universal`` graphs which provide the dependence of particle deposition rates, and associated reductions in convective heat transfer, on such system parameters as mainstream velocity, mean suspended particle size and target size. The deposition rate/deposit microstructue/properties prediction and correlation procedures illustrated be incorporated into improved ``fouling propensity indices,`` to motivate, evaluate and implement ``ruggedization`` and/or fouling reduction strategies, and/or incorporated (as subroutines) into more ``comprehensive`` CFD models of an entire power plant.

  3. MEMBRANE PROCESS TO SEQUESTER CO2 FROM POWER PLANT FLUE GAS

    SciTech Connect (OSTI)

    Tim Merkel; Karl Amo; Richard Baker; Ramin Daniels; Bilgen Friat; Zhenjie He; Haiqing Lin; Adrian Serbanescu

    2009-03-31

    The objective of this project was to assess the feasibility of using a membrane process to capture CO2 from coal-fired power plant flue gas. During this program, MTR developed a novel membrane (Polaris™) with a CO2 permeance tenfold higher than commercial CO2-selective membranes used in natural gas treatment. The Polaris™ membrane, combined with a process design that uses a portion of combustion air as a sweep stream to generate driving force for CO2 permeation, meets DOE post-combustion CO2 capture targets. Initial studies indicate a CO2 separation and liquefaction cost of $20 - $30/ton CO2 using about 15% of the plant energy at 90% CO2 capture from a coal-fired power plant. Production of the Polaris™ CO2 capture membrane was scaled up with MTR’s commercial casting and coating equipment. Parametric tests of cross-flow and countercurrent/sweep modules prepared from this membrane confirm their near-ideal performance under expected flue gas operating conditions. Commercial-scale, 8-inch diameter modules also show stable performance in field tests treating raw natural gas. These findings suggest that membranes are a viable option for flue gas CO2 capture. The next step will be to conduct a field demonstration treating a realworld power plant flue gas stream. The first such MTR field test will capture 1 ton CO2/day at Arizona Public Service’s Cholla coal-fired power plant, as part of a new DOE NETL funded program.

  4. Pilot-Scale Demonstration of a Novel, Low-Cost Oxygen Supply Process and its Integration with Oxy-Fuel Coal-Fired Boilers

    SciTech Connect (OSTI)

    Krish Krishnamurthy; Divy Acharya; Frank Fitch

    2008-09-30

    In order to achieve DOE targets for carbon dioxide capture, it is crucial not only to develop process options that will generate and provide oxygen to the power cycle in a cost-effective manner compared to the conventional oxygen supply methods based on cryogenic air separation technology, but also to identify effective integration options for these new technologies into the power cycle with carbon dioxide capture. The Linde/BOC developed Ceramic Autothermal Recovery (CAR) process remains an interesting candidate to address both of these issues by the transfer of oxygen from the air to a recycled CO{sub 2} rich flue-gas stream in a cyclic process utilizing the high temperature sorption properties of perovskites. Good progress was made on this technology in this project, but significant challenges remain to be addressed before CAR oxygen production technology is ready for commercial exploitation. Phase 1 of the project was completed by the end of September 2008. The two-bed 0.7 tons/day O2 CAR process development unit (PDU) was installed adjacent to WRI's pilot scale coal combustion test facility (CTF). Start-up and operating sequences for the PDU were developed and cyclic operation of the CAR process demonstrated. Controlled low concentration methane addition allowed the beds to be heated up to operational temperature (800-900 C) and then held there during cyclic operation of the 2-bed CAR process, in this way overcoming unavoidable heat losses from the beds during steady state operation. The performance of the PDU was optimized as much as possible, but equipment limitations prevented the system from fully achieving its target performance. Design of the flue gas recirculation system to integrate CAR PDU with the CTF and the system was completed and integrated tests successfully performed at the end of the period. A detailed techno-economic analysis was made of the CAR process for supplying the oxygen in oxy-fuel combustion retrofit option using AEP's 450 MW

  5. Development and testing of industrial scale, coal fired combustion system, Phase 3. Sixteenth quarterly technical progress report, October 1--December 31, 1995

    SciTech Connect (OSTI)

    Zauderer, B.

    1996-01-03

    In the fourth quarter of calendar year 1995 the installation and checkout of the 20 MMBtu/hr combustor and auxiliary equipment in Philadelphia was completed. The task 5, Site Demonstration Testing, combustor-boiler tests on gas, oil, and coal were initiated. The task 5 effort involves testing the combustor over extended periods under conditions that fully simulate commercial operation and that meet the combustion and environmental specifications for this project. To meet this project objective within the current work scope requires up to 500 hours of testing. The focus of this testing will be on the component and environmental performance of combustor, boiler, coal preparation and feeding, and the stack gas equipment. The facility can be converted to a 500 kW power plant by the addition of a steam turbine, condenser, and cooling tower. However, this added effort is beyond the current work scope and its implementation will depend on recovering the added costs by placing the steam production from the boiler to beneficial use. During the present quarterly reporting period, all the components needed to implement the initial 100 hours of testing under task 5 were installed at the test site, and checkout of this equipment was performed. Since the present installation contained substantial improvements and simplifications to all sub-systems that had been used in the Williamsport facility, each component and sub-system had to be tested individually.

  6. 1,"PPL Susquehanna","Nuclear","PPL Susquehanna LLC",2520 2,"FirstEnergy Bruce Mansfield","Coal","FirstEnergy Generation Corp",2510

    U.S. Energy Information Administration (EIA) (indexed site)

    Pennsylvania" ,"Plant","Primary energy source","Operating company","Net summer capacity (MW)" 1,"PPL Susquehanna","Nuclear","PPL Susquehanna LLC",2520 2,"FirstEnergy Bruce Mansfield","Coal","FirstEnergy Generation Corp",2510 3,"Peach Bottom","Nuclear","Exelon Nuclear",2242.4 4,"Limerick","Nuclear","Exelon Nuclear",2241.8

  7. Innovative clean coal technology (ICCT): demonstration of selective catalytic reduction (SCR) technology for the control of nitrogen oxide (NO{sub x}) emission from high-sulfur, coal-fired boilers - economic evaluation of commercial-scale SCR applications for utility boilers

    SciTech Connect (OSTI)

    Healy, E.C.; Maxwell, J.D.; Hinton, W.S.

    1996-09-01

    This report presents the results of an economic evaluation produced as part of the Innovative Clean Coal Technology project, which demonstrated selective catalytic reduction (SCR) technology for reduction of NO{sub x} emissions from utility boilers burning U.S. high-sulfur coal. The document includes a commercial-scale capital and O&M cost evaluation of SCR technology applied to a new facility, coal-fired boiler utilizing high-sulfur U.S. coal. The base case presented herein determines the total capital requirement, fixed and variable operating costs, and levelized costs for a new 250-MW pulverized coal utility boiler operating with a 60-percent NO{sub x} removal. Sensitivity evaluations are included to demonstrate the variation in cost due to changes in process variables and assumptions. This report also presents the results of a study completed by SCS to determine the cost and technical feasibility of retrofitting SCR technology to selected coal-fired generating units within the Southern electric system.

  8. EIS-0215: Pinon Pine Power Project, Tracy Station, NV

    Energy.gov [DOE]

    The U.S. Department of Energy (DOE) prepared this statement to assess the environmental and human health issues associated with the Pinon Pine Power Project, a proposed demonstration project that would be cost-shared by DOE and the Sierra Pacific Power Company (SPPCo.) under DOE's Clean Coal Technology Program. The proposed Federal action is for DOE to provide cost-shared funding support for the construction and operation of the Pinon Pine Power Project, a coal-fired power generating facility, which would be a nominal, 800-ton-per-day (104 megawatt (MW) gross generation) air-blown, Integrated Gasification Combined-Cycle plant proposed by SPPCo. at its Tracy Power Station near Reno, Nevada.

  9. Comparison of large central and small decentralized power generation in India

    SciTech Connect (OSTI)

    1997-05-01

    This reports evaluates two options for providing reliable power to rural areas in India. The benefits and costs are compared for biomass based distributed generation (DG) systems versus a 1200-MW central grid coal-fired power plant. The biomass based DG systems are examined both as alternatives to grid extension and as supplements to central grid power. The benefits are divided into three categories: those associated with providing reliable power from any source, those associated specifically with biomass based DG technology, and benefits of a central grid coal plant. The report compares the estimated delivered costs of electricity from the DG systems to those of the central plant. The analysis includes estimates for a central grid coal plant and four potential DG system technologies: Stirling engines, direct-fired combustion turbines, fuel cells, and biomass integrated gasification combined cycles. The report also discusses issues affecting India`s rural electricity demand, including economic development, power reliability, and environmental concerns. The results of the costs of electricity comparison between the biomass DG systems and the coal-fired central grid station demonstrated that the DG technologies may be able to produce very competitively priced electricity by the start of the next century. The use of DG technology may provide a practical means of addressing many rural electricity issues that India will face in the future. Biomass DG technologies in particular offer unique advantages for the environment and for economic development that will make them especially attractive. 58 refs., 31 figs.

  10. Wind Power Price Trends in the United States

    SciTech Connect (OSTI)

    Bolinger, Mark; Wiser, Ryan

    2009-07-15

    For the fourth year in a row, the United States led the world in adding new wind power capacity in 2008, and also surpassed Germany to take the lead in terms of cumulative installed wind capacity. The rapid growth of wind power in the U.S. over the past decade (Figure 1) has been driven by a combination of increasingly supportive policies (including the Federal production tax credit (PTC) and a growing number of state renewables portfolio standards), uncertainty over the future fuel costs and environmental liabilities of natural gas and coal-fired power plants, and wind's competitive position among generation resources. This article focuses on just the last of these drivers - i.e., trends in U.S. wind power prices - over the period of strong capacity growth since 1998.

  11. Microsoft PowerPoint - 3_FG2 scoping_Ameren

    U.S. Department of Energy (DOE) all webpages (Extended Search)

    Meredosia Plant Location - Meredosia, IL Operated by Ameren Energy Resources 4 existing units, 3-coal fired (2 suspended), 1-oil-fired Illinois and Western Coal Truck & barge ...

  12. Coal Gasification for Power Generation, 3. edition

    SciTech Connect (OSTI)

    2007-11-15

    The report provides a concise look at the challenges faced by coal-fired generation, the ability of coal gasification to address these challenges, and the current state of IGCC power generation. Topics covered include: an overview of Coal Generation including its history, the current market environment, and the status of coal gasification; a description of gasification technology including processes and systems; an analysis of the key business factors that are driving increased interest in coal gasification; an analysis of the barriers that are hindering the implementation of coal gasification projects; a discussion of Integrated Gasification Combined Cycle (IGCC) technology; an evaluation of IGCC versus other generation technologies; a discussion of IGCC project development options; a discussion of the key government initiatives supporting IGCC development; profiles of the key gasification technology companies participating in the IGCC market; and, a detailed description of existing and planned coal IGCC projects.

  13. Gasification CFD Modeling for Advanced Power Plant Simulations

    SciTech Connect (OSTI)

    Zitney, S.E.; Guenther, C.P.

    2005-09-01

    In this paper we have described recent progress on developing CFD models for two commercial-scale gasifiers, including a two-stage, coal slurry-fed, oxygen-blown, pressurized, entrained-flow gasifier and a scaled-up design of the PSDF transport gasifier. Also highlighted was NETL’s Advanced Process Engineering Co-Simulator for coupling high-fidelity equipment models with process simulation for the design, analysis, and optimization of advanced power plants. Using APECS, we have coupled the entrained-flow gasifier CFD model into a coal-fired, gasification-based FutureGen power and hydrogen production plant. The results for the FutureGen co-simulation illustrate how the APECS technology can help engineers better understand and optimize gasifier fluid dynamics and related phenomena that impact overall power plant performance.

  14. Task 2.3 - Review and assessment of results from the comprehensive characterization of toxic emissions from coal-fired power plants: Semiannual report, January 1-June 30, 1996

    SciTech Connect (OSTI)

    Ness, S.R.

    1997-09-01

    The objective of the project is to provide an independent review of the Phase I data, evaluate the scientific validity of the conclusions, identify significant correlations between emissions and fuel or process parameters, compare the data with available data from EPRI studies, make recommendations for future studies, and complete a combined report that summarizes Phase I, Phase II, and EPRI findings.

  15. Task 2.3 - Review and Assessment of Results from the Comprehensive Characterization of Toxic Emissions from Coal-Fired Power Plants: Semi-annual report, July 1-December 31, 1996.

    SciTech Connect (OSTI)

    Ness, S.R.

    1997-12-31

    The air toxic emission data from Phase I were summarized and evaluated in the final Phase I summary report, published in September 1996 and available for distribution in October 1996. Data from Phase I were presented at the Center for Air Toxic Metals annual review meeting at the Energy {ampersand} Environmental Research Center in October 1996. The objective of the project was to provide. an independent review of the Phase I data, evaluate the scientific validity of the conclusions, identify significant correlations between emissions and fuel or process parameters, compare the data with available data from EPRI studies, make recommendations for future studies, and complete a combined report that summarizes Phase I, Phase II, and EPRI findings.

  16. Nuclear economics 2000: Deterministic and probabilistic projections of nuclear and coal electric power generation costs for the year 2000

    SciTech Connect (OSTI)

    Williams, K.A.; Delene, J.G.; Fuller, L.C.; Bowers, H.I.

    1987-06-01

    The total busbar electric generating costs were estimated for locations in ten regions of the United States for base-load nuclear and coal-fired power plants with a startup date of January 2000. For the Midwest region a complete data set that specifies each parameter used to obtain the comparative results is supplied. When based on the reference set of input variables, the comparison of power generation costs is found to favor nuclear in most regions of the country. Nuclear power is most favored in the northeast and western regions where coal must be transported over long distances; however, coal-fired generation is most competitive in the north central region where large reserves of cheaply mineable coal exist. In several regions small changes in the reference variables could cause either option to be preferred. The reference data set reflects the better of recent electric utility construction cost experience (BE) for nuclear plants. This study assumes as its reference case a stable regulatory environment and improved planning and construction practices, resulting in nuclear plants typically built at the present BE costs. Today's BE nuclear-plant capital investment cost model is then being used as a surrogate for projected costs for the next generation of light-water reactor plants. An alternative analysis based on today's median experience (ME) nuclear-plant construction cost experience is also included. In this case, coal is favored in all ten regions, implying that typical nuclear capital investment costs must improve for nuclear to be competitive.

  17. solid-sorbent | netl.doe.gov

    U.S. Department of Energy (DOE) all webpages (Extended Search)

    Evaluation of Solid Sorbents as a Retrofit Technology for CO2 Capture from Coal-Fired Power ... design for the integration of the sorbent system into a coal-fired power plant. ...

  18. low-cost-sorbent | netl.doe.gov

    U.S. Department of Energy (DOE) all webpages (Extended Search)

    Low Cost Sorbent for Capturing CO2 Emissions Generated by Existing Coal-Fired Power Plants ... Mass and energy balances for a commercial-scale, coal-fired power plant retrofit with ...

  19. High-temperature corrosion in power-generating systems.

    SciTech Connect (OSTI)

    Natesan, K.

    2002-05-22

    Several technologies are being developed to convert coal into clean fuel for use in power generation. From the standpoint of component materials in these technologies, the environments created by coal conversion and their interactions with materials are of interest. Coal is a complex and relatively dirty fuel that contains varying amounts of sulfur and a substantial fraction of noncombustible mineral constituents, commonly called ash. Corrosion of metallic and ceramic structural materials is a potential problem at elevated temperatures in the presence of complex gas environments and coal-derived solid/liquid deposits. This paper discusses the coal-fired systems currently under development, identifies several modes of corrosion degradation that occur in many of these systems, and suggests possible mechanisms of metal wastage. Available data on the performance of materials in some of the environments are highlighted, and the research needed to improve the corrosion resistance of various materials is presented.

  20. Efficiency improvement of thermal coal power plants

    SciTech Connect (OSTI)

    Hourfar, D.

    1996-12-31

    The discussion concerning an increase of the natural greenhouse effect by anthropogenic changes in the composition of the atmosphere has increased over the past years. The greenhouse effect has become an issue of worldwide debate. Carbon dioxide is the most serious emission of the greenhouse gases. Fossil-fired power plants have in the recent past been responsible for almost 30 % of the total CO{sub 2} emissions in Germany. Against this background the paper will describe the present development of CO{sub 2} emissions from power stations and present actual and future opportunities for CO{sub 2} reduction. The significance attached to hard coal as one of today`s prime sources of energy with the largest reserves worldwide, and, consequently, its importance for use in power generation, is certain to increase in the years to come. The further development of conventional power plant technology, therefore, is vital, and must be carried out on the basis of proven operational experience. The main incentive behind the development work completed so far has been, and continues to be, the achievement of cost reductions and environmental benefits in the generation of electricity by increasing plant efficiency, and this means that, in both the short and the long term, power plants with improved conventional technology will be used for environmentally acceptable coal-fired power generation.

  1. Coal as an option for power generation in US territories of the Pacific

    SciTech Connect (OSTI)

    Borg, I. Y.

    1981-11-30

    A survey of general considerations relating to the use of coal in US territories and trust territories of the Pacific suggests that coal is a viable option for power generation. Future coal supplies, principally from Australia and the west coast of America, promise to be more than adequate, but large bulk carriers will probably not be able to land coal directly because of inadequate port facilities. Hence, smaller than Panamax-class vessels (60,000 dwt) or some arrangement utilizing self-loading barges or lighters would have to be used. Except for Guam, with peak power requirements on the order of 175 MW/sub e/, most territories have current, albeit inadequate, installations of 1 to 25 MW/sub e/ Turnkey, conventional-coal-fired, electrical-power generating systems are available in that size range. US environmental laws are now applicable to Guam and American Samoa; the trust territories are exempt. However, the small power requirements of many small islands will qualify for exemption from the New Source Performance Standards called for in the Clean Air Act. The principal problems with coal use in the territories, apart from the shallow draft of most harbors, are the limited amount of land available and the high capital costs associated with conversion. Ocean dumping of ash and sludge can be permitted under existing Environmental Protection Agency regulations, and barge-mounted power installations are not out of the question. The feasibility of converting from oil-fired to coal-fired electrical-power generating systems must be determined with site-specific information.

  2. Electric Power Industry--Chap6

    U.S. Energy Information Administration (EIA) (indexed site)

    and carbon dioxide (CO2). Coal-fired generating units produce more SO2 and NOx than other fossil-fuel units for two reasons. First, because coal generally contains more sulfur than...

  3. Tampa Electric Company Polk Power Station IGCC Project -- Project status

    SciTech Connect (OSTI)

    Berry, T.E.

    1998-12-31

    The Tampa Electric Company Polk Power Station is a nominal 25 MW (net) Integrated Gasification Combined Cycle (IGCC) power plant located southeast of Tampa in Polk County, Florida. This project is being partially funded under the Department of Energy`s Clean Coal Technology Program pursuant to a Round III award. The Polk Power Station uses oxygen-blown, entrained-flow coal gasification technology licensed from Texaco Development Corporation in conjunction with a General Electric combined cycle with an advanced combustion turbine. This IGCC configuration demonstrates significant reductions of SO{sub 2} and NOx emissions when compared to existing and future conventional coal-fired power plants. The Polk Power Station achieved ``first fire`` of the gasification system on schedule in mid-July, 1996. It was placed into commercial operation on September 30, 1996. Since that time, significant advances have occurred in the operation of the entire IGCC train. The presentation features an up-to-the-minute update of actual performance parameters achieved by the Polk Power Station. These parameters include overall capacity, heat rate, and availability. Tests of four alternate feedstocks were conducted, and the resulting performance is compared to that achieved on their base coal. This paper also provides an update of the general operating experiences and shutdown causes of the gasification facility throughout 1997. Finally, the future plans for improving the reliability and efficiency of the Unit will be addressed, as well as plans for future additional alternate fuel test burns.

  4. Climate Change, Nuclear Power and Nuclear Proliferation: Magnitude Matters

    SciTech Connect (OSTI)

    Robert J. Goldston

    2010-03-03

    Integrated energy, environment and economics modeling suggests electrical energy use will increase from 2.4 TWe today to 12 TWe in 2100. It will be challenging to provide 40% of this electrical power from combustion with carbon sequestration, as it will be challenging to provide 30% from renewable energy sources. Thus nuclear power may be needed to provide ~30% by 2100. Calculations of the associated stocks and flows of uranium, plutonium and minor actinides indicate that the proliferation risks at mid-century, using current light-water reactor technology, are daunting. There are institutional arrangements that may be able to provide an acceptable level of risk mitigation, but they will be difficult to implement. If a transition is begun to fast-spectrum reactors at mid-century, without a dramatic change in the proliferation risks of such systems, at the end of the century proliferation risks are much greater, and more resistant to mitigation. The risks of nuclear power should be compared with the risks of the estimated 0.64oC long-term global surface-average temperature rise predicted if nuclear power were replaced with coal-fired power plants without carbon sequestration. Fusion energy, if developed, would provide a source of nuclear power with much lower proliferation risks than fission.

  5. Company Name Company Name Address Place Zip Sector Product Website

    Open Energy Information (Open El) [EERE & EIA]

    operates a number of power stations including the largest coal fired power station in the world as well as the Koeberg nuclear power station Esmeralda Energy Company Esmeralda...

  6. ppii | netl.doe.gov

    U.S. Department of Energy (DOE) all webpages (Extended Search)

    Power Plant Improvement Initiative (PPII) The Power Plant Improvement Initiative (PPII) ... the economics and overall performance of coal-fired power plants and will build on the ...

  7. Innovative Clean Coal Technology (ICCT): 500 MW demonstration of advanced wall-fired combustion techniques for the reduction of nitrogen oxide (NO{sub x}) emissions from coal-fired boilers. Technical progress report: First quarter 1993

    SciTech Connect (OSTI)

    Not Available

    1993-12-31

    This quarterly report discusses the technical progress of an Innovative Clean Coal Technology (ICCT) demonstration being conducted at Georgia Power Company`s Plant Hammond Unit 4 located near Rome, Georgia. The primary goal of this project is the characterization of the low NO{sub x} combustion equipment through the collection and analysis of long-term emissions data. A target of achieving fifty percent NO{sub x} reduction using combustion modifications has been established for the project. The project provides a stepwise retrofit of an advanced overfire air (AOFA) system followed by low NO{sub x} burners (LNB). During each test phase of the project, diagnostic, performance, long-term, and verification testing will be performed. These tests are used to quantify the NO{sub x} reductions of each technology and evaluate the effects of those reductions on other combustion parameters such as particulate characteristics and boiler efficiency. During this quarter, long-term testing of the LNB + AOFA configuration continued and no parametric testing was performed. Further full-load optimization of the LNB + AOFA system began on March 30, 1993. Following completion of this optimization, comprehensive testing in this configuration will be performed including diagnostic, performance, verification, long-term, and chemical emissions testing. These tests are scheduled to start in May 1993 and continue through August 1993. Preliminary engineering and procurement are progressing on the Advanced Low NOx Digital Controls scope addition to the wall-fired project. The primary activities during this quarter include (1) refinement of the input/output lists, (2) procurement of the distributed digital control system, (3) configuration training, and (4) revision of schedule to accommodate project approval cycle and change in unit outage dates.

  8. CO₂ Capture Membrane Process for Power Plant Flue Gas

    SciTech Connect (OSTI)

    Toy, Lora; Kataria, Atish; Gupta, Raghubir

    2012-04-01

    Because the fleet of coal-fired power plants is of such importance to the nation's energy production while also being the single largest emitter of CO₂, the development of retrofit, post-combustion CO₂ capture technologies for existing and new, upcoming coal power plants will allow coal to remain a major component of the U.S. energy mix while mitigating global warming. Post-combustion carbon capture technologies are an attractive option for coal-fired power plants as they do not require modification of major power-plant infrastructures, such as fuel processing, boiler, and steam-turbine subsystems. In this project, the overall objective was to develop an advanced, hollow-fiber, polymeric membrane process that could be cost-effectively retrofitted into current pulverized coal-fired power plants to capture at least 90% of the CO₂ from plant flue gas with 95% captured CO₂ purity. The approach for this project tackled the technology development on three different fronts in parallel: membrane materials R&D, hollow-fiber membrane module development, and process development and engineering. The project team consisted of RTI (prime) and two industrial partners, Arkema, Inc. and Generon IGS, Inc. Two CO₂-selective membrane polymer platforms were targeted for development in this project. For the near term, a next-generation, high-flux polycarbonate membrane platform was spun into hollow-fiber membranes that were fabricated into both lab-scale and larger prototype (~2,200 ft²) membrane modules. For the long term, a new fluoropolymer membrane platform based on poly(vinylidene fluoride) [PVDF] chemistry was developed using a copolymer approach as improved capture membrane materials with superior chemical resistance to flue-gas contaminants (moisture, SO₂, NOx, etc.). Specific objectives were: - Development of new, highly chemically resistant, fluorinated polymers as membrane materials with minimum selectivity of 30 for CO₂ over N₂ and CO₂ permeance

  9. Avoiding 100 New Power Plants by Increasing Efficiency of Room Air Conditioners in India: Opportunities and Challenges

    SciTech Connect (OSTI)

    Phadke, Amol; Abhyankar, Nikit; Shah, Nihar

    2014-06-19

    Electricity demand for room ACs is growing very rapidly in emerging economies such as India. We estimate the electricity demand from room ACs in 2030 in India considering factors such as weather and income growth using market data on penetration of ACs in different income classes and climatic regions. We discuss the status of the current standards, labels, and incentive programs to improve the efficiency of room ACs in these markets and assess the potential for further large improvements in efficiency and find that efficiency can be improved by over 40percent cost effectively. The total potential energy savings from Room AC efficiency improvement in India using the best available technology will reach over 118 TWh in 2030; potential peak demand saving is found to be 60 GW by 2030. This is equivalent to avoiding 120 new coal fired power plants of 500 MW each. We discuss policy options to complement, expand and improve the ongoing programs to capture this large potential.

  10. Avoiding 100 new power plants by increasing efficiency of room air conditioners in India: opportunities and challenges

    SciTech Connect (OSTI)

    Phadke, Amol; Abhyankar, Nikit; Shah, Nihar

    2013-10-15

    Electricity demand for room ACs is growing very rapidly in emerging economies such as India. We estimate the electricity demand from room ACs in 2030 in India considering factors such as weather and income growth using market data on penetration of ACs in different income classes and climatic regions. We discuss the status of the current standards, labels, and incentive programs to improve the efficiency of room ACs in these markets and assess the potential for further large improvements in efficiency and find that efficiency can be improved by over 40% cost effectively. The total potential energy savings from Room AC efficiency improvement in India using the best available technology will reach over 118 TWh in 2030; potential peak demand saving is found to be 60 GW by 2030. This is equivalent to avoiding 120 new coal fired power plants of 500 MW each. We discuss policy options to complement, expand and improve the ongoing programs to capture this large potential.

  11. Mansfield Municipal Electric Department - Residential Energy...

    Office of Energy Efficiency and Renewable Energy (EERE) (indexed site)

    dehumidifiers, and window air conditioners. The offer is limited to a total of 100 worth of ENERGY STAR appliance rebates per customer account for appliances purchased in the...

  12. Mansfield, Massachusetts: Energy Resources | Open Energy Information

    Open Energy Information (Open El) [EERE & EIA]

    Massachusetts: Energy Resources Jump to: navigation, search Equivalent URI DBpedia Coordinates 42.0334326, -71.2189405 Show Map Loading map... "minzoom":false,"mappingservice"...

  13. Scoping Comment Summary 092412.docx

    National Nuclear Security Administration (NNSA)

    ... about the nuclear power industry Support for other energy sources, such as biodiesel, solar, wind, and geothermal Concerns about emissions from coal-fired power ...

  14. Coal - U.S. Energy Information Administration (EIA)

    Annual Energy Outlook

    Stocks Imports, exports & distribution Coal-fired electric power plants Transportation costs to electric power sector International All coal data reports Analysis & Projections ...

  15. Advanced Combustion

    U.S. Department of Energy (DOE) all webpages (Extended Search)

    Advanced Combustion Background Conventional coal-fired power plants utilize steam turbines to ... development of large-scale Ni-based superalloy castings for power plant applications. ...

  16. ccpi | netl.doe.gov

    U.S. Department of Energy (DOE) all webpages (Extended Search)

    advanced, clean, efficient coal-based power systems. ... while one existing power plant will be retrofitted with ... on Three 90-MW Coal-Fired Boilers (Complete) Western ...

  17. bib-greenidge | netl.doe.gov

    U.S. Department of Energy (DOE) all webpages (Extended Search)

    ... for Reducing Emissions from Smaller Coal-Fired Power Plants, Paper PDF-600KB; ... PDF-1.7 MB (Aug 2008) Power Plant Air Pollutant Control "MEGA" Symposium, ...

  18. an Illinois Coal-Fired Plant Pavlish, John; Thompson, Jeffrey...

    Office of Scientific and Technical Information (OSTI)

    limits for hydrochloric acid than the reference method. Results from a dry stack unit had better comparability between methods than results from a wet stack unit. This...

  19. Emissions of air toxics from coal-fired boilers: Arsenic

    SciTech Connect (OSTI)

    Mendelsohn, M.H.; Huang, H.S.; Livengood, C.D.

    1994-08-01

    Concerns over emissions of hazardous air pollutants (air toxics) have emerged as a major environmental issue; the authority of the US Environmental Protection Agency to regulate such pollutants has been greatly expanded through passage of the Clean Air Act Amendments of 1990. Arsenic and arsenic compounds are of concern mainly because of their generally recognized toxicity. Arsenic is also regarded as one of the trace elements in coal subject to significant vaporization. This report summarizes and evaluates available published information on the arsenic content of coals mined in the United States, on arsenic emitted in coal combustion, and on the efficacy of various environmental control technologies for controlling airborne emissions. Bituminous and lignite coals have the highest mean arsenic concentrations, with subbituminous and anthracite coals having the lowest. However, all coal types show very significant variations in arsenic concentrations. Arsenic emissions from coal combustion are not well-characterized, particularly with regard to determination of specific arsenic compounds. Variations in emission, rates of more than an order of magnitude have been reported for some boiler types. Data on the capture of arsenic by environmental control technologies are available primarily for systems with cold electrostatic precipitators, where removals of approximately 50 to 98% have been reported. Limited data for wet flue-gas-desulfurization systems show widely varying removals of from 6 to 97%. On the other hand, waste incineration plants report removals in a narrow range of from 95 to 99%. This report briefly reviews several areas of research that may lead to improvements in arsenic control for existing flue-gas-cleanup technologies and summarizes the status of analytical techniques for measuring arsenic emissions from combustion sources.

  20. Emissions of airborne toxics from coal-fired boilers: Mercury

    SciTech Connect (OSTI)

    Huang, H.S.; Livengood, C.D.; Zaromb, S.

    1991-09-01

    Concerns over emissions of hazardous air Pollutants (air toxics) have emerged as a major environmental issue, and the authority of the US Environmental Protection Agency to regulate such pollutants was greatly expanded through the Clean Air Act Amendments of 1990. Mercury has been singled out for particular attention because of concerns over possible effects of emissions on human health. This report evaluates available published information on the mercury content of coals mined in the United States, on mercury emitted in coal combustion, and on the efficacy of various environmental control technologies for controlling airborne emissions. Anthracite and bituminous coals have the highest mean-mercury concentrations, with subbituminous coals having the lowest. However, all coal types show very significant variations in mercury concentrations. Mercury emissions from coal combustion are not well-characterized, particularly with regard to determination of specific mercury compounds. Variations in emission rates of more than an order of magnitude have been reported for some boiler types. Data on the capture of mercury by environmental control technologies are available primarily for systems with electrostatic precipitators, where removals of approximately 20% to over 50% have been reported. Reported removals for wet flue-gas-desulfurization systems range between 35 and 95%, while spray-dryer/fabric-filter systems have given removals of 75 to 99% on municipal incinerators. In all cases, better data are needed before any definitive judgments can be made. This report briefly reviews several areas of research that may lead to improvements in mercury control for existing flue-gas-clean-up technologies and summarizes the status of techniques for measuring mercury emissions from combustion sources.

  1. Concept selection for advanced low-emission coal fired boiler

    SciTech Connect (OSTI)

    Gorrell, R.L.; Rodgers, L.W.; Farthing, G.A.

    1993-12-31

    The Babcock & Wilcox Company (B&W), under contract to the US Department of Energy (DOE) with subcontract to Physical Sciences, Inc. (PSIT), the Massachusetts Institute of Technology (MIT) and United Engineers and Constructors (UE&C) has begun development of an advanced low-emission boiler system (LEBS). The initial phase of this multi-phase program required a thorough review and assessment of potential advanced technologies and techniques for control of combustion and flue gas emissions. Results of this assessment are presented in this paper.

  2. NOx CONTROL OPTIONS AND INTEGRATION FOR US COAL FIRED BOILERS

    SciTech Connect (OSTI)

    Mike Bockelie; Marc Cremer; Kevin Davis; Bob Hurt; Eric Eddings

    2001-01-31

    This is the second Quarterly Technical Report for DOE Cooperative Agreement No: DE-FC26-00NT40753. The goal of the project is to develop cost effective analysis tools and techniques for demonstrating and evaluating low NOx control strategies and their possible impact on boiler performance for firing US coals. The focus of our efforts during the last three months have been on: (1) Completion of a long term field test for Rich Reagent Injection (RRI) at the Conectiv BL England Station Unit No.1, a 130 MW Cyclone fired boiler; (2) Extending our Computational Fluid Dynamics (CFD) based NOx model to accommodate the chemistry for RRI in PC fired boilers; (3) Design improvements and calibration tests of the corrosion probe; and (4) Investigations on ammonia adsorption mechanisms and removal processes for Fly Ash.

  3. NREL: Energy Analysis - Coal-Fired Electricity Generation Results...

    U.S. Department of Energy (DOE) all webpages (Extended Search)

    gasification combine cycle (IGCC), fluidized bed (FB), and supercritical pulverized coal-combustion technologies), NREL developed and applied a systematic approach to review life ...

  4. Advanced coal-fired glass melting development program

    SciTech Connect (OSTI)

    Not Available

    1991-05-01

    The objective of Phase 1 of the current contract was to verify the technical feasibility and economic benefits of Vortec's advanced combustion/melting technology using coal as the fuel of choice. The objective of the Phase 2 effort was to improve the performance of the primary components and demonstrate the effective operation of a subscale process heater system integrated with a glass separator/reservoir. (VC)

  5. Novel Surface Modification Method for Ultrasupercritical Coal-Fired Boilers

    SciTech Connect (OSTI)

    Xiao, T. Danny

    2013-05-22

    US Department of Energy seeks an innovative coating technology for energy production to reduce the emission of SOx, NOx, and CO2 toxic gaseous species. To realize this need, Inframat Corporation (â??IMCâ?) proposed an SPS thermal spray coating technique to produce ultrafine/nanocoatings that can be deposited onto the surfaces of high temperature boiler tubes, so that higher temperatures of boiler operation becomes possible, leading to significantly reduced emission of toxic gaseous species. It should be noted that the original PI was Dr. Xinqing Ma, who after 1.5 year conducting this project left Inframat in December, 2008. Thus, the PI was transferred to Dr. Danny Xiao, who originally co-authored the proposal with Dr. Ma, in order to carry the project into a completion. Phase II Objectives: The proposed technology has the following attributes, including: (1). Dispersion of a nanoparticle or alloyed particle in a solvent to form a uniform slurry feedstock; (2). Feeding of the slurry feedstock into a thermal spray flame, followed by deposition of the slurry feedstock onto substrates to form tenacious nanocoatings; (3). High coating performance: including high bonding strength, and high temperature service life in the temperature range of 760oC/1400oF. Following the above premises, our past Phase I project has demonstrated the feasibility in small scale coatings on boiler substrates. The objective of this Phase II project was to focus on scale-up the already demonstrated Phase I work for the fabrication of SPS coatings that can satisfy DOEâ??s emission reduction goals for energy production operations. Specifically, they are: (1). Solving engineering problems to scale-up the SPS-HVOF delivery system to a prototype production sub-delivery system; (2). Produce ultrafine/nanocoatings using the scale-up prototype system; (3). Demonstrate the coated components using the scale-up device having superior properties. Proposed Phase II Tasks: In the original Phase II proposal, we have six (6) technical tasks plus one (1) reporting task, as described below: Task 1 â?? Scale-up and optimize the SPS process; Task 2 â?? Coating design and fabrication with desired microstructure; Task 3 â?? Evaluate microstructure and physical properties; Task 4 â?? Test performance of long-term corrosion and erosion; Task 5 â?? Test mechanical property and reliability; Task 6 â?? Coating of a prototype boiler tube for evaluation; Task 7 â?? Reporting task. To date, we have already completed all the technical tasks of 1 through 6. Major Phase II Achievements: In this four (4) year working period, Inframat had spent great effort to complete the proposed tasks. The project had been completed; the goals have been accomplished. Major achievements obtained include: (1). Developed a prototype scale-up slurry feedstock delivery system for thermal spray coatings; (2). Successfully coated high performance coatings using this scale-up slurry delivery system; (3). Commercial applications in energy efficiency and clean energy components have been developed using this newly fabricated slurry feedstock delivery system.

  6. Condensing economizers for small coal-fired boilers and furnaces

    SciTech Connect (OSTI)

    Butcher, T.A.; Litzke, W.

    1994-01-01

    Condensing economizers increase the thermal efficiency of boilers by recovering sensible and latent heat from exhaust gas. These economizers are currently being used commercially for this purpose in a wide range of applications. Performance is dependent upon application-specific factors affecting the utility of recovered heat. With the addition of a condensing economizer boiler efficiency improvements up to 10% are possible. Condensing economizers can also capture flue gas particulates. In this work, the potential use of condensing economizers for both efficiency improvement and control of particulate emissions from small, coal water slurry-fired boilers was evaluated. Analysis was done to predict heat transfer and particulate capture by mechanisms including: inertial impaction, interception, diffusion, thermophoretic forces, and condensation growth. Shell-and-tube geometries were considered with flue gas on the outside of Teflon-covered tubes. Experimental studies were done with both air- and water-cooled economizers refit to a small boiler. Two experimental arrangements were used including oil-firing with injection of flyash upstream of the economizer and direct coal water slurry firing. Firing rates ranged from 27 to 82 kW (92,000 to 280,000 Btu/hr). Inertial impaction was found to be the most important particulate capture mechanism and removal efficiencies to 95% were achieved. With the addition of water sprays directly on the first row of tubes, removal efficiencies increased to 98%. Use of these sprays adversely affects heat recovery. Primary benefits of the sprays are seen to be the addition of small impaction sites and future design improvements are suggested in which such small impactors are permanently added to the highest velocity regions of the economizer. Predicted effects of these added impactors on particulate removal and pressure drop are presented.

  7. Power Systems Development Facility Gasification Test Campaign TC22

    SciTech Connect (OSTI)

    Southern Company Services

    2008-11-01

    In support of technology development to utilize coal for efficient, affordable, and environmentally clean power generation, the Power Systems Development Facility (PSDF), located in Wilsonville, Alabama, routinely demonstrates gasification technologies using various types of coals. The PSDF is an engineering scale demonstration of key features of advanced coal-fired power systems, including a KBR Transport Gasifier, a hot gas particulate control device, advanced syngas cleanup systems, and high-pressure solids handling systems. This report summarizes the results of TC22, the first test campaign using a high moisture lignite from Mississippi as the feedstock in the modified Transport Gasifier configuration. TC22 was conducted from March 24 to April 17, 2007. The gasification process was operated for 543 hours, increasing the total gasification operation at the PSDF to over 10,000 hours. The PSDF gasification process was operated in air-blown mode with a total of about 1,080 tons of coal. Coal feeder operation was challenging due to the high as-received moisture content of the lignite, but adjustments to the feeder operating parameters reduced the frequency of coal feeder trips. Gasifier operation was stable, and carbon conversions as high as 98.9 percent were demonstrated. Operation of the PCD and other support equipment such as the recycle gas compressor and ash removal systems operated reliably.

  8. Power Systems Development Facility Gasification Test Campaing TC18

    SciTech Connect (OSTI)

    Southern Company Services

    2005-08-31

    In support of technology development to utilize coal for efficient, affordable, and environmentally clean power generation, the Power Systems Development Facility (PSDF) located in Wilsonville, Alabama, routinely demonstrates gasification technologies using various types of coals. The PSDF is an engineering scale demonstration of key features of advanced coal-fired power systems, including a KBR Transport Gasifier, a hot gas particulate control device (PCD), advanced syngas cleanup systems, and high pressure solids handling systems. This report details Test Campaign TC18 of the PSDF gasification process. Test campaign TC18 began on June 23, 2005, and ended on August 22, 2005, with the gasifier train accumulating 1,342 hours of operation using Powder River Basin (PRB) subbituminous coal. Some of the testing conducted included commissioning of a new recycle syngas compressor for gasifier aeration, evaluation of PCD filter elements and failsafes, testing of gas cleanup technologies, and further evaluation of solids handling equipment. At the conclusion of TC18, the PSDF gasification process had been operated for more than 7,750 hours.

  9. Definitional mission report: NAPCOR thermal-power-conversion project, Philippines. Export trade information

    SciTech Connect (OSTI)

    Not Available

    1991-11-01

    The National Power Corporation (NAPCOR) of Philippines has requested the Trade and Development Program (TDP) to fund a study to evaluate the technical and economic feasibility of converting its existing oil and coal fired power plants to natural gas. The decision to undertake the study resulted from preliminary information on a large gas find off the coast of Palawan island. However, a second exploration well has come up dry. Now, the conversion of the existing power plants to natural gas seems very questionable. Even if the proven gas reserves prove to be commercially viable, the gas will not be available until 1998 or later for utilization. At that time several of NAPCOR's plants would have aged further, the political and economic situation in Philippines could have altered significantly, possibly improved, private power companies might be able to use the gas more efficiently by building state-of-the-art combined cycle power plants which will make more economic sense than converting existing old boilers to natural gas. In addition, most of the existing power equipment was manufactured by Japanese and/or European firms. It makes sense for NAPCOR to solicit services from these firms if it decides to go ahead with the implementation of the power plant conversion project. The potential for any follow on work for U.S. businesses is minimal to zero in the thermal conversion project. Therefore, at this time, TDP funding for the feasibility would be premature and not recommended.

  10. Solar-Augment Potential of U.S. Fossil-Fired Power Plants

    SciTech Connect (OSTI)

    Turchi, C.; Langle, N.; Bedilion, R.; Libby, C.

    2011-02-01

    Concentrating Solar Power (CSP) systems utilize solar thermal energy for the generation of electric power. This attribute makes it relatively easy to integrate CSP systems with fossil-fired power plants. The 'solar-augment' of fossil power plants offers a lower cost and lower risk alternative to stand-alone solar plant construction. This study ranked the potential to add solar thermal energy to coal-fired and natural gas combined cycle (NGCC) plants found throughout 16 states in the southeast and southwest United States. Each generating unit was ranked in six categories to create an overall score ranging from Excellent to Not Considered. Separate analysis was performed for parabolic trough and power tower technologies due to the difference in the steam temperatures that each can generate. The study found a potential for over 11 GWe of parabolic trough and over 21 GWe of power tower capacity. Power towers offer more capacity and higher quality integration due to the greater steam temperatures that can be achieved. The best sites were in the sunny southwest, but all states had at least one site that ranked Good for augmentation.

  11. AMERICAN ELECTRIC POWER'S CONESVILLE POWER PLANT UNIT NO.5 CO2 CAPTURE RETROFIT STUDY

    SciTech Connect (OSTI)

    Carl R. Bozzuto; Nsakala ya Nsakala; Gregory N. Liljedahl; Mark Palkes; John L. Marion

    2001-06-30

    ALSTOM Power Inc.'s Power Plant Laboratories (ALSTOM) has teamed with American Electric Power (AEP), ABB Lummus Global Inc. (ABB), the US Department of Energy National Energy Technology Laboratory (DOE NETL), and the Ohio Coal Development Office (OCDO) to conduct a comprehensive study evaluating the technical feasibility and economics of alternate CO{sub 2} capture and sequestration technologies applied to an existing US coal-fired electric generation power plant. The motivation for this study was to provide input to potential US electric utility actions concerning GHG emissions reduction. If the US decides to reduce CO{sub 2} emissions, action would need to be taken to address existing power plants. Although fuel switching from coal to natural gas may be one scenario, it will not necessarily be a sufficient measure and some form of CO{sub 2} capture for use or disposal may also be required. The output of this CO{sub 2} capture study will enhance the public's understanding of control options and influence decisions and actions by government, regulators, and power plant owners in considering the costs of reducing greenhouse gas CO{sub 2} emissions. The total work breakdown structure is encompassed within three major reports, namely: (1) Literature Survey, (2) AEP's Conesville Unit No.5 Retrofit Study, and (3) Bench-Scale Testing and CFD Evaluation. The report on the literature survey results was issued earlier by Bozzuto, et al. (2000). Reports entitled ''AEP's Conesville Unit No.5 Retrofit Study'' and ''Bench-Scale Testing and CFD Evaluation'' are provided as companion volumes, denoted Volumes I and II, respectively, of the final report. The work performed, results obtained, and conclusions and recommendations derived therefrom are summarized.

  12. Transport Membrane Condenser for Water and Energy Recovery from Power Plant Flue Gas

    SciTech Connect (OSTI)

    Dexin Wang

    2012-03-31

    The new waste heat and water recovery technology based on a nanoporous ceramic membrane vapor separation mechanism has been developed for power plant flue gas application. The recovered water vapor and its latent heat from the flue gas can increase the power plant boiler efficiency and reduce water consumption. This report describes the development of the Transport Membrane Condenser (TMC) technology in details for power plant flue gas application. The two-stage TMC design can achieve maximum heat and water recovery based on practical power plant flue gas and cooling water stream conditions. And the report includes: Two-stage TMC water and heat recovery system design based on potential host power plant coal fired flue gas conditions; Membrane performance optimization process based on the flue gas conditions, heat sink conditions, and water and heat transport rate requirement; Pilot-Scale Unit design, fabrication and performance validation test results. Laboratory test results showed the TMC system can exact significant amount of vapor and heat from the flue gases. The recovered water has been tested and proved of good quality, and the impact of SO{sub 2} in the flue gas on the membrane has been evaluated. The TMC pilot-scale system has been field tested with a slip stream of flue gas in a power plant to prove its long term real world operation performance. A TMC scale-up design approach has been investigated and an economic analysis of applying the technology has been performed.

  13. Coal gasification for power generation. 2nd ed.

    SciTech Connect (OSTI)

    2006-10-15

    The report gives an overview of the opportunities for coal gasification in the power generation industry. It provides a concise look at the challenges faced by coal-fired generation, the ability of coal gasification to address these challenges, and the current state of IGCC power generation. Topics covered in the report include: An overview of coal generation including its history, the current market environment, and the status of coal gasification; A description of gasification technology including processes and systems; An analysis of the key business factors that are driving increased interest in coal gasification; An analysis of the barriers that are hindering the implementation of coal gasification projects; A discussion of Integrated Gasification Combined Cycle (IGCC) technology; An evaluation of IGCC versus other generation technologies; A discussion of IGCC project development options; A discussion of the key government initiatives supporting IGCC development; Profiles of the key gasification technology companies participating in the IGCC market; and A description of existing and planned coal IGCC projects.

  14. Regional Partner Announces Plans for Carbon Storage Project Using CO2

    Office of Energy Efficiency and Renewable Energy (EERE) (indexed site)

    Captured from Coal-Fired Power Plant | Department of Energy Regional Partner Announces Plans for Carbon Storage Project Using CO2 Captured from Coal-Fired Power Plant Regional Partner Announces Plans for Carbon Storage Project Using CO2 Captured from Coal-Fired Power Plant July 20, 2009 - 1:00pm Addthis Washington, DC - Southern Company and the Southeast Regional Carbon Sequestration Partnership (SECARB), one of seven members of the U.S. Department of Energy (DOE) Regional Carbon

  15. Quantity, quality, and availability of waste heat from United States thermal power generation

    DOE PAGES-Beta [OSTI]

    Gingerich, Daniel B; Mauter, Meagan S

    2015-06-10

    Secondary application of unconverted heat produced during electric power generation has the potential to improve the life-cycle fuel efficiency of the electric power industry and the sectors it serves. This work quantifies the residual heat (also known as waste heat) generated by U.S. thermal power plants and assesses the intermittency and transport issues that must be considered when planning to utilize this heat. Combining Energy Information Administration plant-level data with literature-reported process efficiency data, we develop estimates of the unconverted heat flux from individual U.S. thermal power plants in 2012. Together these power plants discharged an estimated 18.9 billion GJthmoreof residual heat in 2012, 4% of which was discharged at temperatures greater than 90 C. We also characterize the temperature, spatial distribution, and temporal availability of this residual heat at the plant level and model the implications for the technical and economic feasibility of its end use. Increased implementation of flue gas desulfurization technologies at coal-fired facilities and the higher quality heat generated in the exhaust of natural gas fuel cycles are expected to increase the availability of residual heat generated by 10.6% in 2040.less

  16. FMI NewCoal | Open Energy Information

    Open Energy Information (Open El) [EERE & EIA]

    developer focused on upgrading low rank coals to improve combustion efficiency and reduce production of greenhouse emissions for coal fired utility and industrial power generation...

  17. New Membrane Technology for Post-Combustion Carbon Capture Begins...

    Office of Environmental Management (EM)

    research portfolio and has the potential to support the reduction of greenhouse gas emissions from coal-fired power plants while minimizing the increase in electricity price. ...

  18. An Analysis of the Economic Impact on Utah County, Utah from...

    WindExchange

    from wind turbines than it is to buy "standard" electricity from gas- or coal- fired generation units (Smith 2005). Because wind power's cost is derived primarily during the...

  19. NREL: Energy Analysis - Stuart Cohen

    U.S. Department of Energy (DOE) all webpages (Extended Search)

    operation at retrofitted coal-fired power plants in the Texas and Great Britain electric grids." ... Full list of Stuart Cohen publications (NREL) Personal interestshobbies Running, ...

  20. "Title","Creator/Author","Publication Date","OSTI Identifier...

    Office of Scientific and Technical Information (OSTI)

    the preliminary economic viability of a COsub 2-sequestering system integrated with a coal-fired power plant based on microalgae biofixation. A review of relevant literature was...

  1. TITLE AUTHORS SUBJECT SUBJECT RELATED DESCRIPTION PUBLISHER AVAILABILI...

    Office of Scientific and Technical Information (OSTI)

    the preliminary economic viability of a CO sub sequestering system integrated with a coal fired power plant based on microalgae biofixation A review of relevant literature was...

  2. Carbon Dioxide Sequestering Using Microalgal Systems Daniel J...

    Office of Scientific and Technical Information (OSTI)

    the preliminary economic viability of a COsub 2-sequestering system integrated with a coal-fired power plant based on microalgae biofixation. A review of relevant literature was...

  3. DOE Seeks Projects to Advance Carbon Dioxide Utilization from...

    Office of Environmental Management (EM)

    ... with integrating biological CO2 utilization processes with coal-fired power plants. ... and chemicals while significantly reducing energy demand for the conversion process. ...

  4. Stanford Synchrotron Radiation Lightsource

    U.S. Department of Energy (DOE) all webpages (Extended Search)

    Quantification of the Mercury Adsorption Mechanism on Brominated Activated Carbon August 2013 SSRL Science Summary by Manuel Gnida Figure Emissions from coal-fired power plants are...

  5. Cerion Energy Inc | Open Energy Information

    Open Energy Information (Open El) [EERE & EIA]

    develops nano-particles that enhance the fuel efficiency and decrease emissions of combustion engines and coal fired power plants. References: Cerion Energy Inc.1 This article...

  6. Zolo Technologies Inc | Open Energy Information

    Open Energy Information (Open El) [EERE & EIA]

    to improve the efficiency and reduce harmful emission, including GHG's, from large combustion sources such as coal-fired power plants and gas turbines. References: Zolo...

  7. Microsoft Word - Department of Energy Coal Solicitation 9-22...

    Energy Savers

    ... example, coal-fired electrical plants or biomass facilities), including those by other ... POWER GENERATION AND INDUSTRIAL GASIFICATION FACILITIES THAT INCORPORATE CARBON ...

  8. Fiber-Optic Sensor for Industrial Process Measurement and Control...

    Office of Energy Efficiency and Renewable Energy (EERE) (indexed site)

    generation of solid-fuel vehicles, and in leak detection for pharmaceutical production. ... in coal-fired power plants by precisely controlling furnace temperature and startups. ...

  9. Functional Materials

    U.S. Department of Energy (DOE) all webpages (Extended Search)

    Testing of materials under ideal and realistic process conditions such as those found in coal-fired power plant and integrated gasification combined cycle fuel gas. Performance ...

  10. PlaneCarbon | Open Energy Information

    Open Energy Information (Open El) [EERE & EIA]

    drive our cars or fly in an airplane or simply using electricity generated by coal fired power plants. These activities are increasing the levels of certain naturally occurring...

  11. Cleantech: Innovative Lab Partnership Reduces Emissions from Coal

    Energy.gov [DOE]

    Learn how the National Energy Technology Laboratory is working to reduce the emission of pollutants from existing coal-fired power plants.

  12. Search for: All records | SciTech Connect

    Office of Scientific and Technical Information (OSTI)

    (MEST) Method at an Illinois Coal-Fired Plant Pavlish, John ; Thompson, Jeffrey ; ... methods were conducted at two power plant units fueled by Illinois Basin bituminous coal. ...

  13. FlueGen Inc | Open Energy Information

    Open Energy Information (Open El) [EERE & EIA]

    California Zip: 92614 Product: Irvine-based original equipment manufacturer (OEM) of air pollution control systems for the utility industry, including coal-fired power plants,...

  14. Coalogix Inc | Open Energy Information

    Open Energy Information (Open El) [EERE & EIA]

    Product: US-based company that provides selective catalyst reduction services to coal-fired power plants. Coordinates: 35.2225, -80.837539 Show Map Loading map......

  15. --No Title--

    Annual Energy Outlook

    retirements jeffery jonesMichael Leff Release Date: 42814 In 2012, coal-fired and nuclear power plants together provided 56% of the electricity generated in the United...

  16. Vice President Biden Announces Recovery Act Funding for 37 Transformat...

    Energy.gov (indexed) [DOE]

    more affordable; and remove the carbon pollution from coal-fired power plants in a more ... growth while helping to cut carbon pollution dramatically," said Secretary Chu. "I ...

  17. Comments on Emergency Order to Resume Limited Operation at the...

    Office of Environmental Management (EM)

    on decreasing the negative effects of global warming by promoting clean energy alternatives and ensuring proper regulation of coal-fired power plants in Maryland, DC and Virginia. ...

  18. FACT SHEET: Clean Coal University Research Awards and Project...

    Energy.gov (indexed) [DOE]

    (AUSC) coal-fired power plants improve generation efficiency, use less coal and ... Compared with current thermal barrier coatings, pyrochlore oxides have ...

  19. How Solar Works | Department of Energy

    Energy.gov (indexed) [DOE]

    Carbon Capture Works 34 likes Carbon capture, utilization and storage is a process that captures carbon dioxide emissions from sources like coal-fired power plants and either...

  20. Department of Energy Formally Commits $1 Billion in Recovery...

    Office of Energy Efficiency and Renewable Energy (EERE) (indexed site)

    innovative technologies for reducing carbon emissions from existing coal-fired power plants. ... The Ameren Energy Resources team estimates that the retrofitting of the plant is ...

  1. DOE's Carbon Sequestration Partnership Program Adds Canadian...

    Office of Energy Efficiency and Renewable Energy (EERE) (indexed site)

    The partnerships provide a critical link to the Administration's plans for FutureGen, a highly efficient and technologically sophisticated coal-fired power plant that will produce ...

  2. baepgac-healy | netl.doe.gov

    U.S. Department of Energy (DOE) all webpages (Extended Search)

    ... Coal Conference, Pittsburgh, PA Reaching an Agreement to Build a New Coal-Fired Power Plant Near a National Park by Mitigating Potential Environmental Impacts (Sept 1994) ...

  3. index | netl.doe.gov

    U.S. Department of Energy (DOE) all webpages (Extended Search)

    of pollutant emissions from today's coal-fired power plants and to obtain a realistic ... address policy questions regarding coal plant emissions and provide guidance for future ...

  4. FINDING OF NO SIGNIFICANT IMPACT

    U.S. Department of Energy (DOE) all webpages (Extended Search)

    Plant Improvement Initiative, which targeted new technologies having potential for improving the environmental performance, power generation, and reliability of coal-fired ...

  5. Advanced Combustion Systems Project Information | netl.doe.gov

    U.S. Department of Energy (DOE) all webpages (Extended Search)

    and Scale-up for New and Retrofit Coal-fired Power Plants Gas Technology Institute ... Turbine Combined Cycle for Improved Plant Efficiency University of Kentucky ...

  6. bcpcfcp-selfscrub | netl.doe.gov

    U.S. Department of Energy (DOE) all webpages (Extended Search)

    Power Plant Performance Improvement (Apr 1994) R.L. Godfrey (Custom Coals Corporation), Plzen Proceedings: Conference on Alternatives for Pollution Control from Coal-Fired Low ...

  7. sub-ambient-membrane | netl.doe.gov

    U.S. Department of Energy (DOE) all webpages (Extended Search)

    Meeting, Pittsburgh, PA CO2 Capture by Cold Membrane Operation with Actual Coal Fired Power Plant Flue Gas PDF (June 2015) Presented by Trapti Chaubey, Air Liquide, Inc., ...

  8. Carbon Sequestration Conference | Department of Energy

    Energy Savers

    ... viable biofuels from a variety of plant sources, including agricultural waste products. ... Coal-fired power plants being built today are over 90% cleaner in emissions of particulate ...

  9. materials | netl.doe.gov

    U.S. Department of Energy (DOE) all webpages (Extended Search)

    Materials for Advanced Steam Cycles Materials for Ultra-Supercritical Coal-Fired Power Plant Boilers R. Viswanathan, EPRI Presentation Coal Ash Corrosion Resistant Materials ...

  10. bib-aggregate | netl.doe.gov

    U.S. Department of Energy (DOE) all webpages (Extended Search)

    PDF-60KB entitled "New Recycling Technology to be Tested At Virginia Coal-Fired Power Plant" (Jan 2003) Environmental Reports Finding of No Significant Impact: Commercial ...

  11. Remote-site power generation opportunities for Alaska

    SciTech Connect (OSTI)

    Jones, M.L.

    1997-03-01

    The Energy and Environmental Research Center (EERC) has been working with the Federal Energy Technology Center in Morgantown, West Virginia, to assess options for small, low-cost, environmental acceptable power generation for application in remote areas of Alaska. The goal of this activity was to reduce the use of fuel in Alaskan villages by developing small, low-cost power generation applications. Because of the abundance of high-quality coal throughout Alaska, emphasis was placed on clean coal applications, but other energy sources, including geothermal, wind, hydro, and coalbed methane, were also considered. The use of indigenous energy sources would provide cheaper cleaner power, reduce the need for PCE (Power Cost Equalization program) subsidies, increase self-sufficiency, and retain hard currency in the state while at the same time creating jobs in the region. The introduction of economical, small power generation systems into Alaska by US equipment suppliers and technology developers aided by the EERC would create the opportunities for these companies to learn how to engineer, package, transport, finance, and operate small systems in remote locations. All of this experience would put the US developers and equipment supply companies in an excellent position to export similar types of small power systems to rural areas or developing countries. Thus activities in this task that relate to determining the generic suitability of these technologies for other countries can increase US competitiveness and help US companies sell these technologies in foreign countries, increasing the number of US jobs. The bulk of this report is contained in the two appendices: Small alternative power workshop, topical report and Global market assessment of coalbed methane, fluidized-bed combustion, and coal-fired diesel technologies in remote applications.

  12. Chlorine induced corrosion of steels in fossil fuel power plants

    SciTech Connect (OSTI)

    Spiegel, M.; Grabke, H.J.

    1998-12-31

    The corrosion of steels in power plants (coal combustion, waste incineration) is mainly due to condensed chlorides in the ash deposited on the boiler tubes. These chlorides are stabilized by HCl in the combustion gas. In the case of coal as a fuel, chlorine is present as chloride minerals in the raw material which is converted to HCl during the combustion process. Corrosion of steels in chlorine containing environments occurs by the active oxidation mechanism, which is a self-sustaining accelerated oxidation process, catalyzed by chlorine. This study shows that solid chlorides react with the oxide scale of the steels to form chlorine, which initiates active oxidation. In order to prevent chlorine induced corrosion, the deposition of chlorides on the tubes within the coal ash must be avoided. This is possible by the presence of SO{sub 2}, which is present in the combustion gas, converting the chlorides to sulfates in the gas phase. The paper presents an example of a failure case in a coal fired plant in Germany. In this plant, chlorine induced corrosion was observed after effective removal of SO{sub 2} by additions of CaO. From thermodynamic calculations it can be shown that a certain amount of SO{sub 2} is necessary in order to avoid deposition of chlorides and to prevent corrosion.

  13. Impact of fuel properties on advanced power systems

    SciTech Connect (OSTI)

    Sondreal, E.A.; Jones, M.L.; Hurley, J.P.; Benson, S.A.; Willson, W.G.

    1995-12-01

    Advanced coal-fired combined-cycle power systems currently in development and demonstration have the goal of increasing generating efficiency to a level approaching 50% while reducing the cost of electricity from new plants by 20% and meeting stringent standards on emissions of SO{sub x} NO{sub x} fine particulates, and air toxic metals. Achieving these benefits requires that clean hot gas be delivered to a gas turbine at a temperature approaching 1350{degrees}C, while minimizing energy losses in the gasification, combustion, heat transfer, and/or gas cleaning equipment used to generate the hot gas. Minimizing capital cost also requires that the different stages of the system be integrated as simply and compactly as possible. Second-generation technologies including integrated gasification combined cycle (IGCC), pressurized fluidized-bed combustion (PFBC), externally fired combined cycle (EFCC), and other advanced combustion systems rely on different high-temperature combinations of heat exchange, gas filtration, and sulfur capture to meet these requirements. This paper describes the various properties of lignite and brown coals.

  14. Progress Towards Commercialization of Electrochemical Membrane Technology for CO2 Capture and Power Generation

    SciTech Connect (OSTI)

    Ghezel-Ayagh, Hossein; Jolly, Stephen; DiNitto, M.; Hunt, Jennifer; Patel, Dilip; Steen, William A.; Richardson, C. F.; Marina, Olga A.; Pederson, Larry R.

    2014-03-01

    To address the concerns about climate change resulting from emission of CO2 by coal-fueled power plants, FuelCell Energy, Inc. has developed Combined Electric Power and Carbon-dioxide Separation (CEPACS) system concept, as a novel solution for greenhouse gas emission reduction. The CEPACS system utilizes Electrochemical Membrane (ECM) technology derived from the Company’s well established Direct FuelCell® products. The system concept works as two devices in one: it separates the CO2 from the exhaust of other plants and simultaneously, using a supplementary fuel, produces electric power at high efficiency. FCE is currently evaluating the use of ECM to cost effectively separate CO2 from the flue gas of coal fired power plants under a U.S. Department of Energy contract. The overarching objective of the project is to verify that the ECM can achieve at least 90% CO2 capture from flue gas of a PC plant with no more than 35% increase in the cost of electricity. The specific objectives and related activities presently ongoing for the project include: 1) conduct bench scale tests of ECM and 2) evaluate the effects of impurities present in the coal plant flue gas by laboratory scale performance tests of the membrane.

  15. Tampa Electric Company Polk Power Station IGCC project: Project status

    SciTech Connect (OSTI)

    McDaniel, J.E.; Carlson, M.R.; Hurd, R.; Pless, D.E.; Grant, M.D.

    1997-12-31

    The Tampa Electric Company Polk Power Station is a nominal 250 MW (net) Integrated Gasification Combined Cycle (IGCC) power plant located to the southeast of Tampa, Florida in Polk County, Florida. This project is being partially funded under the Department of Energy`s Clean Coal Technology Program pursuant to a Round II award. The Polk Power Station uses oxygen-blown, entrained-flow IGCC technology licensed from Texaco Development Corporation to demonstrate significant reductions of SO{sub 2} and NO{sub x} emissions when compared to existing and future conventional coal-fired power plants. In addition, this project demonstrates the technical feasibility of commercial scale IGCC and Hot Gas Clean Up (HGCU) technology. The Polk Power Station achieved ``first fire`` of the gasification system on schedule in mid-July, 1996. Since that time, significant advances have occurred in the operation of the entire IGCC train. This paper addresses the operating experiences which occurred in the start-up and shakedown phase of the plant. Also, with the plant being declared in commercial operation as of September 30, 1996, the paper discusses the challenges encountered in the early phases of commercial operation. Finally, the future plans for improving the reliability and efficiency of the Unit in the first quarter of 1997 and beyond, as well as plans for future alternate fuel test burns, are detailed. The presentation features an up-to-the-minute update on actual performance parameters achieved by the Polk Power Station. These parameters include overall Unit capacity, heat rate, and availability. In addition, the current status of the start-up activities for the HGCU portion of the plant is discussed.

  16. REDUCING POWER PRODUCTION COSTS BY UTILIZING PETROLEUM COKE

    SciTech Connect (OSTI)

    Kevin C. Galbreath; Donald L. Toman; Christopher J. Zygarlicke

    1999-09-01

    Petroleum coke, a byproduct of the petroleum-refining process, is an attractive primary or supplemental fuel for power production primarily because of a progressive and predictable increase in the production volumes of petroleum coke (1, 2). Petroleum coke is most commonly blended with coal in proportions suitable to meet sulfur emission compliance. Petroleum coke is generally less reactive than coal; therefore, the cofiring of petroleum coke with coal typically improves ignition, flame stability, and carbon loss relative to the combustion of petroleum coke alone. Although petroleum coke is a desirable fuel for producing relatively inexpensive electrical power, concerns about the effects of petroleum coke blending on combustion and pollution control processes exist in the coal-fired utility industry (3). The Energy & Environmental Research Center (EERC) completed a 2-year technical assessment of petroleum coke as a supplemental fuel. A survey questionnaire was sent to seven electric utility companies that are currently cofiring coal and petroleum coke in an effort to solicit specific suggestions on research needs and fuel selections. An example of the letter and survey questionnaire is presented in Appendix A. Interest was expressed by most utilities in evaluating the effects of petroleum coke blending on grindability, combustion reactivity, fouling, slagging, and fly ash emissions control. Unexpectedly, concern over corrosion was not expressed by the utilities contacted. Although all seven utilities responded to the question, only two utilities, Northern States Power Company (NSP) and Ameren, sent fuels to the EERC for evaluation. Both utilities sent subbituminous coals from the Power River Basin and petroleum shot coke samples. Petroleum shot coke is produced unintentionally during operational upsets in the petroleum refining process. This report evaluates the effects of petroleum shot coke blending on grindability, fuel reactivity, fouling/slagging, and

  17. Carbon pricing, nuclear power and electricity markets

    SciTech Connect (OSTI)

    Cameron, R.; Keppler, J. H.

    2012-07-01

    In 2010, the NEA in conjunction with the International Energy Agency produced an analysis of the Projected Costs of Electricity for almost 200 power plants, covering nuclear, fossil fuel and renewable electricity generation. That analysis used lifetime costs to consider the merits of each technology. However, the lifetime cost analysis is less applicable in liberalised markets and does not look specifically at the viewpoint of the private investor. A follow-up NEA assessment of the competitiveness of nuclear energy against coal- and gas-fired generation under carbon pricing has considered just this question. The economic competition in electricity markets is today between nuclear energy and gas-fired power generation, with coal-fired power generation not being competitive as soon as even modest carbon pricing is introduced. Whether nuclear energy or natural gas comes out ahead in their competition depends on a number of assumptions, which, while all entirely reasonable, yield very different outcomes. The analysis in this study has been developed on the basis of daily data from European power markets over the last five-year period. Three different methodologies, a Profit Analysis looking at historic returns over the past five years, an Investment Analysis projecting the conditions of the past five years over the lifetime of plants and a Carbon Tax Analysis (differentiating the Investment Analysis for different carbon prices) look at the issue of competitiveness from different angles. They show that the competitiveness of nuclear energy depends on a number of variables which in different configurations determine whether electricity produced from nuclear power or from CCGTs generates higher profits for its investors. These are overnight costs, financing costs, gas prices, carbon prices, profit margins (or mark-ups), the amount of coal with carbon capture and electricity prices. This paper will present the outcomes of the analysis in the context of a liberalised

  18. Opportunities for Combined Heat and Power in Data Centers

    SciTech Connect (OSTI)

    Darrow, Ken; Hedman, Bruce

    2009-03-01

    Data centers represent a rapidly growing and very energy intensive activity in commercial, educational, and government facilities. In the last five years the growth of this sector was the electric power equivalent to seven new coal-fired power plants. Data centers consume 1.5% of the total power in the U.S. Growth over the next five to ten years is expected to require a similar increase in power generation. This energy consumption is concentrated in buildings that are 10-40 times more energy intensive than a typical office building. The sheer size of the market, the concentrated energy consumption per facility, and the tendency of facilities to cluster in 'high-tech' centers all contribute to a potential power infrastructure crisis for the industry. Meeting the energy needs of data centers is a moving target. Computing power is advancing rapidly, which reduces the energy requirements for data centers. A lot of work is going into improving the computing power of servers and other processing equipment. However, this increase in computing power is increasing the power densities of this equipment. While fewer pieces of equipment may be needed to meet a given data processing load, the energy density of a facility designed to house this higher efficiency equipment will be as high as or higher than it is today. In other words, while the data center of the future may have the IT power of ten data centers of today, it is also going to have higher power requirements and higher power densities. This report analyzes the opportunities for CHP technologies to assist primary power in making the data center more cost-effective and energy efficient. Broader application of CHP will lower the demand for electricity from central stations and reduce the pressure on electric transmission and distribution infrastructure. This report is organized into the following sections: (1) Data Center Market Segmentation--the description of the overall size of the market, the size and types of

  19. MONITORING POWER PLANT EFFICIENCY USING THE MICROWAVE-EXCITED PHOTOACOUSTIC EFFECT TO MEASURE UNBURNED CARBON

    SciTech Connect (OSTI)

    Robert C. Brown; Robert J. Weber; Andrew A. Suby

    2002-05-13

    Three test instruments are being evaluated to determine the feasibility of using photo-acoustic technology for measuring unburned carbon in fly ash. The first test instrument is a single microwave frequency system previously constructed to measure photo-acoustic signals in an off-line configuration. This system was assembled and used to begin testing parameters thought to be influential in the resulting photo-acoustic signal output. A standard modulation frequency was chosen based upon signal to noise data gained from experimentation. Sample heterogeneity was tested and found not to be influential. Many other tests were performed during the second quarter. Preliminary results show that compression and photo-acoustic volume have an impact on photo-acoustic signal. Conclusions regarding the data for sample bulk density, temperature, humidity, moisture content, and linearity are pending further review. Conclusions for ambient temperature and humidity are pending further review as well. Simultaneously, a second instrument is to be constructed based in part on lessons learned with the first instrument, and to expand the capabilities of the first instrument. Improvements include a control loop to allow more constant microwave power output and an ability to operate over a range of microwave frequencies. To date, the design of the second instrument has been completed and most of the components received. The third instrument will be designed based on the experiences of the first two instruments and will operate in an on-line carbon-in-ash monitoring system for coal-fired power plants.

  20. Asthma in the vicinity of power stations: II. Outdoor air quality and symptoms

    SciTech Connect (OSTI)

    Henry, R.L.; Bridgman, H.A.; Wlodarczyk, J.; Abramson, R.; Adler, J.A.; Hensley, M.J. )

    1991-01-01

    To assess longitudinally the effect of living in the vicinity of coal-fired power stations on children with asthma, 99 schoolchildren with a history of wheezing in the previous 12 months were studied for 1 year, using daily diaries and measurements of air quality. The children had been identified in a cross-sectional survey of two coastal areas: Lake Munmorah (LM), within 5 km of two power stations, and Nelson Bay (NB), free from major industry. Daily air quality (sulphur dioxide (SO2) and nitrogen oxides (NOx)), respiratory symptoms, and treatment for asthma were recorded throughout the year. Measurements of SO2 and NOx at LM were well within recommended guidelines although they were several times higher than at NB: maximum daily levels in SO2 (micrograms/m3) were 26 at LM, 11 at NB (standard, 365); yearly average SO2 was 2 at LM, 0.3 at NB (standard, 60); yearly average NOx (micrograms/m3) was 2 at LM, 0.4 at NB (standard, 94). Marked weekly fluctuations occurred in the prevalence of cough, wheezing, and breathlessness, without any substantial differences between LM and NB. Overall, the prevalence of symptoms was low (10% for wheezing, 20% for any symptom). Whether the daily SO2 and NOx levels affected the occurrence of respiratory symptoms was investigated in children at LM using a logistic regression (Korn and Whittemore technique). For these children as a group, air quality measurements were not associated with the occurrence of symptoms.

  1. DB Riley-low emission boiler system (LEBS): Superior power for the 21st century

    SciTech Connect (OSTI)

    Beittel, R.; Ruth, L.A.

    1997-12-31

    In conjunction with the US Department of Energy, DB Riley, Inc., is developing a highly advanced coal-fired power-generation plant called the Low Emission Boiler Systems (LEBS). By the year 2000, LEBS will provide the US electric power industry with a reliable, efficient, cost-effective, environmentally superior alternative to current technologies. LEBS incorporates significant advances in coal combustion, supercritical steam boiler design, environmental control, and materials development. The system will include a state-of-the-art steam cycle operating at supercritical steam conditions; a slagging combustor that produces vitrified ash by-products; low nitrogen oxide (NOx) burners; a new, dry, regenerable flue gas cleanup system (copper oxide process) for simultaneously capturing sulfur dioxide (SO{sub 2}) and nitrogen oxides (NOx); a pulse-jet fabric filter for particulate capture; and a low-temperature heat-recovery system. The copper oxide flue gas cleanup system, which has been under development at DOE`s Pittsburgh field center, removes over 98% of SO{sub 2} and 95% of NOx from flue gas. A new moving-bed design provides efficient sorbent utilization that lowers the cleanup process cost. The captured SO{sub 2} can be converted to valuable by-products such as sulfuric acid and/or element sulfur, and the process generates no waste.

  2. Power Systems Development Facility Gasification Test Campaign TC25

    SciTech Connect (OSTI)

    Southern Company Services

    2008-12-01

    In support of technology development to utilize coal for efficient, affordable, and environmentally clean power generation, the Power Systems Development Facility (PSDF), located in Wilsonville, Alabama, routinely demonstrates gasification technologies using various types of coals. The PSDF is an engineering scale demonstration of key features of advanced coal-fired power systems, including a KBR Transport Gasifier, a hot gas particulate control device, advanced syngas cleanup systems, and high-pressure solids handling systems. This report summarizes the results of TC25, the second test campaign using a high moisture lignite coal from the Red Hills mine in Mississippi as the feedstock in the modified Transport Gasifier configuration. TC25 was conducted from July 4, 2008, through August 12, 2008. During TC25, the PSDF gasification process operated for 742 hours in air-blown gasification mode. Operation with the Mississippi lignite was significantly improved in TC25 compared to the previous test (TC22) with this fuel due to the addition of a fluid bed coal dryer. The new dryer was installed to dry coals with very high moisture contents for reliable coal feeding. The TC25 test campaign demonstrated steady operation with high carbon conversion and optimized performance of the coal handling and gasifier systems. Operation during TC25 provided the opportunity for further testing of instrumentation enhancements, hot gas filter materials, and advanced syngas cleanup technologies. The PSDF site was also made available for testing of the National Energy Technology Laboratory's fuel cell module and Media Process Technology's hydrogen selective membrane with syngas from the Transport Gasifier.

  3. Power Systems Development Facility Gasification Test Campaign TC24

    SciTech Connect (OSTI)

    Southern Company Services

    2008-03-30

    In support of technology development to utilize coal for efficient, affordable, and environmentally clean power generation, the Power Systems Development Facility (PSDF), located in Wilsonville, Alabama, routinely demonstrates gasification technologies using various types of coals. The PSDF is an engineering scale demonstration of key features of advanced coal-fired power systems, including a KBR Transport Gasifier, a hot gas particulate control device, advanced syngas cleanup systems, and high-pressure solids handling systems. This report summarizes the results of TC24, the first test campaign using a bituminous coal as the feedstock in the modified Transport Gasifier configuration. TC24 was conducted from February 16, 2008, through March 19, 2008. The PSDF gasification process operated for about 230 hours in air-blown gasification mode with about 225 tons of Utah bituminous coal feed. Operational challenges in gasifier operation were related to particle agglomeration, a large percentage of oversize coal particles, low overall gasifier solids collection efficiency, and refractory degradation in the gasifier solids collection unit. The carbon conversion and syngas heating values varied widely, with low values obtained during periods of low gasifier operating temperature. Despite the operating difficulties, several periods of steady state operation were achieved, which provided useful data for future testing. TC24 operation afforded the opportunity for testing of various types of technologies, including dry coal feeding with a developmental feeder, the Pressure Decoupled Advanced Coal (PDAC) feeder; evaluating a new hot gas filter element media configuration; and enhancing syngas cleanup with water-gas shift catalysts. During TC24, the PSDF site was also made available for testing of the National Energy Technology Laboratory's fuel cell module and Media Process Technology's hydrogen selective membrane.

  4. Utilization of municipal wastewater for cooling in thermoelectric power plants: Evaluation of the combined cost of makeup water treatment and increased condenser fouling

    SciTech Connect (OSTI)

    Walker, Michael E.; Theregowda, Ranjani B.; Safari, Iman; Abbasian, Javad; Arastoopour, Hamid; Dzombak, David A.; Hsieh, Ming-Kai; Miller, David C.

    2013-10-01

    A methodology is presented to calculate the total combined cost (TCC) of water sourcing, water treatment and condenser fouling in the recirculating cooling systems of thermoelectric power plants. The methodology is employed to evaluate the economic viability of using treated municipal wastewater (MWW) to replace the use of freshwater as makeup water to power plant cooling systems. Cost analyses are presented for a reference power plant and five different tertiary treatment scenarios to reduce the scaling tendencies of MWW. Results indicate that a 550 MW sub-critical coal fired power plant with a makeup water requirement of 29.3 ML/day has a TCC of $3.0 - 3.2 million/yr associated with the use of treated MWW for cooling. (All costs USD 2009). This translates to a freshwater conservation cost of $0.29/kL, which is considerably lower than that of dry air cooling technology, $1.5/kL, as well as the 2020 conservation cost target set by the U.S. Department of Energy, $0.74/kL. Results also show that if the available price of freshwater exceeds that of secondary-treated MWW by more than $0.13-0.14/kL, it can be economically advantageous to purchase secondary MWW and treat it for utilization in the recirculating cooling system of a thermoelectric power plant.

  5. In-country and lending institution environmental requirements for thermal power plants in the Philippines and India

    SciTech Connect (OSTI)

    Lehman, A.T.; Khanna, R.

    1996-11-01

    Diverse environmental reviews and approvals are required by both Government and non-government organizations (NGOs) for licensing or permitting of major thermal power plants in Asia; specifically, India and Philippines. The number and type of approvals required for a specific project vary depending on site characteristics, fuel source, project-specific design and operating parameters as well as type of project financing. A model 400 MW coal-fired project located in Asia is presented to illustrate the various lender and host country environmental guidelines. A case study of the environmental reviews and approvals for Ogden Quezon Power, Inc. Project (Quezon Province, Republic of the Philippines) is also included. A list of acronyms is provided at the paper`s end. As independent power project (IPP) developers seek financing for these capital-intensive infrastructure projects, a number of international finance/lending institutions are likely to become involved. Each lender considers different environmental aspects of a project. This paper compares relevant environmental requirements of various lenders which finance IPPs and their interest in a project`s environmental review. Finally, the authors of this paper believe that the environmental review process can bring together many parties involved with IPP development, including local and central governments, non government organizations, various lenders (such as multilateral and export credit agencies) as well as project proponents. Environmental review provides input opportunity for interested and affected parties. Airing environmental issues in open forums such as public hearings or meetings helps ensure projects are not evaluated without public input.

  6. Health hazard evaluation report HETA-95-0393-2633, Clinch River Power Plant, Cleveland, Virginia

    SciTech Connect (OSTI)

    Mattorano, D.A.

    1997-05-01

    In response to a request fromm the Building and Construction Trades Department oof the AFL-CIO, an investigation was begun into possible exposures during rebuilding of coal fired boilers at the Clinch River Power Plant (SIC-4911), Cleveland, Virginia. During the sampling period, boilermakers removed secondary inlet and secondary outlet boiler elements and removed and replaced portions of the steel boiler casting, exposing them to fly ash and fumes from air arc gouging, welding, and torch cutting. Laborers maintained the walkways and prepared work areas using sweeping and vacuuming techniques, primarily exposing them to fly ash. The highest personal breathing zone (PBZ) air sample concentrations of arsenic, beryllium, cadmium, nickel, lead, and respirable dust occurred when boilermakers performed job tasks inside the boiler and outside the boiler on the steel boiler casing. Air arc gouging, welding, oxyacetylene torch cutting, or grinding on or near the scale greatly increased the potential for the generation of airborne particles. Cristobalite was found in one PBZ sampel at 0.03mg/m3. The author concludes that there appears to be a potential for a health hazard at job sites where similar activities take place. The author recommends lowering worker exposures through the use of engineering controls and improvements in housekeeping procedures.

  7. INTEGRATED SYSTEM TO CONTROL PRIMARY PM 2.5 FROM ELECTRIC POWER PLANTS

    SciTech Connect (OSTI)

    Unknown

    2000-10-01

    One of the major tasks of this project is to design and fabricate an Advanced ElectroCore field prototype system. The system is designed to handle 5,000 acfm of exhaust gas from a coal-fired power plant. The system consists of the Advanced ElectroCore module, a water-cooled precharger and a dry scrubber. The system is shown in Figure 1. LSR has completed the design drawings for the ElectroCore module and the water-cooled precharger. The design drawings for the dry scrubber are nearly complete. Merrick Environmental Technology, Inc. has completed most of the fabrication drawings for the ElectroCore module and for the water-cooled precharger. From the original schedule, the design task (Task 2) should have been completed by 15 July 2000. It now looks like this task will be finished by mid-October thereby putting the project about two months behind schedule. Much of the delay is due to design changes that will make this field prototype easier to transport and erect. These changes will make the unit much more valuable as an ElectroCore system sales tool at the end of this project.

  8. Development of Self-Powered Wireless-Ready High Temperature Electrochemical Sensors for In-Situ Corrosion Monitoring for Boiler Tubes in Next Generation Coal-based Power Systems

    SciTech Connect (OSTI)

    Liu, Xingbo

    2015-06-30

    The key innovation of this project is the synergy of the high temperature sensor technology based on the science of electrochemical measurement and state-of-the-art wireless communication technology. A novel self-powered wireless high temperature electrochemical sensor system has been developed for coal-fired boilers used for power generation. An initial prototype of the in-situ sensor demonstrated the capability of the wireless communication system in the laboratory and in a pilot plant (Industrial USC Boiler Setting) environment to acquire electrochemical potential and current signals during the corrosion process. Uniform and localized under-coal ash deposit corrosion behavior of Inconel 740 superalloy has been studied at different simulated coal ash hot corrosion environments using the developed sensor. Two typical potential noise patterns were found to correlate with the oxidation and sulfidation stages in the hot coal ash corrosion process. Two characteristic current noise patterns indicate the extent of the corrosion. There was a good correlation between the responses of electrochemical test data and the results from corroded surface analysis. Wireless electrochemical potential and current noise signals from a simulated coal ash hot corrosion process were concurrently transmitted and recorded. The results from the performance evaluation of the sensor confirm a high accuracy in the thermodynamic and kinetic response represented by the electrochemical noise and impedance test data.

  9. Mechanistic understanding of irradiation-induced corrosion of zirconium alloys in nuclear power plants: Stimuli, status, and outlook

    SciTech Connect (OSTI)

    Johnson, A.B. Jr.; Ishigure, K.; Nechaev, A.F.; Reznichenko, E.A.; Cox, B.; Lemaignan, C.; Petrik, N.G.

    1990-05-01

    Failures in the basic materials used in nuclear power plants continue to be costly and insidious, despite increasing industry vigilance to catch failures before they degrade safety. For instance, the overall costs to the US industry from materials problems could amount to as much as $10 billion annually. Moreover, estimates indicate that the cost of a pipe failure in a nuclear plant is one hundred times greater than the cost of a similar failure in a coal-fired plant. There are important practical stimuli and much scope for further understanding of the effects of irradiation on Zr-alloys (and other materials used in nuclear installations) by careful experimentation. Moreover, these studies need to address the effect of irradiation on all components of heterogeneous systems: the metal, the oxide and the environment, and especially those processes recurring at the interphases between these components. The present paper is aimed at providing specialists with some systematic information on the subject and with important considerations on the key items for further experimentation.

  10. TEM study of PM2.5 emitted from coal and tire combustion in a thermal power station

    SciTech Connect (OSTI)

    Reto Giere; Mark Blackford; Katherine Smith

    2006-10-15

    The research presented here was conducted within the scope of an experiment investigating technical feasibility and environmental impacts of tire combustion in a coal-fired power station. Previous work has shown that combustion of a coal + tire blend rather than pure coal increased bulk emissions of various elements (e.g., Zn, As, Sb, Pb). The aim of this study is to characterize the chemical and structural properties of emitted single particles with dimensions <2.5 {mu}m (PM2.5). This transmission electron microscope (TEM)-based study revealed that, in addition to phases typical of coal fly ash (e.g., aluminum-silicate glass, mullite), the emitted PM2.5 contains amorphous selenium particles and three types of crystalline metal sulfates never reported before from stack emissions. Anglesite, PbSO{sub 4}, is ubiquitous in the PM2.5 derived from both fuels and contains nearly all Pb present in the PM. Gunningite, ZnSO{sub 4}H{sub 2}O, is the main host for Zn and only occurs in the PM derived from the coal + tire blend, whereas yavapaiite, KFe{sup 3+}(SO{sub 4}){sub 2}, is present only when pure coal was combusted. It is concluded that these metal sulfates precipitated from the flue gas may be globally abundant aerosols and have, through hydration or dissolution, a major environmental and health impact. 66 refs., 2 figs., 1 tab.

  11. 06-2016 | netl.doe.gov

    U.S. Department of Energy (DOE) all webpages (Extended Search)

    AUSC power plants are high-efficiency, coal-fired power generation facilities. Compared to ... As a result, the amount of CO2 that must be captured from an AUSC power plant is lower ...

  12. NREL: Solar Research - News Release Archives

    U.S. Department of Energy (DOE) all webpages (Extended Search)

    ... First Hybrid CSP-Coal Power Plant is Fired Up in Colorado Concentrating solar power (CSP) is boosting the energy produced by a coal-fired power plant east of Grand Junction, ...

  13. environmental-control | netl.doe.gov

    U.S. Department of Energy (DOE) all webpages (Extended Search)

    Environmental Control Power Plant The Environmental Control ... an integral part of NETL's Coal and Power Systems RD&D ... the current fleet of coal-fired power plants to comply with ...

  14. Evolution of carbide precipitates in 2.25Cr-1Mo steel during long-term service in a power plant.

    SciTech Connect (OSTI)

    Yang, Y.; Chen, Y.; Sridharan, K.; Allen, T. R.; Nuclear Engineering Division; Univ. of Wisconsin at Madison

    2010-06-01

    Carbide precipitation from the steel matrix during long-term high-temperature exposure can adversely affect the fracture toughness and high-temperature creep resistance of materials with implications on the performance of power plant components. In the present work, carbide evolution in 2.25Cr-1Mo steel after long-term aging during service was investigated. Boiler pipe samples of this steel were removed from a supercritical water-cooled coal-fired power plant after service times of 17 and 28 years and a mean operational temperature of 810 K (537C). The carbide precipitation and coarsening effects were studied using the carbon extraction replica technique followed by analysis using transmission electron microscopy and energy dispersive X-ray spectroscopy. The carbides extracted using an electrolytic technique were also analyzed using X-ray diffraction to evaluate phase transformations of the carbides during long-term service. Small ball punch and Vickers hardness were used to evaluate the changes in mechanical performance after long-term aging during service.

  15. Low-power-loss bearings for electric utilities. Volume 3. Performance tables and design guidelines for thrust and journal bearings. Final report

    SciTech Connect (OSTI)

    Pinkus, O.; Wilcock, D.F.

    1985-06-01

    This is the third of a three volume final report on EPRI Research Project RP 1648-1, ''Low Power Loss Bearings for Electric Utilities.'' The objective of the research was to perform an analytical study into the potential for reducing bearing losses through optimization of both journal and thrust bearings. A preliminary economic study indicated that a reduction in bearing losses by 50% for a 500 MWe unit would result in a fuel savings of approximately $130,000/yr for coal fired and $330,000/yr for oil fired, in 1981 dollars. The third volume presents the tabular performance information, based on dimensionless parameters, which can serve as design guidelines and as the basis for estimating power loss, oil flow and temperature rise. The types of bearings covered are the tapered land and floating disc types of thrust bearing, and the circular three-pad, three-lobe and tilting-pad types of journal bearing. For each bearing type, the pertinent parameters and equations are given, the general performance is discussed, a suggested procedure for using the tables to obtain performance information is given, and numerical examples for a typical application are presented. 32 figs., 5 tabs.

  16. Flow simulation of the Component Development Integration Facility magnetohydrodynamic power train system

    SciTech Connect (OSTI)

    Chang, S.L.; Lottes, S.A.; Bouillard, J.X.; Petrick, M.

    1997-11-01

    This report covers application of Argonne National Laboratory`s (ANL`s) computer codes to simulation and analysis of components of the magnetohydrodynamic (MHD) power train system at the Component Development and Integration Facility (CDIF). Major components of the system include a 50-MWt coal-fired, two-stage combustor and an MHD channel. The combustor, designed and built by TRW, includes a deswirl section between the first and the second-stage combustor and a converging nozzle following the second-stage combustor, which connects to the MHD channel. ANL used computer codes to simulate and analyze flow characteristics in various components of the MHD system. The first-stage swirl combustor was deemed a mature technology and, therefore, was not included in the computer simulation. Several versions of the ICOMFLO computer code were used for the deswirl section and second-stage combustor. The MGMHD code, upgraded with a slag current leakage submodel, was used for the MHD channel. Whenever possible data from the test facilities were used to aid in calibrating parameters in the computer code, to validate the computer code, or to set base-case operating conditions for computations with the computer code. Extensive sensitivity and parametric studies were done on cold-flow mixing in the second-stage combustor, reacting flow in the second-stage combustor and converging nozzle, and particle-laden flow in the deswirl zone of the first-stage combustor, the second-stage combustor, and the converging nozzle. These simulations with subsequent analysis were able to show clearly in flow patterns and various computable measures of performance a number of sensitive and problematical areas in the design of the power train. The simulations of upstream components also provided inlet parameter profiles for simulation of the MHD power generating channel. 86 figs., 18 tabs.

  17. Scenarios for Deep Carbon Emission Reductions from Electricity by 2050 in Western North America using the Switch Electric Power Sector Planning Model: California's Carbon Challenge Phase II, Volume II

    SciTech Connect (OSTI)

    Nelson, James; Mileva, Ana; Johnston, Josiah; Kammen, Daniel; Wei, Max; Greenblatt, Jeffrey

    2014-01-01

    This study used a state-of-the-art planning model called SWITCH for the electric power system to investigate the evolution of the power systems of California and western North America from present-day to 2050 in the context of deep decarbonization of the economy. Researchers concluded that drastic power system carbon emission reductions were feasible by 2050 under a wide range of possible futures. The average cost of power in 2050 would range between $149 to $232 per megawatt hour across scenarios, a 21 to 88 percent increase relative to a business-as-usual scenario, and a 38 to 115 percent increase relative to the present-day cost of power. The power system would need to undergo sweeping change to rapidly decarbonize. Between present-day and 2030 the evolution of the Western Electricity Coordinating Council power system was dominated by implementing aggressive energy efficiency measures, installing renewable energy and gas-fired generation facilities and retiring coal-fired generation. Deploying wind, solar and geothermal power in the 2040 timeframe reduced power system emissions by displacing gas-fired generation. This trend continued for wind and solar in the 2050 timeframe but was accompanied by large amounts of new storage and long-distance high-voltage transmission capacity. Electricity storage was used primarily to move solar energy from the daytime into the night to charge electric vehicles and meet demand from electrified heating. Transmission capacity over the California border increased by 40 - 220 percent by 2050, implying that transmission siting, permitting, and regional cooperation will become increasingly important. California remained a net electricity importer in all scenarios investigated. Wind and solar power were key elements in power system decarbonization in 2050 if no new nuclear capacity was built. The amount of installed gas capacity remained relatively constant between present-day and 2050, although carbon capture and sequestration was

  18. Steam Turbine Materials for Ultrasupercritical Coal Power Plants

    SciTech Connect (OSTI)

    Viswanathan, R.; Hawk, J.; Schwant, R.; Saha, D.; Totemeier, T.; Goodstine, S.; McNally, M.; Allen, D. B.; Purgert, Robert

    2009-06-30

    The Ultrasupercritical (USC) Steam Turbine Materials Development Program is sponsored and funded by the U.S. Department of Energy and the Ohio Coal Development Office, through grants to Energy Industries of Ohio (EIO), a non-profit organization contracted to manage and direct the project. The program is co-funded by the General Electric Company, Alstom Power, Siemens Power Generation (formerly Siemens Westinghouse), and the Electric Power Research Institute, each organization having subcontracted with EIO and contributing teams of personnel to perform the requisite research. The program is focused on identifying, evaluating, and qualifying advanced alloys for utilization in coal-fired power plants that need to withstand steam turbine operating conditions up to 760°C (1400°F) and 35 MPa (5000 psi). For these conditions, components exposed to the highest temperatures and stresses will need to be constructed from nickel-based alloys with higher elevated temperature strength than the highchromium ferritic steels currently used in today's high-temperature steam turbines. In addition to the strength requirements, these alloys must also be weldable and resistant to environmental effects such as steam oxidation and solid particle erosion. In the present project, candidate materials with the required creep strength at desired temperatures have been identified. Coatings that can resist oxidation and solid particle erosion have also been identified. The ability to perform dissimilar welds between nickel base alloys and ferritic steels have been demonstrated, and the properties of the welds have been evaluated. Results of this three-year study that was completed in 2009 are described in this final report. Additional work is being planned and will commence in 2009. The specific objectives of the future studies will include conducting more detailed evaluations of the weld-ability, mechanical properties and repair-ability of the selected candidate alloys for rotors, casings

  19. Town of Mansfield, Massachusetts (Utility Company) | Open Energy...

    Open Energy Information (Open El) [EERE & EIA]

    Phone Number: 508-261-7361 Website: www.mansfieldelectric.com Twitter: @mansfieldma Facebook: https:www.facebook.comtownofmansfield Outage Hotline: 508-261-7300...

  20. NREL: Photovoltaics Research - Lorelle Mansfield, Ph.D.

    U.S. Department of Energy (DOE) all webpages (Extended Search)

    Early in her graduate career, she fabricated and tested CdTe thin-film solar cells at CSM. Her final dissertation project was conducted at the National Institute of Standards and ...

  1. EIS-0284: Low-Emission Boiler System (LEBS) Proof-of-Concept System, Elkhart, Illinois

    Energy.gov [DOE]

    This EIS evaluates the potential environmental impacts of a proposal by Babcock Borsig Power to design, construct, and operate an advanced pulverized coal-fired power facility using a low emission...

  2. Projects Aimed at Advancing State-of-the-Art Carbon Capture from...

    U.S. Department of Energy (DOE) all webpages (Extended Search)

    reducing power sector CO2 emissions because it can be added to existing plants... Technology for CO2 Capture from Coal-Fired Power Plant Flue ... integration methods for the capture ...

  3. Eskom Holdings Limited | Open Energy Information

    Open Energy Information (Open El) [EERE & EIA]

    including the largest coal-fired power station in the world as well as the Koeberg nuclear power station. Coordinates: -26.107894, 28.053755 Show Map Loading map......

  4. 10-27-09_Final_Testimony_(Chu).pdf

    Office of Energy Efficiency and Renewable Energy (EERE) (indexed site)

    own a power company and are considering building more generating capacity. Building a new coal-fired power plant or a new nuclear plant is a serious, multi-billion dollar...

  5. dry-regen | netl.doe.gov

    U.S. Department of Energy (DOE) all webpages (Extended Search)

    for CO2 Removal from Flue Gas of Existing Coal-Fired Power Plants PDF-475KB (Aug 2008) Technical paper presented at the Power Plant Air Pollutant Control "Mega" Symposium, ...

  6. sc0006378 | netl.doe.gov

    U.S. Department of Energy (DOE) all webpages (Extended Search)

    Process for Carbon Capture in Existing Coal-Fired Power Plants Project No.: DE-SC0006378 In ... low-quality energy from the power plant, which is typically released into the ...

  7. News Item

    U.S. Department of Energy (DOE) all webpages (Extended Search)

    and lower cost means to one day remove carbon dioxide (CO2) from coal-fired power plants. ... these scrubbers would consume about one-third of the energy generated by a power plant. ...

  8. AFGE Local 3824 Professional | Department of Energy

    Energy Savers

    WAPA also markets power from the Navajo Generating Station coal-fired plant near Page, AZ. WAPA sells power to preference customers such as Federal and state agencies, cities and ...

  9. CO2 Compression | netl.doe.gov

    U.S. Department of Energy (DOE) all webpages (Extended Search)

    compressor with interstage cooling that required an auxiliary load of approximately 7.5 percent of the gross power output of a subcritical pressure, coal-fired power plant. ...

  10. IBEW Government Coordinating Council (GCC) No. 1 | Department...

    Energy.gov (indexed) [DOE]

    WAPA also markets power from the Navajo Generating Station coal-fired plant near Page, AZ. WAPA sells power to preference customers such as Federal and state agencies, cities and ...

  11. WAPA AFGE Local 3807 Non Professional | Department of Energy

    Office of Environmental Management (EM)

    WAPA also markets power from the Navajo Generating Station coal-fired plant near Page, AZ. WAPA sells power to preference customers such as Federal and state agencies, cities and ...

  12. Department of Energy Finalizes $96.8 Million Loan Guarantee for...

    Office of Environmental Management (EM)

    Unlike coal-fired and natural gas-fired power generation plants, geothermal plants produce ... world's largest wind farm, and the nation's first nuclear power plant in three decades. ...

  13. 2008 Feature Stories | NREL

    U.S. Department of Energy (DOE) all webpages (Extended Search)

    ... Wind, Solar, Gas, Coal? Models Help Communities Decide What's better to build - a new coal-fired power plant, a wind farm or a solar power plant? For communities and industries ...

  14. Secretary Chu, Senator Reid Announce Department of Energy Conditional...

    Energy Savers

    Unlike coal-fired and natural gas-fired power generation plants, geothermal plants produce ... largest wind farm and the nation's first new nuclear power plant in three decades. ...

  15. A Potential Path to Emissions-Free Fossil Energy | Department...

    Energy Savers

    At most coal fired power plants, the coal is mixed with air so that it can burn. When it ... Utility to Purchase Low-Carbon Power from Innovative Clean Coal Plant A Potential Path ...

  16. Department of Energy Finalizes $96.8 Million Loan Guarantee for...

    Energy Savers

    ... Unlike coal-fired and natural gas-fired power generation plants, geothermal plants produce ... world's largest wind farm, and the nation's first nuclear power plant in three decades. ...

  17. Carbon Dioxide Capture at a Reduced Cost - Energy Innovation...

    U.S. Department of Energy (DOE) all webpages (Extended Search)

    This expense is estimated to equal about 25%-35% of the power produced from an existing coal-fired power plant using MEA. The new Berkeley Lab system greatly decreases this expense ...

  18. Discussion on Carbon Capture and Sequestration Legislation |...

    Office of Energy Efficiency and Renewable Energy (EERE) (indexed site)

    ... the efficiency of both existing and new coal-fired power generation plants, and 4) ... is pursuing R&D to increase base power plant efficiency and thereby reduce the amount ...

  19. Bioethanol Co-Location Study: August 15, 2000 - February 28, 2002

    SciTech Connect (OSTI)

    Morris, G.

    2002-11-01

    This report describes the results of an analysis of the generic economic feasibility of co-locating ethanol production facilities with California biomass power plants, and with coal-fired power plants in the Southwest.

  20. Secretary Chu Announces Up to $55 Million in Funding to Develop Advanced

    Office of Energy Efficiency and Renewable Energy (EERE) (indexed site)

    Carbon Capture Technology at Existing Coal-Fired Power Plants | Department of Energy Up to $55 Million in Funding to Develop Advanced Carbon Capture Technology at Existing Coal-Fired Power Plants Secretary Chu Announces Up to $55 Million in Funding to Develop Advanced Carbon Capture Technology at Existing Coal-Fired Power Plants October 13, 2009 - 12:00am Addthis Washington, DC - U.S. Energy Secretary Steven Chu announced today that $55 million will be made available to develop advanced

  1. FE's Advanced Combustion R&D Seeks Innovative Ways to Lower Cost of

    Office of Energy Efficiency and Renewable Energy (EERE) (indexed site)

    Capturing Carbon Emissions from Coal Fired Power Plants | Department of Energy Advanced Combustion R&D Seeks Innovative Ways to Lower Cost of Capturing Carbon Emissions from Coal Fired Power Plants FE's Advanced Combustion R&D Seeks Innovative Ways to Lower Cost of Capturing Carbon Emissions from Coal Fired Power Plants March 27, 2014 - 10:37am Addthis Learn more about the FE Advanced Combustion R&D. You've probably heard about carbon capture and storage (CCS), a suite of

  2. IMPACCT: Carbon Capture Technology

    SciTech Connect (OSTI)

    2012-01-01

    IMPACCT Project: IMPACCT’s 15 projects seek to develop technologies for existing coal-fired power plants that will lower the cost of carbon capture. Short for “Innovative Materials and Processes for Advanced Carbon Capture Technologies,” the IMPACCT Project is geared toward minimizing the cost of removing carbon dioxide (CO2) from coal-fired power plant exhaust by developing materials and processes that have never before been considered for this application. Retrofitting coal-fired power plants to capture the CO2 they produce would enable greenhouse gas reductions without forcing these plants to close, shifting away from the inexpensive and abundant U.S. coal supply.

  3. Characteristics of inhalable particulate matter concentration and size distribution from power plants in China

    SciTech Connect (OSTI)

    Honghong Yi; Jiming Hao; Lei Duan; Xinghua Li; Xingming Guo

    2006-09-15

    The collection efficiency of particulate emission control devices (PECDs), particulate matter (PM) emissions, and PM size distribution were determined experimentally at the inlet and outlet of PECDs at five coal-fired power plants. Different boilers, coals, and PECDs are used in these power plants. Measurement in situ was performed by an electrical low-pressure impactor with a sampling system, which consisted of an isokinetic sampler probe, precut cyclone, and two- stage dilution system with a sample line to the instruments. The size distribution was measured over a range from 0.03 to 10 {mu}m. Before and after all of the PECDs, the particle number size distributions display a bimodal distribution. The PM2.5 fraction emitted to atmosphere includes a significant amount of the mass from the coarse particle mode. The controlled and uncontrolled emission factors of total PM, inhalable PM (PM10), and fine PM (PM2.5) were obtained. Electrostatic precipitator (ESP) and baghouse total collection efficiencies are 96.38 99.89% and 99.94%, respectively. The minimum collection efficiency of the ESP and the baghouse both appear in the particle size range of 0.1 1 0 {mu}m. In this size range, ESP and baghouse collection efficiencies are 85.79 98.6% and 99.54%. Real- time measurement shows that the mass and number concentration of PM10 will be greatly affected by the operating conditions of the PECDs. The number of emitted particles increases with increasing boiler load level because of higher combustion temperature. During test run periods, the data reproducibility is satisfactory. 19 refs., 11 figs., 6 tabs.

  4. MONITORING POWER PLANT EFFICIENCY USING THE MICROWAVE-EXCITED PHOTOACOUSTIC EFFECT TO MEASURE UNBURNED CARBON

    SciTech Connect (OSTI)

    Robert C. Brown; Robert J. Weber; Andrew A. Suby

    2002-07-01

    Three test instruments are being evaluated to determine the feasibility of using photo-acoustic technology for measuring unburned carbon in fly ash. The first test instrument is a single microwave frequency system previously constructed to measure photo-acoustic signals in an off-line configuration. This system was assembled and used to test parameters thought important to photo-acoustic signal output. A standard modulation frequency was chosen based upon signal to noise data gained from experimentation. Sample heterogeneity was tested and found not to be influential. Further testing showed that sample compression and photo-acoustic volume do affect photo-acoustic signal. Many tests were performed in the third quarter, which included the effects of ambient temperature and humidity, as well as sample moisture content, and signal linearity. Conclusions regarding the data for sample bulk density and temperature are pending further review and may require further testing. Simultaneously, a second instrument is being constructed based in part on lessons learned with the first instrument, but which also expands the capabilities of the first instrument. Improvements include a control loop to allow more constant microwave power output and an ability to operate over a range of microwave frequencies. To date, all of the components for the second instrument have been received and most of them tested with the exception of the broadband impedance transformers, as they will be incorporated into the second instrument test chamber. The third instrument will be designed based on the experiences of the first two instruments and will operate in an on-line carbon-in-ash monitoring system for coal-fired power plants.

  5. Low-power-loss bearings for electric utilities. Volume 2. Conceptual design and optimization of high-stability journal bearings. Final report

    SciTech Connect (OSTI)

    Pinkus, O.; Wilcock, D.F.

    1985-06-01

    This is the second of a three volume final report on EPRI Research Project RP1648-1, ''Low Power Loss Bearings for Electric Utilities.'' The objective of the research was to perform an analytical study into the potential for reducing bearing losses through optimization of both journal and thrust bearings. A preliminary economic study indicated that a reduction in bearing losses by 50% for a 500 MWe unit would result in a fuel savings of approximately $130,000/yr for coal fired and $330,000/yr for oil fired, in 1981 dollars. The second volume presents the conceptual design and optimization of high stability journal bearings. This volume treats designs which, unlike the circular designs, will remain stable over the entire range of eccentricities and which will retain their operational capabilities under both zero and rotating loads. Optimization studies in which preload, pad angle and mode of loading were varied in order to obtain the lowest (HP/load) ratios resulted in the formulation of optimized tilting-pad and 3-lobe designs. 4 refs., 32 figs., 31 tabs.

  6. Design and development of Stirling engines for stationary power generation applications in the 500 to 3000 horsepower range. Volume 1. Technical report

    SciTech Connect (OSTI)

    Not Available,

    1980-09-15

    This project was Phase I of a multiphased program for the design and development of Stirling engines for stationary power generation applications in the 500 to 3000 horsepower range. Phase I comprised the conceptual design and associated cost estimates of a stationary Stirling engine capable of being fueled by a variety of heat sources, with emphasis on coal firing, followed by the preparation of a plan for implementing the design, fabrication and testing of a demonstration engine by 1985. The development and evaluation of conceptual designs have been separated into two broad categories: the A designs which represent the present state-of-the-art and which are demonstrable by 1985 with minimum technical risk; and the B designs which involve advanced technology and therefore would require significant research and development prior to demonstration and commercialization, but which may ultimately offer advantages in terms of lower cost, better performance, or higher reliability. The majority of the effort in Phase I was devoted to the A designs.

  7. Electrochemical Membrane for Carbon Dioxide Separation and Power Generation

    SciTech Connect (OSTI)

    Jolly, Stephen; Ghezel-Ayagh, Hossein; Hunt, Jennifer; Patel, Dilip; Steen, William A.; Richardson, Carl F.; Marina, Olga A.

    2012-12-28

    uelCell Energy, Inc. (FCE) has developed a novel system concept for separation of carbon dioxide (CO2) from greenhouse gas (GHG) emission sources using an electrochemical membrane (ECM). The salient feature of the ECM is its capability to produce electric power while capturing CO2 from flue gas, such as from an existing pulverized coal (PC) plant. Laboratory scale testing of the ECM has verified the feasibility of the technology for CO2 separation from simulated flue gases of PC plants as well as combined cycle power plants and other industrial facilities. Recently, FCE was awarded a contract (DE-FE0007634) from the U.S. Department of Energy to evaluate the use of ECM to efficiently and cost effectively separate CO2 from the emissions of existing coal fired power plants. The overarching objective of the project is to verify that the ECM can achieve at least 90% CO2 capture from flue gas of an existing PC plant with no more than 35% increase in the cost of electricity (COE) produced by the plant. The specific objectives and related activities planned for the project include: 1) conduct bench scale tests of a planar membrane assembly consisting of ten or more cells of about 0.8 m2 area each, 2) develop the detailed design for an ECM-based CO2 capture system applied to an existing PC plant, and 3) evaluate the effects of impurities (pollutants such as SO2, NOx, Hg) present in the coal plant flue gas by conducting laboratory scale performance tests of the membrane. The results of this project are anticipated to demonstrate that the ECM is an advanced technology, fabricated from inexpensive materials, based on proven operational track records, modular, scalable to large sizes, and a viable candidate for >90% carbon capture from existing PC plants. In this paper, the fundamentals of ECM technology including: material of construction, principal mechanisms of operation, carbon capture test results and the benefits of applications to PC plants will be presented.

  8. Control of SO{sub 2} and NOx emissions from fossil fuel-fired power plants: Research and practice of TPRI

    SciTech Connect (OSTI)

    Ming-Chuan Zhang

    1993-12-31

    The generation of electric power in China has been dominated by coal for many years. By the end of 1990, total installed generating capacity reached 135 GW, of which fossil fuel-fired plants accounted for 74 percent. The total electricity generated reached 615 TWh, with fossil fuels accounting for 80.5 percent. About 276 million tons of raw coal are consumed in these fossil fuel-burning units per year, accounting for about 25 percent of the total output of the country. According to the government, by the year 2000, the total installed capacity of Chinese power systems should be at least 240 GW, of which fossil fuels will account for about 77 percent. The coal required for power generation will increase to about 530 million tons per year, accounting for about 38 percent of the total coal output. So, it is obvious that coal consumed in coal-fired power plants occupies a very important place in the national fuel balance. The current environmental protection standards, which are based on ground-level concentrations of pollutants, do not effectively lead to the control of pollution emission concentrations or total SO{sub 2} emissions. Due to the practical limitations of the Chinese economy, there is a limited capability to introduce advanced sulfur emission control technologies. Thus, except for the two 360 MW units imported from Japan for the Luohuang Power Plant in Shichuan province, all the other fossil fuel-fired units have not yet adopted any kind of SO{sub 2} removal measures. The Luohuang units are equipped with Mitsubishi limestone flue gas desulfurization systems. Because of the lack of effective pollution control technologies, large areas of the country have been seriously polluted by SO{sub 2}, and some of them even by acid rain.

  9. June 2014 Most Viewed Documents for Fossil Fuels | OSTI, US Dept...

    Office of Scientific and Technical Information (OSTI)

    Cycle Assessment of Coal-fired Power Production Spath, P. L.; Mann, M. K.; Kerr, D. R. (1999) 27 Life cycle inventory of biodiesel and petroleum diesel for use in an urban bus. ...

  10. Microsoft Word - JHP-Subtask 4.27-Sep14

    Office of Scientific and Technical Information (OSTI)

    METHOD AT AN ILLINOIS COAL-FIRED PLANT ABSTRACT Owners of fossil fuel-fired power plants face the challenge of ... TABLE OF CONTENTS LIST OF FIG U R E S......

  11. Novel Sorbent Achieves 90 Percent Carbon Capture in DOE-Sponsored Test

    Office of Energy Efficiency and Renewable Energy (EERE)

    The successful bench-scale test of a novel carbon dioxide capturing sorbent promises to further advance the process as a possible technological option for reducing CO2 emissions from coal-fired power plants.

  12. Department of Energy Announces $41 Million Investment for Carbon Capture Development

    Office of Energy Efficiency and Renewable Energy (EERE)

    The U.S. Department of Energy announced today the selection of 16 projects aimed at developing advanced post-combustion technologies for capturing carbon dioxide from coal-fired power plants.

  13. Annual Report: Carbon Capture (30 September 2012) (Technical...

    Office of Scientific and Technical Information (OSTI)

    of the COsub 2 produced from an existing coal-fired power plant with less than a 35% ... and efficient capture of COsub 2 from coal-based processes, and ultimately assess the ...

  14. How Carbon Capture Works | Department of Energy

    Energy.gov (indexed) [DOE]

    -- is a process that captures carbon dioxide emissions from sources like coal-fired power plants and either reuses or stores it so it will not enter the atmosphere. We'll...

  15. Lawrence Berkeley National Laboratory (LBNL) Feed | Open Energy...

    Open Energy Information (Open El) [EERE & EIA]

    discovered a means by which the removal of carbon dioxide (CO2) from coal-fired power plants might one day be done far more efficiently and at far lower costs than today. By...

  16. double-action | netl.doe.gov

    U.S. Department of Energy (DOE) all webpages (Extended Search)

    Current methods of CO2 post-combustion recovery from coal-fired power plants focus on such techniques as absorption in aqueous ethanolamine scrubbers - and this is now a mature ...

  17. sorbent-tda-research | netl.doe.gov

    U.S. Department of Energy (DOE) all webpages (Extended Search)

    A Low-Cost, High-Capacity Regenerable Sorbent for CO2 Capture From Existing Coal-Fired Power Plants Project No.: DE-FE0007580 TDA Research, Inc is developing a low cost, high...

  18. Presenting a New (and Cool) Appliance Efficiency Standard | Department...

    Energy Savers

    capacity by 2043 - the equivalent to 8-9 coal-fired power plants nationwide - and the ... products, which will cumulatively save consumers between 250 billion and 300 billion ...

  19. 1

    U.S. Department of Energy (DOE) all webpages (Extended Search)

    Implementing CO 2 capture in coal-fired power plants could result in almost a doubling of electricity prices for consumers. The researchers examined near-term market-viable ...

  20. Evaluating a new approach to CO2 capture and storage

    U.S. Department of Energy (DOE) all webpages (Extended Search)

    Implementing CO2 capture in coal-fired power plants could result in almost a doubling of electricity prices for consumers. The researchers examined near-term market-viable ...

  1. bectso-ct121 | netl.doe.gov

    U.S. Department of Energy (DOE) all webpages (Extended Search)

    A Study of Toxic Emissions from a Coal-Fired Power Plant Utilizing an ESP while ... Testing at Low-Particulate Loading With ESP In Service PDF-4.5 MB ((May 1995) ...

  2. Systems and economic analysis of microalgae ponds for conversion of CO{sub 2} to biomass. Quarterly technical progress report, September 1993--December 1993

    SciTech Connect (OSTI)

    Benemann, J.R.; Oswald, W.J.

    1994-01-15

    This report provides an economic analysis and feasibility study for the utilization by microalgal systems of carbon dioxide generated from coal-fired power plants. The resulting biomass could be a fuel substitute for fossil fuels.

  3. Developments in European Thermal Energy Systems | GE Global Research

    U.S. Department of Energy (DOE) all webpages (Extended Search)

    Possibly the most important question is, will natural gas fracking be allowed in Germany? ... when it comes to energy with major investments in coal-fired power plants of 24 ...

  4. Analysis of Alternative Mercury Control Strategies

    Reports and Publications

    2005-01-01

    This analysis responds to a September 14, 2004, request from Chairmen James M. Inhofe and George V. Voinovich asking the Energy Information Administration (EIA) to analyze the impacts of different approaches for removing mercury from coal-fired power plants.

  5. Status of Energy in Nevada

    National Nuclear Security Administration (NNSA)

    ... proposed to build a 1,500 MW coal-fired power plant (2, 750 MW units) located ... The Nevada Division of Environmental Protection (NDEP) released a draft air quality permit ...

  6. New Computer Codes Unlock the Secrets of Cleaner Burning Coal

    U.S. Department of Energy (DOE) all webpages (Extended Search)

    ... Cleaner Coal through Gasification In a traditional coal-fired power plant, coal undergoes combustion in a boiler to turn water into steam. This steam pressure then drives turbine ...

  7. Fuel Cell Stacks Still Going Strong After 5,000 Hours | Department...

    Office of Energy Efficiency and Renewable Energy (EERE) (indexed site)

    ... higher than today's average U.S.-based coal-fired power plant--while separating at least 90 percent of the carbon dioxide emissions for capture and environmentally secure storage. ...

  8. DOE-Sponsored Project Begins Demonstrating CCUS Technology in...

    Energy.gov (indexed) [DOE]

    ... Regional Partner Announces Plans for Carbon Storage Project Using CO2 Captured from Coal-Fired Power Plant Alabama Project Testing Potential for Combining CO2 Storage with Enhanced ...

  9. VanDoc_135908_1

    U.S. Department of Energy (DOE) all webpages (Extended Search)

    ... Market for New Coal Power Plant Technology 0 50 100 150 200 250 300 350 400 2000 2005 2010 2015 2020 2025 2030 2035 2040 2045 2050 Coal-Fired Plant Capacity (GW) EIA Projected Coal ...

  10. SHERATON STATION SQUARE FLOOR PLAN FIRST FLOOR

    U.S. Department of Energy (DOE) all webpages (Extended Search)

    ... Slipstream Pilot-Scale Demonstration of a Novel Amine-Based Post-Combustion Process Technology for CO 2 Capture from Coal-Fired Power Plant Flue Gas (FE0007453) Krish ...

  11. DOE-Supported Project Advances Clean Coal, Carbon Capture Technology...

    Office of Energy Efficiency and Renewable Energy (EERE) (indexed site)

    CO2 capture at less than 40 per metric ton--when integrated into a new or existing coal fired power plant. The successful test moves chemical-looping a step closer to full scale. ...

  12. Microsoft Word - Comments on Alexandria Mirant Plant-DOE order...

    Office of Energy Efficiency and Renewable Energy (EERE) (indexed site)

    sound", has created a plan that would allow a 1950s, Truman Era, coal-fired power plant to resume and continue operation in a populated, residential area of northern Virginia. ...

  13. ionic | netl.doe.gov

    U.S. Department of Energy (DOE) all webpages (Extended Search)

    of Notre Dame is developing a new ionic liquid absorbent and accompanying process that enables 90 percent of the post-combustion CO2 to be removed from a coal-fired power plant. ...

  14. Ultra-Thin Antifouling Surface Treatments for Industrial Heat...

    Office of Environmental Management (EM)

    9 9 9 Process Cost Economics Multi-Step One Step Transition and Deployment Coal Fired Power Plant, Fireside Fly Ash Corrosion Midwest Generation, Homer City, PA (still in ...

  15. Accomplishments - An Ongoing Endeavor | Department of Energy

    Office of Energy Efficiency and Renewable Energy (EERE) (indexed site)

    ... SRS replaced its 1950s-era coal-fired power plant with a renewable energy biomass facility that meets the sites energy demands, reduces greenhouse emissions, and creates jobs by ...

  16. Categorical Exclusion Determinations: Delaware | Department of...

    Office of Energy Efficiency and Renewable Energy (EERE) (indexed site)

    January 28, 2014 CX-011805: Categorical Exclusion Determination Carbon Dioxide Capture By Cold Membrane Operation with Actual Coal-Fired Power Plant Flue Gas CX(s) Applied: A1, A9, ...

  17. Department of Energy and FutureGen Alliance Discuss Next Steps...

    Energy Savers

    prepare future operators for careers in coal plant repowering, future CO2 pipeline networks, ... and storage from existing coal fired power plants in the U.S and around the world." ...

  18. Department of Energy Announces $41 Million Investment for Carbon...

    Energy Savers

    post-combustion technologies for capturing carbon dioxide (CO2) from coal-fired power plants. ... to no more than a 35 percent increase in the cost of electricity produced at the plant. ...

  19. Other Regulatory Efforts | Department of Energy

    U.S. Department of Energy (DOE) all webpages (Extended Search)

    Collecting and providing notice in the Federal Register when self certification for coal fired generation have been filed under Title II of the Power Plant and Industrial Fuel Use ...

  20. Carbon Capture and Storage FutureGen 2.0 Project Moves Forward...

    Office of Environmental Management (EM)

    In cooperation with the FutureGen project partners, the Department of Energy is investing in the upgrade of a coal-fired power plant in Meredosia, Ill. with oxy-combustion ...

  1. Search for: All records | SciTech Connect

    Office of Scientific and Technical Information (OSTI)

    ... (United States) Waste Isolation Pilot Plant (WIPP), Carlsbad, NM (United States) ... for capturing COsub 2 from existing coal-fired power plants can play a major role in the ...

  2. seca-workshop | netl.doe.gov

    U.S. Department of Energy (DOE) all webpages (Extended Search)

    on the Capital Cost and Effect of a Coal Fired Power Generation Unit PDF-227KB J. ... Balance of Plant R&D Dynamics Corporation PDF-5MB Giri Agrawal Innovative Concepts ...

  3. DOE Selects Eight Projects to Receive Funding for Reducing the...

    Office of Energy Efficiency and Renewable Energy (EERE) (indexed site)

    ... tonnes per day of CO2 with a 90 percent capture rate from existing coal-fired boilers at the Abbott Power Plant on the campus of the University of Illinois using LindeBASF's ...

  4. Post-Combustion CO2 Control | netl.doe.gov

    U.S. Department of Energy (DOE) all webpages (Extended Search)

    Testing of LindeBASF Post-Combustion CO2 Capture Technology at the Abbott Coal-Fired Power Plant University of Illinois FE0026588 Phase 1 - Large pilot-scale (25 MWe) Large ...

  5. research-education | netl.doe.gov

    U.S. Department of Energy (DOE) all webpages (Extended Search)

    DOE is partnering with the University of Cincinnati to conduct research and training on separating CO2 from post-combustion coal-fired power plant flue gases using regenerable ...

  6. fe0003311 | netl.doe.gov

    U.S. Department of Energy (DOE) all webpages (Extended Search)

    Petra Nova Parish Holdings, a joint venture between NRG Energy and JX Nippon Oil and Gas Exploration, will retrofit a CO2 capture plant on an existing coal-fired power plant (W.A. ...

  7. sensors | netl.doe.gov

    U.S. Department of Energy (DOE) all webpages (Extended Search)

    ... Note: Analysis based on 2011 coal costs and 2011 coal-fired power plant fleet 1Source: Outage Data - NERC GADS Database 91912 Accessed 1913; 55.07 Avg. Wholesale Price Data - ...

  8. Sulfur Resistant Electrodes for Zirconia Oxygen Sensors - Energy...

    U.S. Department of Energy (DOE) all webpages (Extended Search)

    oxide (Tb-YSZ) electrode have tested in a high-sulfur-coal fired power plant side by side against Zirconia-based O2 sensors with a standard platinum electrode. ...

  9. bectso-adflug | netl.doe.gov

    U.S. Department of Energy (DOE) all webpages (Extended Search)

    1994) Number 1 PDF-14.1MB (Oct 1993) Characterizing Toxic Emissions from a Coal-Fired Power Plant Demonstrating the AFGD ICCT Project and a Plant Utilizing a Dry Scrubber...

  10. membrane-process2 | netl.doe.gov

    U.S. Department of Energy (DOE) all webpages (Extended Search)

    of an approximately 1 ton of CO2 per day capacity membrane skid for use in a six-month pilot-scale field test using a slip-stream of flue gas from a coal-fired power plant. ...

  11. bectcom-snoxtm | netl.doe.gov

    U.S. Department of Energy (DOE) all webpages (Extended Search)

    Volume 1: Sampling ResultsSpecial Topics PDF-11.2MB Volume 2: Appendices PDF-14.6MB A Study of Toxic Emissions from a Coal-Fired Power Plant Niles Station Boiler No. 2, Final ...

  12. Recycling Energy Yields Super Savings | Department of Energy

    Energy.gov (indexed) [DOE]

    In 2013, with help from RED, the plant will capture its waste heat with dynamic results ... pollutants, yet it will generate power for less than the cost of new coal-fired generation. ...

  13. Microsoft Word - 2011sr09.doc

    U.S. Department of Energy (DOE) all webpages (Extended Search)

    ... special concrete used in reactor grouting; and the remediation of P and R Area Ash basins, which received coal-fired power plant ash and waste during the operation of the reactors. ...

  14. This document is to provide input for a probable future state...

    U.S. Department of Energy (DOE) all webpages (Extended Search)

    coal-fired generation. In addition, natural gas and coal prices will continue to rise, as will the cost of nuclear fuel. And the capital cost for new power plant ...

  15. sc0011885 | netl.doe.gov

    U.S. Department of Energy (DOE) all webpages (Extended Search)

    high capacity sorbent that will integrate into a hybrid membrane-sorbent post-combustion carbon capture system to remove carbon dioxide (CO2) from coal-fired power plant flue gas. ...

  16. ccpi-toxecon | netl.doe.gov

    U.S. Department of Energy (DOE) all webpages (Extended Search)

    TOXECON Retrofit for Mercury and Multi-Pollutant Control on Three 90 MW Coal-Fired Boilers - ...NOx Removal at the Presque Isle Power Plant PDF-1.1MB (Aug 2008) TOXECON Mercury ...

  17. UNITED STATES OF AMERICA BEFORE THE FEDERAL ENERGY REGULATORY...

    Office of Environmental Management (EM)

    ... The combined conditions occur infrequently, Mirant said. The coal-fired power plant, which began operation in 1949, produces 482 megawatts of electricity for Washington D.C. and ...

  18. biomimetric | netl.doe.gov

    U.S. Department of Energy (DOE) all webpages (Extended Search)

    low energy, carbon dioxide (CO2) capture system applicable to coal-fired power plant flue gas exhaust streams, while achieving an energy consumption target of less than 15 percent. ...

  19. 2015 CO2 Capture Technology Meeting | netl.doe.gov

    U.S. Department of Energy (DOE) all webpages (Extended Search)

    ... Wednesday, June 24, 2015 POST-COMBUSTION SOLVENT-BASED CAPTURE An Advanced Catalytic Solvent for Lower Cost Post-Combustion CO2 Capture in a Coal Fired Power Plant Cameron Lippert, ...

  20. Sandia National Laboratories:

    U.S. Department of Energy (DOE) all webpages (Extended Search)

    The CO2 Memzyme she helped develop captures carbon dioxide from coal-fired power plants and ... third of the energy the plant generates and requires large, high-pressure facilities. ...