Science.gov

Sample records for advanced coal-fired combined-cycle

  1. The development of Coke Carried-Heat Gasification Coal-Fired Combined Cycle

    NASA Astrophysics Data System (ADS)

    Zhao, Li; Xu, Xiangdong

    1999-12-01

    Carried-Heat Partial Gasification Combined cycle is a novel combined cycle which was proposed by Thermal Engineering Department of Tsinghua University in 1992. The idea of the system comes from the situation that the efficiency of the power plants in China is much lower than that of the advanced countries, but the coal consumption is much higher, which brings about the waste of primary energy resources and the pollution of the environment. With the deep study of the gasification technology, Coke Carried-Heat Gasification Coal-Fired Combined Cycle, as the improved system, came into birth in 1996 based on the partial gasification one. At the end of 1997, a new cycle scheme similar to IGCC was created. This paper focuses on several classes combined cycle put forward by Tsinghua University, depending on the plant configuration and carbon conversion, making the solution a viable and attractive option for efficient coal utilization.

  2. Direct coal-fired gas turbines for combined cycle plants

    SciTech Connect

    Rothrock, J.; Wenglarz, R.; Hart, P.; Mongia, H.

    1993-11-01

    The combustion/emissions control island of the CFTCC plant produces cleaned coal combustion gases for expansion in the gas turbine. The gases are cleaned to protect the turbine from flow-path degeneration due to coal contaminants and to reduce environmental emissions to comparable or lower levels than alternate clean coal power plant tedmologies. An advantage of the CFTCC system over other clean coal technologies using gas turbines results from the CFTCC system having been designed as an adaptation to coal of a natural gas-fired combined cycle plant. Gas turbines are built for compactness and simplicity. The RQL combustor is designed using gas turbine combustion technology rather than process plant reactor technology used in other pressurized coal systems. The result is simpler and more compact combustion equipment than for alternate technologies. The natural effect is lower cost and improved reliability. In addition to new power generation plants, CFTCC technology will provide relatively compact and gas turbine compatible coal combustion/emissions control islands that can adapt existing natural gas-fired combined cycle plants to coal when gas prices rise to the point where conversion is economically attractive. Because of the simplicity, compactness, and compatibility of the RQL combustion/emission control island compared to other coal technologies, it could be a primary candidate for such conversions.

  3. PFB coal fired combined cycle development program. Advanced hot gas cleanup concept evaluation (Task 4. 3). Volume B. Developmental cyclone evaluation

    SciTech Connect

    Not Available

    1980-02-01

    This report summarizes the results of cold flow model testing of a conventional reverse-flow cyclone containing several developmental features designed to improve its separative performance. The four advanced features evaluated were: Outlet Scroll Skimming - to remove particles from the high dust concentration region at the periphery of the outlet dust; Base Purge - to reduce reentrainment of dust from the disengagement hopper; Increased Outlet Duct Engagement - to reduce short-circuiting of the inlet dust into the outlet; and Vortex Shield - to stabilize the point of vortex attachment at the cyclone base and thus reduce base pickup. A schematic of the advanced cyclone, showing the various developmental features, is provided. The results of the cold flow experiments showed that substantial improvement (approximately 30% reduction in exhaust emission) could be obtained from outlet skimming or from increased engagement of the exhaust dust. Furthermore, the effects of these features are additive so that about 60% overall reduction in emissions could be achieved by incorporating both of these elements. On the other hand, the vortex shield and the base purge had little effect on the separative performance. Almost all of the experimental results exhibited strong electrostatic influence. At high flowrates, the separative performance of the cyclone decreased as the flowrate was reduced, as expected from cyclone theory. Although the improvements obtained with the developmental cyclone are significant, further improvements appear possible with the Air Shield cyclone and the Electrocyclone. Consequently, subsequent efforts under the CFCC program were focused on these concepts.

  4. Evaluation of air toxic emissions from advanced and conventional coal-fired power plants

    SciTech Connect

    Chu, P.; Epstein, M.; Gould, L.; Botros, P.

    1995-12-31

    This paper evaluates the air toxics measurements at three advanced power systems and a base case conventional fossil fuel power plant. The four plants tested include a pressurized fluidized bed combustor, integrated gasification combined cycle, circulating fluidized bed combustor, and a conventional coal-fired plant.

  5. Economic aspects of advanced coal-fired gas turbine locomotives

    NASA Technical Reports Server (NTRS)

    Liddle, S. G.; Bonzo, B. B.; Houser, B. C.

    1983-01-01

    Increases in the price of such conventional fuels as Diesel No. 2, as well as advancements in turbine technology, have prompted the present economic assessment of coal-fired gas turbine locomotive engines. A regenerative open cycle internal combustion gas turbine engine may be used, given the development of ceramic hot section components. Otherwise, an external combustion gas turbine engine appears attractive, since although its thermal efficiency is lower than that of a Diesel engine, its fuel is far less expensive. Attention is given to such a powerplant which will use a fluidized bed coal combustor. A life cycle cost analysis yields figures that are approximately half those typical of present locomotive engines.

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

    SciTech Connect

    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.

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

    SciTech Connect

    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. Engineering development of advanced coal-fired low-emission boiler system

    SciTech Connect

    Not Available

    1993-02-26

    The Pittsburgh Energy Technology Center of the US Department of Energy (DOE) has contracted with Combustion Engineering, Inc. (ABB CE) to perform work on the Engineering Development of Advanced Coal-Fired Low-Emission Boiler Systems'' Project and has authorized ABB CE to complete Phase I on a cost-reimbursable basis. The overall objective of the Project is the expedited commercialization of advanced coal-fired low-emission boiler systems. The specified primary objectives are: NO[sub x] emissions not greater than one-third NSPS; SO[sub x] emissions not greater than one-third NSPS; and particulate emissions not greater than one-half NSPS. The specific secondary objectives are: Improved ash disposability and reduced waste generation; reduced air toxics emissions; 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.

  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

    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. Advanced coal-fired glass melting development program

    SciTech Connect

    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)

  11. Steam turbine development for advanced combined cycle power plants

    SciTech Connect

    Oeynhausen, H.; Bergmann, D.; Balling, L.; Termuehlen, H.

    1996-12-31

    For advanced combined cycle power plants, the proper selection of steam turbine models is required to achieve optimal performance. The advancements in gas turbine technology must be followed by advances in the combined cycle steam turbine design. On the other hand, building low-cost gas turbines and steam turbines is desired which, however, can only be justified if no compromise is made in regard to their performance. The standard design concept of two-casing single-flow turbines seems to be the right choice for most of the present and future applications worldwide. Only for very specific applications it might be justified to select another design concept as a more suitable option.

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

    SciTech Connect

    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.

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

    SciTech Connect

    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.

  14. Flue Gas Cleanup at Temperatures about 1400 C for a Coal Fired Combined Cycle Power Plant: State and Perspectives in the Pressurized Pulverized Coal Combustion (PPCC) Project

    SciTech Connect

    Foerster, M.E.C.; Oeking, K.; Hannes, K.

    2002-09-18

    The PPCC technology, a combined cycle, requires comprehensive cleaning of the flue gases because coal contains a large variety of minerals and other substances. This would lead to fast destruction of the gas turbine blades due to erosion and corrosion. The present specifications of the turbine manufacturers for the required flue gas quality are at a maximum particulate content of 5 mg/m3 s.t.p., diameter of < 5 {micro}m, and a maximum alkali content < 0.01 mg/m3 s.t.p. The PPCC project is aimed at cleaning the flue gases of pressurized coal combustion. This method will be applied at temperature ranges where the ash is in a liquid state and which will be thus cleaned from coarse particulate material by agglomeration and inertial force separators. Appropriate separating methods are also being investigated and developed for the hazardous gaseous contents, e.g. alkali compounds, which are released during the coal combustion process. The following companies are working on the development within the scope of a collaborative project to find a feasible technical solution: Babcock-Borsig-Power Env. GmbH (BBP Env.), E.ON Kraftwerke GmbH, SaarEnergie GmbH, Siemens AG, and Steag AG.

  15. Thermodynamics of combined cycle plant

    NASA Astrophysics Data System (ADS)

    Crane, R. I.

    The fundamental thermodynamics of power plants including definitions of performance criteria and an introduction to exergy are reviewed, and treatments of simplified performance calculations for the components which form the major building blocks and a gas/steam combined cycle plant are given: the gas turbine, the heat recovery steam generator, and the remainder of the steam plant. Efficiency relationships and energy and exergy analyses of combined cycle plant are presented, with examples. Among the aspects considered are gas turbine performance characteristics and fuels, temperature differences for heat recovery, multiple steam pressures and reheat, supplementary firing and feed water heating. Attention is drawn to points of thermodynamic interest arising from applications of combined cycle plant to repowering of existing steam plant and to combined heat and power (cogeneration); some advances, including coal firing, are also introduced.

  16. Engineering development of advanced coal-fired low-emission boiler system. Technical progress report No. 1, August--December 1992

    SciTech Connect

    Not Available

    1993-02-26

    The Pittsburgh Energy Technology Center of the US Department of Energy (DOE) has contracted with Combustion Engineering, Inc. (ABB CE) to perform work on the ``Engineering Development of Advanced Coal-Fired Low-Emission Boiler Systems`` Project and has authorized ABB CE to complete Phase I on a cost-reimbursable basis. The overall objective of the Project is the expedited commercialization of advanced coal-fired low-emission boiler systems. The specified primary objectives are: NO{sub x} emissions not greater than one-third NSPS; SO{sub x} emissions not greater than one-third NSPS; and particulate emissions not greater than one-half NSPS. The specific secondary objectives are: Improved ash disposability and reduced waste generation; reduced air toxics emissions; 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.

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

    SciTech Connect

    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.

  18. Development of advanced NO sub x control concepts for coal-fired utility boilers

    SciTech Connect

    Newhall, J.; England, G.; Seeker, W.R.

    1992-01-16

    Hybrid technologies for reduction of NO{sub x} emissions from coal fired utility boilers may offer greater levels of NO{sub x} control than the sum of the individual technologies, leading to more cost effective emissions control strategies. CombiNO{sub x} is an integration of modified reburning, promoted selective non-catalytic reduction (SNCR) and methanol injection to reduce NO{sub x} emissions from coal fired flue gas. The first two steps, modified reburning and promoted SNCR are linked. It was shown previously that oxidation of CO in the presence of a SNCR agent enhances the NO reduction performance. Less reburning than is typically done is required to generate the optimum amount of CO to promote the SNCR agent. If the reburn fuel is natural gas this may result in a significant cost savings over typical reburning. Injection of methanol into the flue gas has been shown at laboratory scale to convert NO to NO{sub 2} which may subsequently be removed in a wet scrubber. The overall objective of this program is to demonstrate the effectiveness of the CombiNOx process at a large enough scale and over a sufficiently broad range of conditions to provide all of the information needed to conduct a full-scale demonstration in a coal fired utility boiler. The specific technical goals of this program are: 70% NO{sub x} reduction at 20% of the cost of selective catalytic reduction; NO{sub x} levels at the stack of 60 ppm for ozone non-attainment areas; demonstrate coal reburning; identify all undesirable by-products of the process and their controlling parameters; demonstrate 95% NO{sub 2} removal in a wet scrubber. During this reporting period, experimental work was initiated at both the laboratory and pilot scale in the Fundamental Studies phase of the program. The laboratory scale work focused on determining whether or not the NO{sub 2} formed by the methanol injection step can be removed in an SO{sub 2} scrubber.

  19. Development of advanced NO sub x control concepts for coal-fired utility boilers

    SciTech Connect

    Newhall, J.; England, G.; Seeker, W.R.

    1991-12-23

    Hybrid technologies for reduction of NO{sub x} emissions from coal fired utility boilers may offer greater levels of NO{sub x} control than the sum of the individual technologies, leading to more cost effective emissions control strategies. Energy and Environmental Research Corporation had developed a hybrid NO{sub x} control strategy involving two proprietary concepts which has the potential to meet the US Department of Energy's goal at a significant reduction in cost compared to existing technology. The process has been named CombiNO{sub x}. CombiNO{sub x} is the integration of three separate NO control technologies: (1) Gas Reburning, (2) CO-Promoted Selective Non-Catalytic Reduction, and (3) Methanol Injection/NO{sub 2} Scrubbing.

  20. Modelling and assessment of advanced processes for integrated environmental control of coal-fired power plants. Technical progress report

    SciTech Connect

    Barrett, J.G.; Bloyd, C.N.; McMichael, F.C.; Rubin, E.S.

    1984-07-01

    The key objective of this research is the development of a computer based model for the assessment of integrated environmental control (IEC) systems for conventional and advanced coal fired power plant designs. Efforts during the period April 1-June 30, 1984 focused on, (1) testing of a preliminary integrated model linking pre-combustion and post-combustion control options for conventional plants; (2) documentation of the analytical models of existing control technology options; (3) development and preliminary testing of a second model design for the propagation and analysis of uncertainty; and (4) development of new analytical models needed for IEC assessments. Activities and accomplishments in each of these areas are described. 4 references, 13 figures, 4 tables.

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

    SciTech Connect

    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.

  2. Engineering development of advanced coal-fired low-emission boiler systems. Technical progress report No. 15, April 15 1996--June 1996

    SciTech Connect

    1996-08-19

    The Pittsburgh Energy Technology center of the US 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_quote} 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.

  3. Optical fiber evanescent wave adsorption sensors for high-temperature gas sensing in advanced coal-fired power plants

    SciTech Connect

    Buric, M.; Ohodnicky, P.; Duy, J.

    2012-01-01

    Modern advanced energy systems such as coal-fired power plants, gasifiers, or similar infrastructure present some of the most challenging harsh environments for sensors. The power industry would benefit from new, ultra-high temperature devices capable of surviving in hot and corrosive environments for embedded sensing at the highest value locations. For these applications, we are currently exploring optical fiber evanescent wave absorption spectroscopy (EWAS) based sensors consisting of high temperature core materials integrated with novel high temperature gas sensitive cladding materials. Mathematical simulations can be used to assist in sensor development efforts, and we describe a simulation code that assumes a single thick cladding layer with gas sensitive optical constants. Recent work has demonstrated that Au nanoparticle-incorporated metal oxides show a potentially useful response for high temperature optical gas sensing applications through the sensitivity of the localized surface plasmon resonance absorption peak to ambient atmospheric conditions. Hence, the simulation code has been applied to understand how such a response can be exploited in an optical fiber based EWAS sensor configuration. We demonstrate that interrogation can be used to optimize the sensing response in such materials.

  4. 500 MW demonstration of advanced wall-fired combustion techniques for the reduction of nitrogen oxide emissions from coal-fired boilers

    SciTech Connect

    Sorge, J.N.; Menzies, B.; Smouse, S.M.; Stallings, J.W.

    1995-09-01

    Technology project demonstrating advanced wall-fired combustion techniques for the reduction of nitrogen oxide NOx emissions from coal-fired boilers. The primary objective 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.

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

    SciTech Connect

    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.

  6. Update of progress for Phase II of B&W`s advanced coal-fired low-emission boiler system

    SciTech Connect

    McDonald, D.K.; Madden, D.A.; Rodgers, L.W.

    1995-11-01

    Over the past five years, advances in emission control techniques at reduced costs and auxiliary power requirements coupled with significant improvements in steam turbine and cycle design have significantly altered the governing criteria by which advanced technologies have been compared. With these advances, it is clear that pulverized coal technology will continue to be competitive in both cost and performance with other advanced technologies such as Integrated Gasification Combined Cycle (IGCC) or first generation Pressurized Fluidized Bed Combustion (PFBC) technologies for at least the next decade. In the early 1990`s it appeared that if IGCC and PFBC could achieve costs comparable to conventional pulverized coal plants, their significantly reduced NO{sub x} and SO{sub 2} emissions would make them more attractive. A comparison of current emission control capabilities shows that all three technologies can already achieve similarly low emissions levels.

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

    SciTech Connect

    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.

  8. 500 MW demonstration of advanced wall-fired combustion techniques for the reduction of nitrogen oxide emissions from coal-fired boilers

    SciTech Connect

    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.

  9. Engineering development of advanced coal-fired low-emission boiler systems. Technical progress report No. 12, July--September 1995

    SciTech Connect

    1995-11-27

    The overall objective of the Project is the expedited commercialization of advanced coal-fired low-emission boiler systems. The goals for emissions and plant efficiency are: NO{sub x} emissions not greater than 0.1 lb/million Btu; SO{sub x} emissions not greater than 0.1 lb/million Btu; particulate emissions not greater than 0.01 lb/million Btu; and net plant efficiency (HHV basis) not less than 42%. Other goals include: improved ash disposability and reduced waste generation; and reduced air toxics emissions. 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.

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

    SciTech Connect

    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.

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

    SciTech Connect

    Kenneth E. Baldrey

    2000-09-01

    The U.S. Department of Energy and ADA Environmental Solutions have 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. During the second reporting quarter for this project, design and development is continuing on an electrostatic tensiometer to measure cohesion of flyash layers. A dedicated test fixture to automate flyash electrical resistivity testing is also underway. Ancillary instrumentation to control gas humidification within these test fixtures is also under construction.

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

    SciTech Connect

    Kenneth E. Baldrey

    2001-05-01

    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. During this reporting quarter, further laboratory-screening tests of additive formulations were completed. For these tests, the electrostatic tensiometer method was used for determination of flyash cohesivity. Resistivity was measured for each screening test with a multi-cell laboratory flyash resistivity furnace constructed for this project. Also during this quarter chemical formulation testing was undertaken to identify stable and compatible resistivity/cohesivity liquid products.

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

    SciTech Connect

    Kenneth E. Baldrey

    2001-01-01

    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. During the third reporting quarter, the electrostatic tensiometer for laboratory determination of flyash cohesivity was completed. Modifications were made to this method to improve repeatability. In addition, a new multi-cell laboratory flyash resistivity furnace was completed. Also during this quarter an agreement was reached for the initial field trial of the new additives at the City of Ames, Iowa Municipal Power Plant.

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

    SciTech Connect

    Kenneth E. Baldrey

    2003-01-01

    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, installation of a liquid flue gas conditioning system was completed at the American Electric Power Conesville Plant, Unit 3. This plant fires a bituminous coal and has opacity and particulate emissions performance issues related to fly ash re-entrainment. Two cohesivity-specific additive formulations, ADA-44C and ADA-51, will be evaluated. In addition, ammonia conditioning will also be compared.

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

    SciTech Connect

    Kenneth E. Baldrey

    2001-10-01

    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, progress was made in obtaining an industry partner for a long-term demonstration and in technology transfer activities. Engineering and equipment procurement activities related to the long-term demonstration were also completed.

  16. Advances of flue gas desulfurization technology for coal-fired boilers and strategies for sulfur dioxide pollution prevention in China

    SciTech Connect

    Yang, C.; Zeng, G.; Li, G.; Qiu, J.

    1999-07-01

    Coal is one of the most important kinds of energy resources at the present time and in the immediate future in China. Sulfur dioxide resulting from combustion of coal is one of the principle pollutants in the air. Control of SO{sub 2} discharge is still a major challenge for environmental protection in developing China. In this paper, research, development and application of technology of flue gas desulfurization (FGD) for coal-fired boilers in China will be reviewed with emphasis on cost-effective technology, and the development trends of FGD technology, as well as the strategy for SO{sub 2} discharge control in China, will be analyzed. A practical technology for middle-small-sized boilers developed by the primary author and the field investigation results will also be presented. At present, there are four major kinds of FGD technologies that are practical to be applied in China for their cost-effectiveness and efficiency to middle-small-sized boilers. An important development trend of the FGD technology for middle-small-sized boilers for the next decade is improvement of the existing cost-effective wet-type FGD technology, and in the future it will be the development of dry-type FGD technology. For middle-sized generating boilers, the development direction of the FGD technology is the spraying and drying process. For large-sized generating boilers, the wet-type limestone-plaster process will still be applied in the immediate future, and dry-type FGD technologies, such as ammonia with electron beam irradiation, will be developed in the future. State strategies for the control of SO{sub 2} discharge will involve the development and popularization of efficient coal-fired devices, extension of gas coal and liquefied coal, spreading coal washing, and centralized heating systems.

  17. Diagnosis of Thermal Efficiency of Advanced Combined Cycle Power Plants Using Optical Torque Sensors

    NASA Astrophysics Data System (ADS)

    Umezawa, Shuichi

    A new optical torque measurement method was applied to diagnosis of thermal efficiency of advanced combined cycle, i.e. ACC, plants. Since the ACC power plant comprises a steam turbine and a gas turbine and both of them are connected to the same generator, it is difficult to identify which turbine in the plant deteriorates the performance when the plant efficiency is reduced. The sensor measures axial distortion caused by power transmission by use of He-Ne laser beams, small stainless steel reflectors having bar-code patterns, and a technique of signal processing featuring high frequency. The sensor was applied to the ACC plants of TOKYO ELECTRIC POWER COMPANY, TEPCO, following the success in the application to the early combined cycle plants of TEPCO. The sensor performance was inspected over a year. After an improvement related to the signal process, it is considered that the sensor performance has reached a practical use level.

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

    SciTech Connect

    Kenneth E. Baldrey

    2003-07-30

    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. This quarterly report summarizes project activity for the period April-June, 2003. In this period there was limited activity and no active field trials. Results of ash analysis from the AEP Conesville demonstration were received. In addition, a site visit was made to We Energies Presque Isle Power Plant and a proposal extended for a flue gas conditioning trial with the ADA-51 cohesivity additive. It is expected that this will be the final full-scale evaluation on the project.

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

    SciTech Connect

    Kenneth E. Baldrey

    2003-02-01

    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, two cohesivity-specific additive formulations, ADA-44C and ADA-51, were evaluated in a full-scale trial at the American Electric Power Conesville plant. Ammonia conditioning was also evaluated for comparison. ADA-51 and ammonia conditioning significantly reduced rapping and non-rapped particulate re-entrainment based on stack opacity monitor data. Based on the successful tests to date, ADA-51 will be evaluated in a long-term test.

  20. Advanced intelligent coordinated control of coal fired power plant based on fuzzy reasoning and auto-tuning

    SciTech Connect

    Li, S.Y.; Liu, H.B.; Cai, W.J.; Soh, Y.C.; Xie, L.H.

    2004-07-01

    The load following operation of coal-fired boiler-turbine unit in power plants can lead to changes in operating points, and it results in nonlinear variations of the plant variables and parameters. As there exist strong couplings between the main steam pressure control loop and the power output control loop in the boiler-turbine unit with large time-delay and uncertainties, automatic coordinated control of the two loops is a very challenging problem. This paper presents a new coordinated control strategy (CCS) which is organized into two levels: a basic control level and a high supervision level. PID-type controllers are used in the basic level to perform basic control functions while the decoupling between two control loops can be realized in the high level. Moreover, PID-type controllers can be auto-tuned to achieve a better control performance in the whole operating range and to reject the unmeasurable disturbances. A special subclass of fuzzy inference systems, namely the Gaussian partition system with evenly spaced midpoints, is also proposed to auto-tune the PID controller in the main steam pressure loop based on the error signal and its first difference to overcome uncertainties caused by changing fuel calorific value, machine wear, contamination of the boiler heating surfaces and plant modeling errors, etc. The developed CCS has been implemented in a power plant in China, and satisfactory industrial operation results demonstrate that the proposed control strategy has enhanced the adaptability and robustness of the process.

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

    SciTech Connect

    Kenneth E. Baldrey

    2001-05-01

    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. During the fourth reporting quarter, laboratory-screening tests of more than 20 potential additive formulations were completed. For these tests, the electrostatic tensiometer method was used for determination of flyash cohesivity. Resistivity was measured for each screening test with a new multi-cell laboratory flyash resistivity furnace constructed for this project. An initial field trial of three additive formulations was also conducted at the City of Ames, Iowa Municipal Power Plant.

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

    SciTech Connect

    Kenneth E. Baldrey

    2002-01-01

    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, installation of a flue gas conditioning system was completed at PacifiCorp Jim Bridger Power Plant. Performance testing was underway. Results will be detailed in the next quarterly and subsequent technical summary reports. Also in this quarter, discussions were initiated with a prospective long-term candidate plant. This plant fires a bituminous coal and has opacity performance issues related to fly ash re-entrainment. Ammonia conditioning has been proposed here, but there is interest in liquid additives as a safer alternative.

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

    SciTech Connect

    Kenneth E. Baldrey

    2001-09-01

    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, further laboratory-screening tests of additive formulations were completed. For these tests, the electrostatic tensiometer method was used for determination of fly ash cohesivity. Resistivity was measured for each screening test with a multi-cell laboratory fly ash resistivity furnace constructed for this project. Also during this quarter chemical formulation testing was undertaken to identify stable and compatible resistivity/cohesivity liquid products.

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

    SciTech Connect

    Kenneth E. Baldrey

    2002-07-01

    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 completed at the PacifiCorp Jim Bridger Power Plant. The product tested, ADA-43, was a combination resistivity modifier with cohesivity polymers. The product was effective as a flue gas conditioner. However, ongoing problems with in-duct deposition resulting from the flue gas conditioning were not entirely resolved. Primarily these problems were the result of difficulties encountered with retrofit of an existing spray humidification system. Eventually it proved necessary to replace all of the original injection lances and to manually bypass the PLC-based air/liquid feed control. This yielded substantial improvement in spray atomization and system reliability. However, the plant opted not to install a permanent system. Also in this quarter, preparations continued for a test of the cohesivity additives at the American Electric Power Conesville Plant, Unit 3. 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.

  5. Technoeconomic Assessment of an Advanced Aqueous Ammonia-Based Postcombustion Capture Process Integrated with a 650-MW Coal-Fired Power Station.

    PubMed

    Li, Kangkang; Yu, Hai; Yan, Shuiping; Feron, Paul; Wardhaugh, Leigh; Tade, Moses

    2016-10-04

    Using a rigorous, rate-based model and a validated economic model, we investigated the technoeconomic performance of an aqueous NH3-based CO2 capture process integrated with a 650-MW coal-fired power station. First, the baseline NH3 process was explored with the process design of simultaneous capture of CO2 and SO2 to replace the conventional FGD unit. This reduced capital investment of the power station by US$425/kW (a 13.1% reduction). Integration of this NH3 baseline process with the power station takes the CO2-avoided cost advantage over the MEA process (US$67.3/tonne vs US$86.4/tonne). We then investigated process modifications of a two-stage absorption, rich-split configuration and interheating stripping to further advance the NH3 process. The modified process reduced energy consumption by 31.7 MW/h (20.2% reduction) and capital costs by US$55.4 million (6.7% reduction). As a result, the CO2-avoided cost fell to $53.2/tonne: a savings of $14.1 and $21.9/tonne CO2 compared with the NH3 baseline and advanced MEA process, respectively. The analysis of energy breakdown and cost distribution indicates that the technoeconomic performance of the NH3 process still has great potential to be improved.

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

    SciTech Connect

    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.

  7. Technical and Energy Performance of an Advanced, Aqueous Ammonia-Based CO2 Capture Technology for a 500 MW Coal-Fired Power Station.

    PubMed

    Li, Kangkang; Yu, Hai; Feron, Paul; Tade, Moses; Wardhaugh, Leigh

    2015-08-18

    Using a rate-based model, we assessed the technical feasibility and energy performance of an advanced aqueous-ammonia-based postcombustion capture process integrated with a coal-fired power station. The capture process consists of three identical process trains in parallel, each containing a CO2 capture unit, an NH3 recycling unit, a water separation unit, and a CO2 compressor. A sensitivity study of important parameters, such as NH3 concentration, lean CO2 loading, and stripper pressure, was performed to minimize the energy consumption involved in the CO2 capture process. Process modifications of the rich-split process and the interheating process were investigated to further reduce the solvent regeneration energy. The integrated capture system was then evaluated in terms of the mass balance and the energy consumption of each unit. The results show that our advanced ammonia process is technically feasible and energy-competitive, with a low net power-plant efficiency penalty of 7.7%.

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

    SciTech Connect

    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

  9. Analysis of R&D Strategy for Advanced Combined Cycle Power Systems

    NASA Astrophysics Data System (ADS)

    Akimoto, Keigo; Hayashi, Ayami; Kosugi, Takanobu; Tomoda, Toshimasa

    This article analyzes and evaluates the R&D strategy for advanced power generation technologies, such as natural gas combined cycles, IGCCs (Integrated coal Gasification Combined Cycles), and large-scale fuel cell power generation systems with a mixed-integer programming model. The R&D processes are explicitly formulated in the model through GERT (Graphical Evaluation and Review Technique), and the data on each required time of R&D was collected through questionnaire surveys among the experts. The obtained cost-effective strategy incorporates the optimum investment allocation among the developments of various elemental technologies, and at the same time, it incorporates the least-cost expansion planning of power systems in Japan including other power generation technologies such as conventional coal, oil, and gas fired, and hydro and wind power. The simulation results show the selection of the cost-effective technology developments and the importance of the concentrated investments in them. For example, IGCC, which has a relatively high thermal efficiency, and LNG-CCs of the assumed two efficiencies are the cost-effective investment targets in the no-CO2-regulation case.

  10. 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

    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.

  11. Emissions by Uncontrolled Coal Fires

    NASA Astrophysics Data System (ADS)

    Terschure, A. F.; Engle, M.; Heffern, E.; Hower, J.; Kolker, A.; Prakash, A.; Radke, L.

    2010-12-01

    Thousands of self-ignited coal fires, naturally occurring coal fires, and coal fires resulting from human activities persist for decades in underground coal mines, coal waste piles, and un-mined coal beds. These uncontrolled coal fires occur in all coal-bearing parts of the world and pose multiple threats to the global environment due to emission of greenhouse gases (GHG) such as CO2, CO, CH4, and other toxic substances such as mercury (Hg). Estimates of the amount of coal that is involved globally range between 20 and 600 Mt sing simple calculations, the only published peer-reviewed estimate of CO2 and Hg emissions from coal-fires in the United States (U.S.) are between 14 to 290 Mt/yr and 0.1 to 11.5 t/yr, respectively. In comparison, the U.S. coal-fired power plant fleet -the largest known anthropogenic source of CO2 and Hg to the atmosphere in the U.S.- emits ~2.4 Gt, and ~45 t annually, respectively. This paper builds on these results and will present result of a first-of-a-kind U.S.-based field campaign combining airborne remote sensing using thermal infrared technique and ground based measurements as a first step to constraining and scaling-up the emission factors, nature and extent of coal-fire emissions of CO2 and Hg to a global scale, which will allow for these emission sources to be better accounted for in global atmospheric models.

  12. Propulsion/ASME Rocket-Based Combined Cycle Activities in the Advanced Space Transportation Program Office

    NASA Technical Reports Server (NTRS)

    Hueter, Uwe; Turner, James

    1998-01-01

    NASA's Office Of Aeronautics and Space Transportation Technology (OASTT) has establish three major coals. "The Three Pillars for Success". The Advanced Space Transportation Program Office (ASTP) at the NASA's Marshall Space Flight Center in Huntsville,Ala. focuses on future space transportation technologies under the "Access to Space" pillar. The Advanced Reusable Technologies (ART) Project, part of ASTP, focuses on the reusable technologies beyond those being pursued by X-33. The main activity over the past two and a half years has been on advancing the rocket-based combined cycle (RBCC) technologies. In June of last year, activities for reusable launch vehicle (RLV) airframe and propulsion technologies were initiated. These activities focus primarily on those technologies that support the year 2000 decision to determine the path this country will take for Space Shuttle and RLV. In February of this year, additional technology efforts in the reusable technologies were awarded. The RBCC effort that was completed early this year was the initial step leading to flight demonstrations of the technology for space launch vehicle propulsion. Aerojet, Boeing-Rocketdyne and Pratt & Whitney were selected for a two-year period to design, build and ground test their RBCC engine concepts. In addition, ASTROX, Pennsylvania State University (PSU) and University of Alabama in Huntsville also conducted supporting activities. The activity included ground testing of components (e.g., injectors, thrusters, ejectors and inlets) and integrated flowpaths. An area that has caused a large amount of difficulty in the testing efforts is the means of initiating the rocket combustion process. All three of the prime contractors above were using silane (SiH4) for ignition of the thrusters. This follows from the successful use of silane in the NASP program for scramjet ignition. However, difficulties were immediately encountered when silane (an 80/20 mixture of hydrogen/silane) was used for rocket

  13. Coal-fired high performance power generating system. Quarterly progress report, April 1--June 30, 1993

    SciTech Connect

    Not Available

    1993-11-01

    This report covers work carried out under Task 2, Concept Definition and Analysis, Task 3, Preliminary R&D and Task 4, Commercial Generating Plant Design, under Contract AC22-92PC91155, ``Engineering Development of a Coal Fired High Performance Power Generation System`` between DOE Pittsburgh Energy Technology Center and United Technologies Research Center. 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 {le}25% NSPS; cost {ge}65% of heat input; 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. A survey of currently available high temperature alloys has been completed and some of their high temperature properties are shown for comparison. Several of the most promising candidates will be selected for testing to determine corrosion resistance and high temperature strength. The corrosion resistance testing of candidate refractory coatings is continuing and some of the recent results are presented. This effort will provide important design information that will ultimately establish the operating ranges of the HITAF.

  14. Industry perspectives on increasing the efficiency of coal-fired power generation

    SciTech Connect

    Torrens, I.M.; Stenzel, W.C.

    1997-12-31

    Independent power producers will build a substantial fraction of expected new coal-fired power generation in developing countries over the coming decades. To reduce perceived risk and obtain financing for their projects, they are currently building and plan to continue to build subcritical coal-fired plants with generating efficiency below 40%. Up-to-date engineering assessment leads to the conclusion that supercritical generating technology, capable of efficiencies of up to 45%, can produce electricity at a lower total cost than conventional plants. If such plants were built in Asia over the coming decades, the savings in carbon dioxide emissions over their lifetime would be measured in billions of tons. IPPs perceive supercritical technology as riskier and higher cost than conventional technology. The truth needs to be confirmed by discussions with additional experienced power engineering companies. Better communication among the interested parties could help to overcome the IPP perception issue. Governments working together with industry might be able to identify creative financing arrangements which can encourage the use of more efficient pulverized clean coal technologies, while awaiting the commercialization of advanced clean coal technologies like gasification combined cycle and pressurized fluidized bed combustion.

  15. Coal-fired high performance power generating system. Quarterly progress report, January 1--March 31, 1992

    SciTech Connect

    Not Available

    1992-12-31

    This report covers work carried out under Task 2, Concept Definition and Analysis, and Task 3, Preliminary R and D, under contract DE-AC22-92PC91155, ``Engineering Development of a Coal Fired High Performance Power Generation System`` between DOE Pittsburgh Energy Technology Center and United Technologies Research Center. 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 {le} 25% NSPS; cost {ge} 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 (FHTAF) which integrates several combustor and air heater designs with appropriate ash management procedures. The cycle optimization effort has brought about several revisions to the system configuration resulting from: (1) the use of Illinois No. 6 coal instead of Utah Blind Canyon; (2) the use of coal rather than methane as a reburn fuel; (3) reducing radiant section outlet temperatures to 1700F (down from 1800F); and (4) the need to use higher performance (higher cost) steam cycles to offset losses introduced as more realistic operating and construction constraints are identified.

  16. Life Cycle Assessment of Coal-fired Power Production

    SciTech Connect

    Spath, P. L.; Mann, M. K.; Kerr, D. R.

    1999-09-01

    Coal has the largest share of utility power generation in the US, accounting for approximately 56% of all utility-produced electricity (US DOE, 1998). Therefore, understanding the environmental implications of producing electricity from coal is an important component of any plan to reduce total emissions and resource consumption. A life cycle assessment (LCA) on the production of electricity from coal was performed in order to examine the environmental aspects of current and future pulverized coal boiler systems. Three systems were examined: (1) a plant that represents the average emissions and efficiency of currently operating coal-fired power plants in the US (this tells us about the status quo), (2) a new coal-fired power plant that meets the New Source Performance Standards (NSPS), and (3) a highly advanced coal-fired power plant utilizing a low emission boiler system (LEBS).

  17. 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

    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.

  18. 500 MW demonstration of advanced wall-fired combustion techniques for the reduction of nitrogen oxide (NOx) emissions from coal-fired boilers. Public design report (preliminary and final)

    SciTech Connect

    1996-07-01

    This Public Design Report presents the design criteria of a DOE Innovative Clean Coal Technology (ICCT) project demonstrating advanced wall-fired combustion techniques for the reduction of NO{sub x} emissions from coal-fired boilers. The project is being conducted at Georgia Power Company`s Plant Hammond Unit 4 (500 MW) near Rome, Georgia. The technologies being demonstrated at this site include Foster Wheeler Energy Corporation`s advanced overfire air system and Controlled Flow/Split Flame low NO{sub x} burner. 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 NO{sub x} burners, advanced overfire systems, and digital control system.

  19. 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, second quarter 1994, April 1994--June 1994

    SciTech Connect

    1995-09-01

    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 (NOx) 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 NOx combustion equipment through the collection and analysis of long-term emissions data. A target of achieving fifty percent NOx 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 NOx 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 NOx reductions of each technology and evaluate the effects of those reductions on other combustion parameters. Results are described.

  20. 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

    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.

  1. 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

    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.

  2. Coal-fired high performance power generating system

    SciTech Connect

    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.

  3. Advanced Shock Position Control for Mode Transition in a Turbine Based Combined Cycle Engine Inlet Model

    NASA Technical Reports Server (NTRS)

    Csank, Jeffrey T.; Stueber, Thomas J.

    2013-01-01

    A dual flow-path inlet system is being tested to evaluate methodologies for a Turbine Based Combined Cycle (TBCC) propulsion system to perform a controlled inlet mode transition. Prior to experimental testing, simulation models are used to test, debug, and validate potential control algorithms. One simulation package being used for testing is the High Mach Transient Engine Cycle Code simulation, known as HiTECC. This paper discusses the closed loop control system, which utilizes a shock location sensor to improve inlet performance and operability. Even though the shock location feedback has a coarse resolution, the feedback allows for a reduction in steady state error and, in some cases, better performance than with previous proposed pressure ratio based methods. This paper demonstrates the design and benefit with the implementation of a proportional-integral controller, an H-Infinity based controller, and a disturbance observer based controller.

  4. Development of advanced NO{sub x} control concepts for coal-fired utility boilers. Quarterly technical progress report No. 3, April 1--June 30, 1991

    SciTech Connect

    Newhall, J.; England, G.; Seeker, W.R.

    1992-01-16

    Hybrid technologies for reduction of NO{sub x} emissions from coal fired utility boilers may offer greater levels of NO{sub x} control than the sum of the individual technologies, leading to more cost effective emissions control strategies. CombiNO{sub x} is an integration of modified reburning, promoted selective non-catalytic reduction (SNCR) and methanol injection to reduce NO{sub x} emissions from coal fired flue gas. The first two steps, modified reburning and promoted SNCR are linked. It was shown previously that oxidation of CO in the presence of a SNCR agent enhances the NO reduction performance. Less reburning than is typically done is required to generate the optimum amount of CO to promote the SNCR agent. If the reburn fuel is natural gas this may result in a significant cost savings over typical reburning. Injection of methanol into the flue gas has been shown at laboratory scale to convert NO to NO{sub 2} which may subsequently be removed in a wet scrubber. The overall objective of this program is to demonstrate the effectiveness of the CombiNOx process at a large enough scale and over a sufficiently broad range of conditions to provide all of the information needed to conduct a full-scale demonstration in a coal fired utility boiler. The specific technical goals of this program are: 70% NO{sub x} reduction at 20% of the cost of selective catalytic reduction; NO{sub x} levels at the stack of 60 ppm for ozone non-attainment areas; demonstrate coal reburning; identify all undesirable by-products of the process and their controlling parameters; demonstrate 95% NO{sub 2} removal in a wet scrubber. During this reporting period, experimental work was initiated at both the laboratory and pilot scale in the Fundamental Studies phase of the program. The laboratory scale work focused on determining whether or not the NO{sub 2} formed by the methanol injection step can be removed in an SO{sub 2} scrubber.

  5. Coal-fired ships reappear

    SciTech Connect

    Not Available

    1983-09-01

    A situation now exists where, in many countries, coal prices are almost half those of oil, and indications point toward this trend continuing. It is not surprising, therefore, that many shipowners are planning and building the next generation of steamships with coal-fired propulsion units. Six new coal-fired ships, the first for over 25 years, are now being built in Italy, Japan, and Spain. In the forefront in technology and systems for handling coal and ash is the British company Macawber Engineering. It has developed on-board systems responding to the problems created by coal handling on a modern steamship, problems that formed a major reason for the universal changeover to oil firing in the 1950s and 1960s. The traditional method of handling coal uses mechanical systems such as belt and draglink conveyors, and bucket elevators. These methods have disadvantages that make their use on ships far from satisfactory. Pneumatic conveying systems, due to their totally enclosed construction and relative simplicity, overcome these problems. The type of pneumatic system chosen, however, has to accommodate several other constraints imposed by on-board handling of coal. (SC)

  6. Development of advanced NO{sub x} control concepts for coal-fired utility boilers. Quarterly technical progress report No. 1, September 26--December 31, 1990

    SciTech Connect

    Newhall, J.; England, G.; Seeker, W.R.

    1991-12-23

    Hybrid technologies for reduction of NO{sub x} emissions from coal fired utility boilers may offer greater levels of NO{sub x} control than the sum of the individual technologies, leading to more cost effective emissions control strategies. Energy and Environmental Research Corporation had developed a hybrid NO{sub x} control strategy involving two proprietary concepts which has the potential to meet the US Department of Energy`s goal at a significant reduction in cost compared to existing technology. The process has been named CombiNO{sub x}. CombiNO{sub x} is the integration of three separate NO control technologies: (1) Gas Reburning, (2) CO-Promoted Selective Non-Catalytic Reduction, and (3) Methanol Injection/NO{sub 2} Scrubbing.

  7. Status of NO sub x control for coal-fired power plants

    NASA Technical Reports Server (NTRS)

    Teixeira, D. P.

    1978-01-01

    The status of technologies for controlling emissions of oxides of nitrogen (NOx) from coal-fired power plants is reviewed. A discussion of current technology as well as future NOx control approaches is presented. Advanced combustion approaches are included as well as post-combustion alternatives such as catalytic and noncatalytic ammonia-bases systems and wet scrubbing. Special emphasis is given to unresolved development issues as they relate to practical applications on coal-fired power plants.

  8. Engineering development of coal-fired high-performance power systems. Progress report, April 1--June 30, 1996

    SciTech Connect

    1996-12-31

    In Phase 1 of the project, a conceptual design of a coal-fired, high-performance power system (HIPPS) was developed, and small-scale R and D was done in critical areas of the design. The current phase of the project includes development through the pilot plant stage and design of a prototype plant that would be built in Phase 3. The power-generating system being developed in this project will be an improvement over current coal-fired systems. It is a combined-cycle plant. This arrangement is referred to as the All Coal HIPPS because it does not require any other fuels for normal operation. A fluidized bed, air-blown pyrolyzer converts coal into fuel gas and char. The char is fired in a high-temperature advanced furnace (HITAF) which heats both air for a gas turbine and steam for a steam turbine. The fuel gas from the pyrolyzer goes to a topping combustor where it is used to raise the air entering the gas turbine to 1288 C. In addition to the HITAF, steam duty is achieved with a heat-recovery steam generator (HRSG) in the gas turbine exhaust stream and economizers in the HITAF flue gas exhaust stream. Progress during the quarter is described.

  9. Technical progress report for the Magnetohydrodynamics Coal-Fired Flow Facility: October 1, 1992--December 31, 1992

    SciTech Connect

    Not Available

    1993-06-01

    Progress is reported on a multitask contract to develop technology for steam bottoming cycle of a Combined Cycle MHD Steam Power Plant. The report describes a 314 hour proof-of-concept (POC) test completed during the quarter. Results include secondary combustion and effect of potassium on the light-off temperature, fouling of heat transfer surfaces, particulate clean-up device performance and advanced diagnostic system performance. Test results on ceramic materials and tubes directed toward the development of a high temperature recuperative air heater are summarized. Results of data analysis of previous tests that are reported include the continuing analysis of tube materials that were exposed to 1500 and 2000 hours of eastern coal fired operation during the previously completed 2000 hour POC test series on eastern, high sulfur coal.

  10. The Magnetohydrodynamics Coal-Fired Flow Facility

    SciTech Connect

    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.

  11. 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

    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.

  12. Summary report: Trace substance emissions from a coal-fired gasification plant

    SciTech Connect

    Williams, A.; Wetherold, B.; Maxwell, D.

    1996-10-16

    The U.S. Department of Energy (DOE), the Electric Power Research Institute (EPRI), and Louisiana Gasification Technology Inc. (LGTI) sponsored field sampling and analyses to characterize emissions of trace substances from LGTI`s integrated gasification combined cycle (IGCC) power plant at Plaquemine, Louisiana. The results indicate that emissions from the LGTI facility were quite low, often in the ppb levels, and comparable to a well-controlled pulverized coal-fired power plant.

  13. Coal-fired diesel generator

    SciTech Connect

    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.

  14. Coal fired air turbine cogeneration

    NASA Astrophysics Data System (ADS)

    Foster-Pegg, R. W.

    Fuel options and generator configurations for installation of cogenerator equipment are reviewed, noting that the use of oil or gas may be precluded by cost or legislation within the lifetime of any cogeneration equipment yet to be installed. A coal fueled air turbine cogenerator plant is described, which uses external combustion in a limestone bed at atmospheric pressure and in which air tubes are sunk to gain heat for a gas turbine. The limestone in the 26 MW unit absorbs sulfur from the coal, and can be replaced by other sorbents depending on types of coal available and stringency of local environmental regulations. Low temperature combustion reduces NOx formation and release of alkali salts and corrosion. The air heat is exhausted through a heat recovery boiler to produce process steam, then can be refed into the combustion chamber to satisfy preheat requirements. All parts of the cogenerator are designed to withstand full combustion temperature (1500 F) in the event of air flow stoppage. Costs are compared with those of a coal fired boiler and purchased power, and it is shown that the increased capital requirements for cogenerator apparatus will yield a 2.8 year payback. Detailed flow charts, diagrams and costs schedules are included.

  15. Advanced Monitoring to Improve Combustion Turbine/Combined Cycle Reliability, Availability & Maintainability

    SciTech Connect

    Leonard Angello

    2005-09-30

    Power generators are concerned with the maintenance costs associated with the advanced turbines that they are purchasing. Since these machines do not have fully established Operation and Maintenance (O&M) track records, power generators face financial risk due to uncertain future maintenance costs. This risk is of particular concern, as the electricity industry transitions to a competitive business environment in which unexpected O&M costs cannot be passed through to consumers. These concerns have accelerated the need for intelligent software-based diagnostic systems that can monitor the health of a combustion turbine in real time and provide valuable information on the machine's performance to its owner/operators. EPRI, Impact Technologies, Boyce Engineering, and Progress Energy have teamed to develop a suite of intelligent software tools integrated with a diagnostic monitoring platform that, in real time, interpret data to assess the 'total health' of combustion turbines. The 'Combustion Turbine Health Management System' (CTHMS) will consist of a series of 'Dynamic Link Library' (DLL) programs residing on a diagnostic monitoring platform that accepts turbine health data from existing monitoring instrumentation. CTHMS interprets sensor and instrument outputs, correlates them to a machine's condition, provide interpretative analyses, project servicing intervals, and estimate remaining component life. In addition, the CTHMS enables real-time anomaly detection and diagnostics of performance and mechanical faults, enabling power producers to more accurately predict critical component remaining useful life and turbine degradation.

  16. ADVANCED MONITORING TO IMPROVE COMBUSTION TURBINE (CT)/COMBINED CYCLE (CC) RELIABILITY, AVAILABILITY AND MAINTAINABILITY (RAM)

    SciTech Connect

    Leonard Angello

    2002-04-01

    Power generators are concerned with the maintenance costs associated with the advanced turbines that they are purchasing. Since these machines do not have fully established operation and maintenance (O&M) track records, power generators face financial risk due to uncertain future maintenance costs. This risk is of particular concern, as the electricity industry transitions to a competitive business environment in which unexpected O&M costs cannot be passed through to consumers. These concerns have accelerated the need for intelligent software-based diagnostic systems that can monitor the health of a combustion turbine in real time and provide valuable information on the machine's performance to its owner/operators. Such systems would interpret sensor and instrument outputs, correlate them to the machine's condition, provide interpretative analyses, forward projections of servicing intervals, estimate remaining component life, and identify faults. EPRI, Impact Technologies, Boyce Engineering, and Progress Energy have teamed to develop a suite of intelligent software tools integrated with a diagnostic monitoring platform that will, in real time, interpret data to assess the ''total health'' of combustion turbines. The Combustion Turbine Health Management System (CTHM) will consist of a series of dynamic link library (DLL) programs residing on a diagnostic monitoring platform that accepts turbine health data from existing monitoring instrumentation. The CTHM system will be a significant improvement over currently available techniques for turbine monitoring and diagnostics. CTHM will interpret sensor and instrument outputs, correlate them to a machine's condition, provide interpretative analyses, project servicing intervals, and estimate remaining component life. In addition, it will enable real-time anomaly detection and diagnostics of performance and mechanical faults, enabling power producers to more accurately predict critical component remaining useful life and

  17. Technical progress report for the Magnetohydrodynamics Coal-Fired Flow Facility. January 1, 1993--March 31, 1993

    SciTech Connect

    Not Available

    1993-07-01

    Progress is reported in developing technology for steam bottoming cycle of the coal-fired MHD Steam Combined Cycle Power Plant. During this period, no testing was scheduled in the DOE Coal-Fired Flow Facility. The report covers facilities modification and maintenance in preparation for a 225 hour POC test that is scheduled for early next quarter. The modifications to the dry ESP to replace the electrodes with smaller diameter wires is discussed. Continued work on the rotary vacuum filter, which is designed to separate the more soluble potassium carbonate from the potassium sulfate and fly ash, is reported. Environmental activities for the quarter are summarized.

  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

    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. 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

    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.

  20. 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

    Not Available

    1992-08-24

    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.

  1. 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, Second quarter 1992

    SciTech Connect

    Not Available

    1992-08-24

    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.

  2. ENGINEERING DEVELOPMENT OF COAL-FIRED HIGH PERFORMANCE POWER SYSTEMS

    SciTech Connect

    1998-10-01

    A High Performance Power System (HIPPS) is being developed. This system is a coal-fired, combined cycle plant with indirect heating of gas turbine air. Foster Wheeler Development Corporation and a team consisting of Foster Wheeler Energy Corporation, Bechtel Corporation, University of Tennessee Space Institute and Westinghouse Electric Corporation are developing this system. In Phase 1 of the project, a conceptual design of a commercial plant was developed. Technical and economic analyses indicated that the plant would meet the goals of the project which include a 47 percent efficiency (HHV) and a 10 percent lower cost of electricity than an equivalent size PC plant. The concept uses a pyrolyzation process to convert coal into fuel gas and char. The char is fired in a High Temperature Advanced Furnace (HITAF). The HITAF is a pulverized fuel-fired boiler/air heater where steam is generated and gas turbine air is indirectly heated. The fuel gas generated in the pyrolyzer is then used to heat the gas turbine air further before it enters the gas turbine. The project is currently in Phase 2 which includes engineering analysis, laboratory testing and pilot plant testing. Research and development is being done on the HIPPS systems that are not commercial or being developed on other projects. Pilot plant testing of the pyrolyzer subsystem and the char combustion subsystem are being done separately, and after each experimental program has been completed, a larger scale pyrolyzer will be tested at the Power Systems Development Facility (PSDF) in Wilsonville, Al. The facility is equipped with a gas turbine and a topping combustor, and as such, will provide an opportunity to evaluate integrated pyrolyzer and turbine operation. This report addresses the areas of technical progress for this quarter. Preliminary process design was started with respect to the integrated test program at the PSDF. All of the construction tasks at Foster Wheeler's Combustion and Environmental Test

  3. Development of a high-performance coal-fired power generating system with pyrolysis gas and char-fired High Temperature Furnace (HITAF). Quarterly progress report 11, July--September, 1994

    SciTech Connect

    1995-05-01

    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 and D plan to develop the concept further. The power generating system being developed in this project will be an improvement over current coal-fired systems. Goals have been specified that relate to the efficiency, emissions, costs, and general operation of the system. These goals are: total station efficiency of at least 47%; no more than: 0.15 lb NO{sub x}/10{sup 6} Btu fuel heat input, 0.15 lb SO{sub x}/10{sup 6} Btu fuel heat input, 0.0075 lb of particulates/10{sup 6} Btu fuel heat input; all solid wastes must be benign, generation of solid wastes is minimized through production of usable by-products; over 95% of the total heat input is ultimately from coal, with initial systems capable of using coal for at least 65% of the heat input; efficient and economic baseload power generation: operation with a range of US coals, annual capacity factor of 65%, load following with minimal degradation in efficiency, net electrical output as low as 100 MW, 10% lower cost of electricity (COE) relative to a modern coal-fired plant conforming to NSPS; safety, reliability, and maintainability to meet or exceed conventional coal-fired power plants; amenable to construction using factory-assembled modular components based upon standard design.

  4. The Magnetohydrodynamics Coal-Fired Flow Facility technical progress report, July 1, 1993--September 30, 1993

    SciTech Connect

    Not Available

    1993-12-01

    In this quarterly technical progress report, UTSI reports on a multi-task research contract directed toward developing the technology for an MHD steam combined cycle power plant. During the period two tests were conducted in the DOE Coal Fired FLow Facility. Both of these tests were part of the western coal proof-of-concept (POC) test series. The report describes the performance of the tests and provides some preliminary performance data on particulate removal systems during the tests. The performance of ceramic tubes being tested for high temperature air heater application is described. Performance of advanced diagnostics equipment from both UTSI and MSU is summarized. The results of experiments designed to determine the effects of potassium compounds on combustion are included. Plans for analysis of metal tube specimens previously removed from the test train are discussed. Modeling and analysis of previous test data include a deposition model to predict ash deposition on tubes, mass balance results, automated data screening and chemical analyses and the data base containing these analyses. Laboratory tests on sealing ceramic tubes and corrosion analyses of previously tested tubes are reported.

  5. Microfine coal firing results from a retrofit gas/oil-designed industrial boiler

    SciTech Connect

    Patel, R.; Borio, R.W.; Liljedahl, G.

    1995-11-01

    Under US Department of Energy, Pittsburgh Energy Technology Center (PETC) support, the development of a High Efficiency Advanced Coal Combustor (HEACC) has been in progress since 1987 at the ABB Power Plant Laboratories. The initial work on this concept produced an advanced coal firing system that was capable of firing both water-based and dry pulverized coal in an industrial boiler environment.

  6. 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

    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.

  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. Third quarterly technical progress report

    SciTech Connect

    Not Available

    1993-12-31

    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 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. Baseline, AOFA, LNB, and LNB plus AOFA test segments have been completed. Analysis of the 94 days of LNB long-term data collected show the full-load NO{sub x} emission levels to be approximately 0.65 lb/MBtu with fly ash LOI values of approximately 8 percent. Corresponding values for the AOFA configuration are 0.94 lb/MBtu and approximately 10 percent. For comparison, the long-term full-load, baseline NO{sub x} emission level was approximately 1.24 lb/MBtu at 5.2 percent LOI. Comprehensive testing in the LNB+AOFA configuration indicate that at full-load, NO{sub x} emissions and fly ash LOI are near 0.40 lb/MBtu and 8 percent, respectively. However, it is believed that a substantial portion of the incremental change in NO{sub x} emissions between the LNB and LNB+AOFA configurations is the result of additional burner tuning and other operational adjustments and is not the result of the AOFA system. During this quarter, LNB+AOFA testing was concluded. Testing performed during this quarter included long-term and verification testing in the LNB+AOFA configuration.

  8. 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, Fourth quarter 1992

    SciTech Connect

    Not Available

    1992-12-31

    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 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. Baseline, AOFA, and LNB without AOFA test segments have been completed. Analysis of the 94 days of LNB tong-term data collected show the full load NO{sub x} emission levels to be approximately 0.65 lb/MBtu. Flyash LOI values for the LNB configuration are approximately 8 percent at full load. Corresponding values for the AOFA configuration are 0.94 lb/MBtu and approximately 10 percent. Abbreviated diagnostic tests for the LNB+AOFA configuration indicate that at 500 MWe, NO{sub x} emissions are approximately 0.55 lb/MBtu with corresponding flyash LOI values of approximately 11 percent. For comparison, the long-term, full load, baseline NO{sub x} emission level was approximately 1.24 lb/MBtu at 5.2 percent LOI. Comprehensive testing of the LNB+AOFA configuration will be performed when the stack particulate emissions issue is resolved.

  9. Development of a high-performance coal-fired power generating system with pyrolysis gas and char-fired high temperature furnace (HITAF). Quarterly progress report 8, October--December 1993

    SciTech Connect

    Not Available

    1994-02-01

    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 power generating system being developed in this project will be an improvement over current coal-fired systems. Goals have been specified that relate to the efficiency, emissions, costs, and general operation of the system. The system proposed to meet these goals is a combined-cycle system where air for a gas turbine is indirectly heated to approximately 1800{degrees}F in furnaces fired with coal-derived fuels and then directly heated in a natural-gas-fired combustor to about 2400{degrees}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.

  10. Engineering development of advanced coal-fired low-emissions boiler systems. Quarterly report, October 1994--December 1994; January 1995--March 1995; April 1995--June 1995; July 1995--September 1995; October 1995--December 1995

    SciTech Connect

    1996-04-01

    This report covers five quarters of work on the engineering development of a coal-fired low -emissions boiler systems. Contents include summaries of activities and key accomplishments for the following: project management; NO{sub x} subsystem; SO{sub 2}/particulate/air toxics/solid by-product subsystems; controls and sensors subsystems; boiler subsystem; and balance of plant subsystem.

  11. Innovative Clean Coal Technology (ICCT): 180 MW demonstration of advanced tangentially-fired combustion techniques for the reduction of nitrogen oxide (NO{sub x}) emissions from coal-fired boilers. Topical report, LNCFS Levels 1 and 3 test results

    SciTech Connect

    Not Available

    1993-08-17

    This report presents results from the third phase of an Innovative Clean Coal Technology (ICC-1) project demonstrating advanced tangentially-fired combustion techniques for the reduction of nitrogen oxide (NO{sub x}) emissions from a coal-fired boiler. The purpose of this project was to study the NO{sub x} emissions characteristics of ABB Combustion Engineering`s (ABB CE) Low NO{sub x} Concentric Firing System (LNCFS) Levels I, II, and III. These technologies were installed and tested in a stepwise fashion at Gulf Power Company`s Plant Lansing Smith Unit 2. The objective of this report is to provide the results from Phase III. During that phase, Levels I and III of the ABB C-E Services Low NO{sub x} Concentric Firing System were tested. The LNCFS Level III technology includes separated overfire air, close coupled overfire air, clustered coal nozzles, flame attachment coal nozzle tips, and concentric firing. The LNCFS Level I was simulated by closing the separated overfire air nozzles of the LNCFS Level III system. Based upon long-term data, LNCFS Level HI reduced NO{sub x} emissions by 45 percent at full load. LOI levels with LNCFS Level III increased slightly, however, tests showed that LOI levels with LNCFS Level III were highly dependent upon coal fineness. After correcting for leakage air through the separated overfire air system, the simulated LNCFS Level I reduced NO{sub x} emissions by 37 percent. There was no increase in LOI with LNCFS Level I.

  12. DOE/NETL's field tests of mercury control technologies for coal-fired power plants

    SciTech Connect

    Thomas Feeley; James Murphy; Lynn Brickett; Andrew O'Palko

    2005-08-01

    The U.S. Department of Energy's National Energy Technology Laboratory (DOE/NETL) is conducting a comprehensive research and development program directed at advancing the performance and economics of mercury control technologies for coal-fired power plants. This article presents results from ongoing full-scale and slipstream field tests of several mercury control technologies. 15 refs., 4 figs., 3 tabs.

  13. Coal-gasification combined-cycle power generation

    SciTech Connect

    Roberts, J.A.

    1984-06-01

    Rolls-Royce has joined forces with Foster Wheeler to offer a modern power plant that integrates the benefits of coal gasification with the efficiency advantages of combined-cycle power generation. Powered by fuel gas from two parallel Lurgi slagging gasifiers, the 150-MW power station employs two Rolls-Royce SK60 gas-turbine generating sets. The proposed plant is designed for continuous power generation and should operate efficiently down to one-third of its rated capacity. Rolls estimates that the installed cost for this station would be lower than that for a conventional coal-fired station of the same output with comparable operating costs. Cooling water requirements would be less than half those of a coal-fired station.

  14. Executive roundtable on coal-fired generation

    SciTech Connect

    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.

  15. Development of a high-performance, coal-fired power generating system with a pyrolysis gas and char-fired high-temperature furnace

    SciTech Connect

    Shenker, J.

    1995-11-01

    A high-performance power system (HIPPS) is being developed. This system is a coal-fired, combined-cycle plant that will have an efficiency of at least 47 percent, based on the higher heating value of the fuel. The original emissions goal of the project was for NOx and SOx to each be below 0.15 lb/MMBtu. In the Phase 2 RFP this emissions goal was reduced to 0.06 lb/MMBtu. The ultimate goal of HIPPS is to have an all-coal-fueled system, but initial versions of the system are allowed up to 35 percent heat input from natural gas. Foster Wheeler Development Corporation is currently leading a team effort with AlliedSignal, Bechtel, Foster Wheeler Energy Corporation, Research-Cottrell, TRW and Westinghouse. Previous work on the project was also done by General Electric. The HIPPS plant will use a high-Temperature Advanced Furnace (HITAF) to achieve combined-cycle operation with coal as the primary fuel. The HITAF is an atmospheric-pressure, pulverized-fuel-fired boiler/air heater. The HITAF is used to heat air for the gas turbine and also to transfer heat to the steam cycle. its design and functions are very similar to conventional PC boilers. Some important differences, however, arise from the requirements of the combined cycle operation.

  16. Characterization of pressurized fluidized bed and pulverized coal fired power plants

    SciTech Connect

    Doss, H.S.; Pietruszkiewicz, J.; Thomas, G.O.; Hamm, J.R.; Bezella, W.A.

    1984-01-01

    This paper presents the major technical and economic characteristics of a steam-cooled and an air-cooled pressurized fluidized bed (PFB) power plant concept along with the characteristics of a pulverized coal fired power plant equipped with an adipic acid enhanced wet-limestone flue gas desulfurization system. The conceptual designs were prepared to satisfy a set of common groundrules that were developed for the study. The power plants are of the grassroots type, located on a generic plant site. The designs incorporate technological advances available for commercialization in the 1990 time frame. The net power outputs of the base case plants, using Illinois No. 6 coal, range from 502 MWe for the pulverized coal fired plant to 554 MWe for the air-cooled PFB plant. The net power plant heat rates vary from 9725 Btu/kWh for the pulverized coal fired plant to 8710 Btu/kWh for the steam-cooled PFB plant. For the economic groundrules set for the study, the pulverized coal fired plant utilizing an advanced flue gas desulfurization concept had the lowest specific capital cost and lowest levelized cost of electricity. However, utility and site specific conditions could materially alter the relative merits of the various concepts in a given utility application.

  17. Development and application of performance and cost models for the externally-fired combined cycle. Task 1, Volume 2. Topical report, June 1995

    SciTech Connect

    Agarwal, P.; Frey, H.; Rubin, E.S.

    1995-07-01

    Increasing restrictions on emission of pollutants from conventional pulverized coal fired steam (PCFS) plant generating electrical power is raising capital and operating cost of these plants and at the same time lowering plant efficiency. This is creating a need for alternative technologies which result in lower emissions of regulated pollutants and which are thermally more efficient. Natural gas-fired combined cycle power generation systems have lower capital cost and higher efficiencies than conventional coal fired steam plants, and at this time they are the leading contender for new power plant construction in the U.S. But the intermediate and long term cost of these fuels is high and there is uncertainty regarding their long-term price and availability. Coal is a relatively low cost fuel which will be abundantly available in the long term. This has motivated the development of advanced technologies for power production from coal which will have advantages of other fuels. The Externally Fired Combined Cycle (EFCC) is one such technology. Air pollution control/hot gas cleanup issues associated with this technology are described.

  18. 180 MW demonstration of advanced tangentially-fired combustion techniques for the reduction of nitrogen oxide (NO sub x ) emissions from coal-fired boilers

    SciTech Connect

    Not Available

    1991-01-01

    ABB CE's Low NOx Bulk Furnace Staging (LNBFS) System and Low NOx Concentric Firing System (LNCFS) are demonstrated in stepwise fashion. These systems incorporate the concept of advanced overfire air (AOFA), clustered coal nozzles, and offset air. A complete description of the installed technologies is provided in the following section. The primary objective of the Plant Lansing Smith demonstration is to determine the long-term effects of commercially available tangentially-fired low NOx combustion technologies on NOx emissions and boiler performance. Short-term tests of each technology are also being performed to provide engineering information about emissions and performance trends. A target of achieving fifty percent NOx reduction using combustion modifications has been established for the project.

  19. 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

    Not Available

    1992-01-01

    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 particulatecharacteristics and boiler efficiency. Baseline, AOFA, and LNB without AOFA test segments have been completed. Analysis of the 94 days of LNB long-term data collected show the full-load NO[sub x] emission levels to be approximately 0.65 lb/MBtu. Flyash LOI values for the LNB configuration are approximately 8 percent at full-load. Corresponding values for the AOFA configuration are 0.94 lb/MBtu and approximately 10 percent. Abbreviated diagnostic tests for the LNB+AOFA configuration indicate that at 500 MWe, NO[sub x] emissions are approximately 0.55 lb/MBtu with corresponding flyash LOI values of approximately 11 percent. For comparison, the long-term full-load, baseline NO[sub x] emission level was approximately 1.24 lb/MBtu at 5.2 percent LOI. Comprehensive testing of the LNB+AOFA configuration will be performed when the stackparticulate emissions issue is resolved. Testing of a process optimization package on Plant Hammond Unit 4 was performed during this quarter. The software was configured to minimize NO[sub x] emissions using total combustion air flow and advanced overfire air distribution as the controlled parameters. Preliminary results from this testing indicate that this package shows promise in reducing NO[sub x] emissions while maintaining or improving other boiler performance parameters.

  20. Ways to Improve Russian Coal-Fired Power Plants

    SciTech Connect

    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.

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

    SciTech Connect

    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.

  2. Engineering Development of Coal-Fired High-Performance Power Systems

    SciTech Connect

    York Tsuo

    2000-12-31

    A High Performance Power System (HIPPS) is being developed. This system is a coal-fired, combined cycle plant with indirect heating of gas turbine air. Foster Wheeler Development Corporation and a team consisting of Foster Wheeler Energy Corporation, Bechtel Corporation, University of Tennessee Space Institute and Westinghouse Electric Corporation are developing this system. In Phase 1 of the project, a conceptual design of a commercial plant was developed. Technical and economic analyses indicated that the plant would meet the goals of the project which include a 47 percent efficiency (HHV) and a 10 percent lower cost of electricity than an equivalent size PC plant. The concept uses a pyrolysis process to convert coal into fuel gas and char. The char is fired in a High Temperature Advanced Furnace (HITAF). The HITAF is a pulverized fuel-fired boiler/air heater where steam is generated and gas turbine air is indirectly heated. The fuel gas generated in the pyrolyzer is then used to heat the gas turbine air further before it enters the gas turbine. The project is currently in Phase 2 which includes engineering analysis, laboratory testing and pilot plant testing. Research and development is being done on the HIPPS systems that are not commercial or being developed on other projects. Pilot plant testing of the pyrolyzer subsystem and the char combustion subsystem are being done separately. This report addresses the areas of technical progress for this quarter. The detail of syngas cooler design is given in this report. The final construction work of the CFB pyrolyzer pilot plant has started during this quarter. No experimental testing was performed during this quarter. The proposed test matrix for the future CFB pyrolyzer tests is given in this report. Besides testing various fuels, bed temperature will be the primary test parameter.

  3. The coal-fired gas turbine locomotive - A new look

    NASA Technical Reports Server (NTRS)

    Liddle, S. G.; Bonzo, B. B.; Purohit, G. P.

    1983-01-01

    Advances in turbomachine technology and novel methods of coal combustion may have made possible the development of a competitive coal fired gas turbine locomotive engine. Of the combustor, thermodynamic cycle, and turbine combinations presently assessed, an external combustion closed cycle regenerative gas turbine with a fluidized bed coal combustor is judged to be the best suited for locomotive requirements. Some merit is also discerned in external combustion open cycle regenerative systems and internal combustion open cycle regenerative gas turbine systems employing a coal gasifier. The choice of an open or closed cycle depends on the selection of a working fluid and the relative advantages of loop pressurization, with air being the most attractive closed cycle working fluid on the basis of cost.

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

    DOEpatents

    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.

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

    DOEpatents

    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.

  6. Emissions from Coal Fires and Their Impact on the Environment

    USGS Publications Warehouse

    Kolker, Allan; Engle, Mark; Stracher, Glenn; Hower, James; Prakash, Anupma; Radke, Lawrence; ter Schure, Arnout; Heffern, Ed

    2009-01-01

    Self-ignited, naturally occurring coal fires and fires resulting from human activities persist for decades in underground coal mines, coal waste piles, and unmined coal beds. These uncontrolled coal fires occur in all coal-bearing parts of the world (Stracher, 2007) and pose multiple threats to the global environment because they emit greenhouse gases - carbon dioxide (CO2), and methane (CH4) - as well as mercury (Hg), carbon monoxide (CO), and other toxic substances (fig. 1). The contribution of coal fires to the global pool of atmospheric CO2 is little known but potentially significant. For China, the world's largest coal producer, it is estimated that anywhere between 10 million and 200 million metric tons (Mt) of coal reserves (about 0.5 to 10 percent of production) is consumed annually by coal fires or made inaccessible owing to fires that hinder mining operations (Rosema and others, 1999; Voigt and others, 2004). At this proportion of production, coal amounts lost to coal fires worldwide would be two to three times that for China. Assuming this coal has mercury concentrations similar to those in U.S. coals, a preliminary estimate of annual Hg emissions from coal fires worldwide is comparable in magnitude to the 48 tons of annual Hg emissions from all U.S. coal-fired power-generating stations combined (U.S. Environmental Protection Agency, 2002). In the United States, the combined cost of coal-fire remediation projects, completed, budgeted, or projected by the U.S. Department of the Interior's Office of Surface Mining Reclamation and Enforcement (OSM), exceeds $1 billion, with about 90% of that in two States - Pennsylvania and West Virginia (Office of Surface Mining Enforcement and Reclamation, 2008; fig. 2). Altogether, 15 States have combined cumulative OSM coal-fire project costs exceeding $1 million, with the greatest overall expense occurring in States where underground coal fires are predominant over surface fires, reflecting the greater cost of

  7. The magnetohydrodynamics Coal-Fired Flow Facility

    SciTech Connect

    Not Available

    1991-07-01

    In this quarterly technical progress report, UTSI summarizes the results of a multi-task research and development project directed toward the development of the technology for the commercialization of the steam bottoming plant for the MHD steam combined cycle power plant. The report covers the final test in a 2000-hour proof-of-concept (POC) test series on eastern coal, the plans and progress for the facility modifications and the conduct of the POC tests to be conducted with western coal. Results summarized in the report include chloride emissions from the particle removal (ESP/BH) processes, nitrogen and sulfur oxide emissions for various tests conditions, measurements of particulate control efficiency and management of the facility holding ponds during testing. Activities relating to corrosion and deposition probe measurements during testing and the fouling of heat transfer tubes and interaction with sootblowing cycles are summarized. The performance of both UTSI and Mississippi State University (MSU) advanced diagnostic systems is reported. Significant administrative and contractual actions are included. 2 refs., 28 figs., 7 tabs.

  8. Introduction to combined cycles

    NASA Astrophysics Data System (ADS)

    Moore, M. J.

    Ideas and concepts underlying the technology of combined cycles including the scientific principles involved and the reasons these cycles are in fashion at the present time, are presented. A cycle is a steady flow process for conversion of heat energy into work, in which a working medium passes through a range of states, returning to its original state. Cycles for power production are the steam cycle, which is a closed cycle, and the gas turbine, which represents an open cycle. Combined cycle thermodynamic parameters, are discussed. The general arrangement of the plant is outlined and important features of their component parts described. The scope for future development is discussed. It is concluded that for the next few years the natural gas fired combined cycle will be the main type of plant installed for electricity generation and cogeneration. Whilst gas turbines may not increase substantially in unit size, there remains scope for further increase in firing temperature with consequent increase in cycle performance. However the larger global reserves of coal are providing an incentive to the development of plant for clean coal combustion using the inherent advantage of the combined cycle to attain high efficiencies.

  9. Airbreathing combined cycle engine systems

    NASA Technical Reports Server (NTRS)

    Rohde, John

    1992-01-01

    The Air Force and NASA share a common interest in developing advanced propulsion systems for commercial and military aerospace vehicles which require efficient acceleration and cruise operation in the Mach 4 to 6 flight regime. The principle engine of interest is the turboramjet; however, other combined cycles such as the turboscramjet, air turborocket, supercharged ejector ramjet, ejector ramjet, and air liquefaction based propulsion are also of interest. Over the past months careful planning and program implementation have resulted in a number of development efforts that will lead to a broad technology base for those combined cycle propulsion systems. Individual development programs are underway in thermal management, controls materials, endothermic hydrocarbon fuels, air intake systems, nozzle exhaust systems, gas turbines and ramjet ramburners.

  10. CONTROLLING MULTIPLE EMISSIONS FROM COAL-FIRED POWER PLANTS

    EPA Science Inventory

    The paper presents and analyzes nine existing and novel control technologies designed to achieve multipollutant emissions reductions. It provides an evaluation of multipollutant emission control technologies that are potentially available for coal-fired power plants of 25 MW capa...

  11. Numerical Modelling by FLAC on Coal Fires in North China

    NASA Astrophysics Data System (ADS)

    Gusat, D.; Drebenstedt, C.

    2009-04-01

    Coal fires occur in many countries all over the world (e.g. Australia, China, India, Indonesia, USA and Russia) in underground and on surface. In China the most coal fires occur especially in the North. Economical and environmental damages are the negative effects of the coal fires: coal fires induce open fractures and fissures within the seam and neighbouring rocks. So that these are the predominant pathways for oxygen flow and exhaust gases from a coal fire. All over northern China there are a large number of coal fires, which cause and estimated yearly coal loss of between 100 and 200 million tons ([1], [2], [3]). Spontaneous combustion is a very complicated process and is influenced by number of factors. The process is an exothermic reaction in which the heat generated is dissipated by conduction to the surrounding environment, by radiation, by convection to the ventilation flow, and in some cases by evaporation of moisture from the coal [4]. The coal fires are very serious in China, and the dangerous extent of spontaneous combustion is bad which occupies about 72.9% in mining coal seams. During coal mining in China, the coal fires of spontaneous combustion are quite severity. The dangerous of coal spontaneous combustion has been in 56% of state major coalmines [5]. The 2D and 3D-simulation models describing coal fire damages are strong tools to predict fractures and fissures, to estimate the risk of coal fire propagation into neighbouring seams, to test and evaluate coal fire fighting and prevention methods. The numerical simulations of the rock mechanical model were made with the software for geomechanical and geotechnical calculations, the programs FLAC and FLAC3D [6]. To fight again the coal fires, exist several fire fighting techniques. Water, slurries or liquefied nitrogen can be injected to cool down the coal or cut of air supply with the backfill and thereby extinct the fire. Air supply also can be cut of by covering the coal by soil or sealing of the

  12. Coal-Fired Power Plant Heat Rate Reductions

    EPA Pesticide Factsheets

    View a report that identifies systems and equipment in coal-fired power plants where efficiency improvements can be realized, and provides estimates of the resulting net plant heat rate reductions and costs for implementation.

  13. H gas turbine combined cycle

    SciTech Connect

    Corman, J.

    1995-10-01

    A major step has been taken in the development of the Next Power Generation System - {open_quotes}H{close_quotes} Technology Combined Cycle. This new gas turbine combined-cycle system increases thermal performance to the 60% level by increasing gas turbine operating temperature to 1430 C (2600 F) at a pressure ratio of 23 to 1. Although this represents a significant increase in operating temperature for the gas turbine, the potential for single digit NOx levels (based upon 15% O{sub 2}, in the exhaust) has been retained. The combined effect of performance increase and environmental control is achieved by an innovative closed loop steam cooling system which tightly integrates the gas turbine and steam turbine cycles. The {open_quotes}H{close_quotes} Gas Turbine Combined Cycle System meets the goals and objectives of the DOE Advanced Turbine System Program. The development and demonstration of this new system is being carried out as part of the Industrial/Government cooperative agreement under the ATS Program. This program will achieve first commercial operation of this new system before the end of the century.

  14. ADVANCED MONITORING TO IMPROVE COMBUSTION TURBINE/COMBINED CYCLE CT/(CC) RELIABILITY, AVAILABILITY AND MAINTAINABILITY (RAM)

    SciTech Connect

    Leonard Angello

    2004-09-30

    Power generators are concerned with the maintenance costs associated with the advanced turbines that they are purchasing. Since these machines do not have fully established operation and maintenance (O&M) track records, power generators face financial risk due to uncertain future maintenance costs. This risk is of particular concern, as the electricity industry transitions to a competitive business environment in which unexpected O&M costs cannot be passed through to consumers. These concerns have accelerated the need for intelligent software-based diagnostic systems that can monitor the health of a combustion turbine in real time and provide valuable information on the machine's performance to its owner/operators. EPRI, Impact Technologies, Boyce Engineering, and Progress Energy have teamed to develop a suite of intelligent software tools integrated with a diagnostic monitoring platform that will, in real time, interpret data to assess the ''total health'' of combustion turbines. The Combustion Turbine Health Management System (CTHM) will consist of a series of dynamic link library (DLL) programs residing on a diagnostic monitoring platform that accepts turbine health data from existing monitoring instrumentation. The CTHM system will be a significant improvement over currently available techniques for turbine monitoring and diagnostics. CTHM will interpret sensor and instrument outputs, correlate them to a machine's condition, provide interpretative analyses, project servicing intervals, and estimate remaining component life. In addition, it will enable real-time anomaly detection and diagnostics of performance and mechanical faults, enabling power producers to more accurately predict critical component remaining useful life and turbine degradation.

  15. ADVANCED MONITORING TO IMPROVE COMBUSTION TURBINE/COMBINED CYCLE CT/(CC) RELIABILITY, AVAILABILITY AND MAINTAINABILITY (RAM)

    SciTech Connect

    Leonard Angello

    2004-03-31

    Power generators are concerned with the maintenance costs associated with the advanced turbines that they are purchasing. Since these machines do not have fully established operation and maintenance (O&M) track records, power generators face financial risk due to uncertain future maintenance costs. This risk is of particular concern, as the electricity industry transitions to a competitive business environment in which unexpected O&M costs cannot be passed through to consumers. These concerns have accelerated the need for intelligent software-based diagnostic systems that can monitor the health of a combustion turbine in real time and provide valuable information on the machine's performance to its owner/operators. EPRI, Impact Technologies, Boyce Engineering, and Progress Energy have teamed to develop a suite of intelligent software tools integrated with a diagnostic monitoring platform that will, in real time, interpret data to assess the ''total health'' of combustion turbines. The Combustion Turbine Health Management System (CTHM) will consist of a series of dynamic link library (DLL) programs residing on a diagnostic monitoring platform that accepts turbine health data from existing monitoring instrumentation. The CTHM system will be a significant improvement over currently available techniques for turbine monitoring and diagnostics. CTHM will interpret sensor and instrument outputs, correlate them to a machine's condition, provide interpretative analyses, project servicing intervals, and estimate remaining component life. In addition, it will enable real-time anomaly detection and diagnostics of performance and mechanical faults, enabling power producers to more accurately predict critical component remaining useful life and turbine degradation.

  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. 7, July--September 1993

    SciTech Connect

    Not Available

    1993-11-01

    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. Foster Wheeler Development Corporation (FWDC) is leading a team of companies involved in this effort. The power generating system being developed in this project will be an improvement over current coal-fired systems. Goals have been specified that relate to the efficiency, emissions, costs, and general operation of the system. The system proposed to meet these goals is a combined-cycle system where air for a gas turbine is indirectly heated to approximately 1800{degrees}F in furnaces fired with coal-derived fuels and then directly heated in a natural-gas-fired combustor to about 2400{degrees}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. A simplified process flow diagram is shown in Figure 1.

  17. ADVANCED MONITORING TO IMPROVE COMBUSTION TURBINE/COMBINED CYCLE CT/(CC) RELIABILITY, AVAILABILITY AND MAINTAINABILITY (RAM)

    SciTech Connect

    Leonard Angello

    2003-09-30

    Power generators are concerned with the maintenance costs associated with the advanced turbines that they are purchasing. Since these machines do not have fully established operation and maintenance (O&M) track records, power generators face financial risk due to uncertain future maintenance costs. This risk is of particular concern, as the electricity industry transitions to a competitive business environment in which unexpected O&M costs cannot be passed through to consumers. These concerns have accelerated the need for intelligent software-based diagnostic systems that can monitor the health of a combustion turbine in real time and provide valuable information on the machine's performance to its owner/operators. Such systems would interpret sensor and instrument outputs, correlate them to the machine's condition, provide interpretative analyses, forward projections of servicing intervals, estimate remaining component life, and identify faults. EPRI, Impact Technologies, Boyce Engineering, and Progress Energy have teamed to develop a suite of intelligent software tools integrated with a diagnostic monitoring platform that will, in real time, interpret data to assess the ''total health'' of combustion turbines. The Combustion Turbine Health Management System (CTHM) will consist of a series of dynamic link library (DLL) programs residing on a diagnostic monitoring platform that accepts turbine health data from existing monitoring instrumentation. The CTHM system will be a significant improvement over currently available techniques for turbine monitoring and diagnostics. CTHM will interpret sensor and instrument outputs, correlate them to a machine's condition, provide interpretative analyses, project servicing intervals, and estimate remaining component life. In addition, it will enable real-time anomaly detection and diagnostics of performance and mechanical faults, enabling power producers to more accurately predict critical component remaining useful life and

  18. Coal fired powerhouse wastewater pressure filtration

    SciTech Connect

    Martin, H.L.; Diener, G.A.

    1994-05-01

    The Savannah River Site`s permit for construction of an industrial wastewater treatment facility to remove solids from the boiler blow-down and wet ash scrubber effluent of the A-Area coal fired powerhouse was rejected. Conventional clarification technology would not remove arsenic from the combined effluent sufficient to achieve human health criteria in the small receiving surface stream. Treatability studies demonstrated that an existing facility, which will no longer be needed for metal finishing wastewater, can very efficiently process the powerhouse wastewater to less than 35 {mu}g/L arsenic. Use of cationic and anionic polymers to flocculate both the wastewater and filter aid solids formed a ``bridged cake`` with exceptionally low resistance to flow. This will double the capacity of the Oberlin pressure filters with the Tyvek T-980 sub micron filter media. The affects of high sheer agitation and high temperature in the raw wastewater on the filtration process were also studied and adequate controls were demonstrated.

  19. ENGINEERING DEVELOPMENT OF COAL-FIRED HIGH-PERFORMANCE POWER SYSTEMS

    SciTech Connect

    Unknown

    1999-02-01

    A High Performance Power System (HIPPS) is being developed. This system is a coal-fired, combined cycle plant with indirect heating of gas turbine air. Foster Wheeler Development Corporation and a team consisting of Foster Wheeler Energy Corporation, Bechtel Corporation, University of Tennessee Space Institute and Westinghouse Electric Corporation are developing this system. In Phase 1 of the project, a conceptual design of a commercial plant was developed. Technical and economic analyses indicated that the plant would meet the goals of the project which include a 47 percent efficiency (HHV) and a 10 percent lower cost of electricity than an equivalent size PC plant. The concept uses a pyrolysis process to convert coal into fuel gas and char. The char is fired in a High Temperature Advanced Furnace (HITAF). The HITAF is a pulverized fuel-fired boiler/air heater where steam is generated and gas turbine air is indirectly heated. The fuel gas generated in the pyrolyzer is then used to heat the gas turbine air further before it enters the gas turbine. The project is currently in Phase 2 which includes engineering analysis, laboratory testing and pilot plant testing. Research and development is being done on the HIPPS systems that are not commercial or being developed on other projects. Pilot plant testing of the pyrolyzer subsystem and the char combustion subsystem are being done separately, and after each experimental program has been completed, a larger scale pyrolyzer will be tested at the Power Systems Development Facility (PSDF) in Wilsonville, AL. The facility is equipped with a gas turbine and a topping combustor, and as such, will provide an opportunity to evaluate integrated pyrolyzer and turbine operation. This report addresses the areas of technical progress for this quarter. A general arrangement drawing of the char transfer system was forwarded to SCS for their review. Structural steel drawings were used to generate a three-dimensional model of the char

  20. 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

    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.

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

    SciTech Connect

    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.

  2. Characterization of open-cycle coal-fired MHD generators

    NASA Astrophysics Data System (ADS)

    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 is detailed. In addition, studies related to understanding arcing phenomena in the vicinity of an anode are reported.

  3. Environmental impact assessment at the Coal-Fired Flow Facility

    SciTech Connect

    Casey, J L; Holt, J K

    1992-08-01

    The environmental program for the Coal-Fired Flow Facility (CFFF) has been established to monitor and evaluate facility operations on a continuing basis in accordance with the purpose and policy of the National Environmental Policy Act (NEPA). Program objectives include: (1) Compliance with all applicable Federal, State, and local effluent regulations and DOE orders; (2) Compliance with commitments made in the ``Environmental Monitoring Program for the MHD Coal Fired Flow Facility at University of Tennessee Space Institute``; (3) Evaluation of the effectiveness of effluent treatment and control; (4) Assessing the potential impact of CFFF operations on the environment. (VC)

  4. Temporal trends and spatial variation characteristics of primary air pollutants emissions from coal-fired industrial boilers in Beijing, China.

    PubMed

    Xue, Yifeng; Tian, Hezhong; Yan, Jing; Zhou, Zhen; Wang, Junling; Nie, Lei; Pan, Tao; Zhou, Junrui; Hua, Shenbing; Wang, Yong; Wu, Xiaoqing

    2016-06-01

    Coal-fired combustion is recognized as a significant anthropogenic source of atmospheric compounds in Beijing, causing heavy air pollution events and associated deterioration in visibility. Obtaining an accurate understanding of the temporal trends and spatial variation characteristics of emissions from coal-fired industrial combustion is essential for predicting air quality changes and evaluating the effectiveness of current control measures. In this study, an integrated emission inventory of primary air pollutants emitted from coal-fired industrial boilers in Beijing is developed for the period of 2007-2013 using a technology-based approach. Future emission trends are projected through 2030 based on current energy-related and emission control policies. Our analysis shows that there is a general downward trend in primary air pollutants emissions because of the implementation of stricter local emission standards and the promotion by the Beijing municipal government of converting from coal-fired industrial boilers to gas-fired boilers. However, the ratio of coal consumed by industrial boilers to total coal consumption has been increasing, raising concerns about the further improvement of air quality in Beijing. Our estimates indicate that the total emissions of PM10, PM2.5, SO2, NOx, CO and VOCs from coal-fired industrial boilers in Beijing in 2013 are approximately 19,242 t, 13,345 t, 26,615 t, 22,965 t, 63,779 t and 1406 t, respectively. Under the current environmental policies and relevant energy savings and emission control plans, it may be possible to reduce NOx and other air pollutant emissions by 94% and 90% by 2030, respectively, if advanced flue gas purification technologies are implemented and coal is replaced with natural gas in the majority of existing boilers.

  5. Using plasma-fuel systems at Eurasian coal-fired thermal power stations

    NASA Astrophysics Data System (ADS)

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

    2009-06-01

    The development of plasma technology for igniting solid fuels at coal-fired thermal power stations in Russia, Kazakhstan, China, and other Eurasian countries is briefly reviewed. Basic layouts and technical and economic characteristics of plasma-fuel systems installed in different coal-fired boiles are considered together with some results from using these systems at coal-fired thermal power stations.

  6. Biomass Gasification Combined Cycle

    SciTech Connect

    Judith A. Kieffer

    2000-07-01

    Gasification combined cycle continues to represent an important defining technology area for the forest products industry. The ''Forest Products Gasification Initiative'', organized under the Industry's Agenda 2020 technology vision and supported by the DOE ''Industries of the Future'' program, is well positioned to guide these technologies to commercial success within a five-to ten-year timeframe given supportive federal budgets and public policy. Commercial success will result in significant environmental and renewable energy goals that are shared by the Industry and the Nation. The Battelle/FERCO LIVG technology, which is the technology of choice for the application reported here, remains of high interest due to characteristics that make it well suited for integration with the infrastructure of a pulp production facility. The capital cost, operating economics and long-term demonstration of this technology area key input to future economically sustainable projects and must be verified by the 200 BDT/day demonstration facility currently operating in Burlington, Vermont. The New Bern application that was the initial objective of this project is not currently economically viable and will not be implemented at this time due to several changes at and around the mill which have occurred since the inception of the project in 1995. The analysis shows that for this technology, and likely other gasification technologies as well, the first few installations will require unique circumstances, or supportive public policies, or both to attract host sites and investors.

  7. EMISSIONS OF SULFUR TRIOXIDE FROM COAL-FIRED POWER PLANTS

    EPA Science Inventory

    Emissions of sulfur trioxide (SO3) are a key component of plume opacity and acid deposition. Consequently, these emissions need to be low enough not to cause opacity violations and acid deposition. Generally, a small fraction of sulfur in coal is converted to SO3 in coal-fired co...

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

    SciTech Connect

    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.

  9. Adsorbents for capturing mercury in coal-fired boiler flue gas.

    PubMed

    Yang, Hongqun; Xu, Zhenghe; Fan, Maohong; Bland, Alan E; Judkins, Roddie R

    2007-07-19

    This paper reviews recent advances in the research and development of sorbents used to capture mercury from coal-fired utility boiler flue gas. Mercury emissions are the source of serious health concerns. Worldwide mercury emissions from human activities are estimated to be 1000 to 6000 t/annum. Mercury emissions from coal-fired power plants are believed to be the largest source of anthropogenic mercury emissions. Mercury emissions from coal-fired utility boilers vary in total amount and speciation, depending on coal types, boiler operating conditions, and configurations of air pollution control devices (APCDs). The APCDs, such as fabric filter (FF) bag house, electrostatic precipitator (ESP), and wet flue gas desulfurization (FGD), can remove some particulate-bound and oxidized forms of mercury. Elemental mercury often escapes from these devices. Activated carbon injection upstream of a particulate control device has been shown to have the best potential to remove both elemental and oxidized mercury from the flue gas. For this paper, NORIT FGD activated carbon was extensively studied for its mercury adsorption behavior. Results from bench-, pilot- and field-scale studies, mercury adsorption by coal chars, and a case of lignite-burned mercury control were reviewed. Studies of brominated carbon, sulfur-impregnated carbon and chloride-impregnated carbon were also reviewed. Carbon substitutes, such as calcium sorbents, petroleum coke, zeolites and fly ash were analyzed for their mercury-adsorption performance. At this time, brominated activated carbon appears to be the best-performing mercury sorbent. A non-injection regenerable sorbent technology is briefly introduced herein, and the issue of mercury leachability is briefly covered. Future research directions are suggested.

  10. Control strategies of atmospheric mercury emissions from coal-fired power plants in China.

    PubMed

    Tian, Hezhong; Wang, Yan; Cheng, Ke; Qu, Yiping; Hao, Jiming; Xue, Zhigang; Chai, Fahe

    2012-05-01

    Atmospheric mercury (Hg) emission from coal is one of the primary sources of anthropogenic discharge and pollution. China is one of the few countries in the world whose coal consumption constitutes about 70% of total primary energy, and over half of coals are burned directly for electricity generation. Atmospheric emissions of Hg and its speciation from coal-fired power plants are of great concern owing to their negative impacts on regional human health and ecosystem risks, as well as long-distance transport. In this paper, recent trends of atmospheric Hg emissions and its species split from coal-fired power plants in China during the period of 2000-2007 are evaluated, by integrating each plant's coal consumption and emission factors, which are classified by different subcategories of boilers, particulate matter (PM) and sulfur dioxide (SO2) control devices. Our results show that the total Hg emissions from coal-fired power plants have begun to decrease from the peak value of 139.19 t in 2005 to 134.55 t in 2007, though coal consumption growing steadily from 1213.8 to 1532.4 Mt, which can be mainly attributed to the co-benefit Hg reduction by electrostatic precipitators/fabric filters (ESPs/FFs) and wet flue gas desulfurization (WFGD), especially the sharp growth in installation of WFGD both in the new and existing power plants since 2005. In the coming 12th five-year-plan, more and more plants will be mandated to install De-NO(x) (nitrogen oxides) systems (mainly selective catalytic reduction [SCR] and selective noncatalytic reduction [SNCR]) for minimizing NO(x) emission, thus the specific Hg emission rate per ton of coal will decline further owing to the much higher co-benefit removal efficiency by the combination of SCR + ESPs/FFs + WFGD systems. Consequently, SCR + ESPs/FFs + WFGD configuration will be the main path to abate Hg discharge from coal-fired power plants in China in the near future. However advanced specific Hg removal technologies are necessary

  11. Coal-fired high performance power generating system. Quarterly progress report, July 1, 1993--September 30, 1993

    SciTech Connect

    Not Available

    1993-12-31

    This report covers work carried out under Task 3, Preliminary Research and Development, and Task 4, Commercial Generating Plant Design, under contract DE-AC22-92PC91155, {open_quotes}Engineering Development of a Coal Fired High Performance Power Generation System{close_quotes} between DOE Pittsburgh Energy Technology Center and United Technologies Research Center. 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 {le} 25% NSPS; cost {ge} 65% of heat input; and all solid wastes benign. The report discusses progress in cycle analysis, chemical reactor modeling, ash deposition rate calculations for HITAF (high temperature advanced furnace) convective air heater, air heater materials, and deposit initiation and growth on ceramic substrates.

  12. Use of foaming mud cement to terminate underground coal fires and to control subsidence of burn cavities. Final report

    SciTech Connect

    Lucero, R.F.

    1988-09-29

    Foaming Mud Cement (FMC) is a class of materials related to cellular cement studied and developed for the purpose of addressing Abandoned Mine Land problems. During the 2-year program, significant advances were made using a specific methodology that properly employed will enable the successful termination of many surface and underground coal mine fires. Fundamental but key developments attained were: the ability to effectively isolate burning coal from the available air by effectively penetrating burning coal rubble with heat-resistive FMC and encapsulating and isolation of a wide range of coal particle sizes, resulting in permanent coal-fire termination by air exclusion. The materials developed were specifically designed to terminate underground coal fires and preventing further subsidence.

  13. Thermal surface characteristics of coal fires 1 results of in-situ measurements

    NASA Astrophysics Data System (ADS)

    Zhang, Jianzhong; Kuenzer, Claudia

    2007-12-01

    Natural underground coal fires are fires in coal seams occurring subsurface. The fires are ignited through a process named spontaneous combustion, which occurs based on a natural reaction but is usually triggered through human interaction. Coal mining activities expose coal to the air. This leads to the exothermal oxidation of the carbon in the coal with the air's oxygen to CO 2 and - under certain circumstances - to spontaneous combustion. Coal fires occur in many countries world wide - however, currently the Chinese coal mining industry faces the biggest problems with coal fires. Coal fires destroy the valuable resource coal and furthermore lead to many environmental degradation phenomena such as the deterioration of surrounding vegetation, land subsidence and the emission of toxic gasses (CO, N 2O). They additionally contribute to the emission of green house relevant gasses such as CO 2 and CH 4 to the atmosphere. In this paper we present thermal characteristics of coal fires as measured in-situ during a field campaign to the Wuda coal fire area in south-central Inner Mongolia, China. Thermal characteristics include temperature anomaly measurements at the surface, spatial surface temperature profiles of fire areas and unaffected background areas, diurnal temperature profiles, and temperature measurements inside of coal fire induced cracks in the overlying bedrock. For all the measurements the effects of uneven solar heating through influences of slope and aspect are considered. Our findings show that coal fires result in strong or subtle thermal surface anomalies. Especially the latter can easily be influenced by heating of the surrounding background material through solar influences. Temperature variation of background rocks with different albedo, slope, aspect or vegetation cover can substantially influence the detectability of thermal anomalies. In the worst case coal fire related thermal anomalies can be completely masked by solar patterns during the daytime

  14. Applications of coatings in coal-fired energy systems

    SciTech Connect

    Natesan, K.

    1992-03-01

    Corrosion and erosion of metallic structural materials at elevated temperatures in complex multicomponent gas environments that include particulates are potential problems in many fossil energy systems, especially those using coal as a feedstock. The use of appropriate corrosion-resistant coatings on metallic components offers an avenue to minimize material degradation and extend component life. The purpose of this paper is to review the current status of coating performance in environments typical of pulverized-coal-fired boilers, coal gasification, fluidized-bed combustion, and gas turbines. The paper discusses the complexity of environments in different systems and the coating requirements for acceptable performance. Examples illustrate the morphology and corrosion/erosion performance of coating/structural alloy combinations exposed in some of these systems. La addition, future research and development needs are discussed for coating applications in several coal-fired systems.

  15. Natural Radiation in Wastes From Coal-Fired Power Plants ...

    EPA Pesticide Factsheets

    2016-09-07

    Fly ash, bottom ash and boiler slag from coal-fired power plants contain small amounts of naturally occurring radioactive material. Naturally radioactive materials that were in coal before processing mostly end up in fly ash, bottom ash and boiler slag. About 80 to 90 percent of fly ash, bottom ash and boiler slag are non-radioactive minerals, typically silicon, aluminum, iron and calcium.

  16. System studies of coal fired-closed cycle MHD for central station power plants

    NASA Technical Reports Server (NTRS)

    Zauderer, B.

    1976-01-01

    This paper presents a discussion of the closed cycle MHD results obtained in a recent study of various advanced energy conversion (ECAS) power systems. The study was part of the first phase of this ECAS study. Since this was the first opportunity to evaluate the coal fired closed cycle MHD system, a number of iterations were required to partially optimize the system. The present paper deals with the latter part of the study in which the direct coal fired, MHD topping-steam bottoming cycle was established as the current choice for central station power generation. The emphasis of the paper is on the background assumptions and the conclusions that can be drawn from the closed cycle MHD analysis. The author concludes that closed cycle MHD has efficiencies comparable to that of open cycle MHD and that both systems are considerably more efficient than the other system studies in Phase 1 of the GE ECAS. Its cost will possibly be slightly higher than that of the open cycle MHD system. Also, with reasonable fuel escalation assumptions, both systems can produce lower cost electricity than conventional steam power plants. Suggestions for further work in closed cycle MHD components and systems is made.

  17. Direct estimation of diffuse gaseous emissions from coal fires: current methods and future directions

    USGS Publications Warehouse

    Engle, Mark A.; Olea, Ricardo A.; O'Keefe, Jennifer M. K.; Hower, James C.; Geboy, Nicholas J.

    2013-01-01

    Coal fires occur in nature spontaneously, contribute to increases in greenhouse gases, and emit atmospheric toxicants. Increasing interest in quantifying coal fire emissions has resulted in the adaptation and development of specialized approaches and adoption of numerical modeling techniques. Overview of these methods for direct estimation of diffuse gas emissions from coal fires is presented in this paper. Here we take advantage of stochastic Gaussian simulation to interpolate CO2 fluxes measured using a dynamic closed chamber at the Ruth Mullins coal fire in Perry County, Kentucky. This approach allows for preparing a map of diffuse gas emissions, one of the two primary ways that gases emanate from coal fires, and establishing the reliability of the study both locally and for the entire fire. Future research directions include continuous and automated sampling to improve quantification of gaseous coal fire emissions.

  18. Integrated coal gasification combined cycle

    NASA Astrophysics Data System (ADS)

    Richards, P. C.; Wijffels, J.-B.; Zuideveld, P. L.

    Features of the integrated coal gasification combined cycle power plants are described against the backdrop of the development and first commercial application of the shell coal gasification process. Focus is on the efficiency and excellent environmental performance of the integrated coal gasification combined power plants. Current IGCC projects are given together with an outline of some of the options for integrating coal gasification with combined cycles and also other applications of synthesis gas.

  19. Evaluation of the British Gas Corporation/Lurgi slagging gasifier in gasification-combined-cycle power generation. Final report

    SciTech Connect

    delaMora, J.A.; Grisso, J.R.; Klumpe, H.W.; Musso, A.; Roszkowski, T.R.; Thompson, B.H.; Lienhard, H.; Beyer, T.

    1985-03-01

    Plant designs, performance data, cost estimates, and bus-bar power costs were developed for a nominal 500-MW integrated coal gasification, combined-cycle power plant. The British Gas/Lurgi slagging, fixed-bed gasifier was employed to produce a clean fuel gas from coal. The clean fuel gas was fired in near-term, advanced technology combustion gas turbines operating at combustor temperatures of 2200/sup 0/F. Gas turbine exhausts were used to produce steam that was employed in a superheat/reheat main steam turbine generator to produce additional power. Duct burners and external combustors were investigated for the purpose of firing any fuel gas available in excess of that consumed by the gas turbines. The results of the study indicate that the power plant has the potential to provide base-load electricity at a cost that is 10% to 15% lower than the cost of electricity produced by a conventional coal-steam plant. In addition, the plant has the capability for producing very low-cost peak and intermediate load electricity. Harmful emissions from the plant would be considerably reduced in quantity relative to conventional coal-fired plants. 24 figures, 43 tables.

  20. Design of advanced fossil-fuel systems (DAFFS): a study of three developing technologies for coal-fired, base-load electric power generation. Integrated coal-gasification/combined power plant with BGC/Lurgi gasification process

    SciTech Connect

    Not Available

    1983-06-01

    The objectives of this report are to present the facility description, plant layouts and additional information which define the conceptual engineering design, and performance and cost estimates for the BGC/Lurgi Integrated Gasification Combined Cycle (IGCC) power plant. Following the introductory comments, the results of the British Gas Corporation (BGC)/Lurgi IGCC power plant study are summarized in Section 2. In Secion 3, a description of plant systems and facilities is provided. Section 4 includes pertinent performance information and assessments of availability, natural resource requirements and environmental impact. Estimates of capital costs, operating and maintenance costs and cost of electricity are presented in Section 5. A Bechtel Group Inc. (BGI) assessment and comments on the designs provided by Burns and Roe-Humphreys and Glasgow Synthetic Fuels, Inc. (BRHG) are included in Section 6. The design and cost estimate reports which were prepared by BRHG for those items within their scope of responsibility are included as Appendices A and B, respectively. Apendix C is an equipment list for items within the BGI scope. The design and cost estimate classifications chart referenced in Section 5 is included as Appendix D. 8 references, 18 figures, 5 tables.

  1. A coal-fired combustion system for industrial process heating applications

    SciTech Connect

    Not Available

    1992-09-03

    PETC has implemented a number of advanced combustion research projects that will lead to the establishment of a broad, commercially acceptable engineering data base for the advancement of coal as the fuel of choice for boilers, furnaces, and process heaters. Vortec Corporation's Phase III development contract DE-AC22-91PC91161 for a Coal-Fired Combustion System for Industrial Process Heating Applications'' is project funded under the DOE/PETC advanced combustion program. This advanced combustion system research program is for the development of innovative coal-fired process heaters which can be used for high temperature melting, smelling and waste vitrification processes. The process heater concepts to be developed are based on advanced glass melting and ore smelting furnaces developed and patented by Vortec Corporation. The process heater systems to be developed have multiple use applications; however, the Phase III research effort is being focused on the development of a process heater system to be used for producing value added vitrified glass products from boiler/incinerator ashes and industrial wastes. The primary objective of the Phase III project is 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 marketability. During the current reporting period, approval of Vortec's Environmental Assessment (EA) required under the National Environmental Policy Act (NEPA) was approved. The EA approval cycle took approximately 9 months. The preliminary test program which was being held in abeyance pending approval of the EA was initiated. Six preliminary test runs were successfully competed during the period. Engineering and design activities in support of the Phase III proof of concept are continuing, and modifications to the existing test system configuration to allow performance of the preliminary tests were completed.

  2. ENGINEERING DEVELOPMENT OF COAL-FIRED HIGH-PERFORMANCE POWER SYSTEMS

    SciTech Connect

    1998-11-01

    A High Performance Power System (HIPPS) is being developed. This system is a coal-fired, combined cycle plant with indirect heating of gas turbine air. Foster Wheeler Development Corporation and a team consisting of Foster Wheeler Energy Corporation, Bechtel Corporation, University of Tennessee Space Institute and Westinghouse Electric Corporation are developing this system. In Phase 1 of the project, a conceptual design of a commercial plant was developed. Technical and economic analyses indicated that the plant would meet the goals of the project which include a 47 percent efficiency (HHV) and a 10 percent lower cost of electricity than an equivalent size PC plant. The concept uses a pyrolyzation process to convert coal into fuel gas and char. The char is fired in a High Temperature Advanced Furnace (HITAF). The HITAF is a pulverized fuel-fired boiler/air heater where steam is generated and gas turbine air is indirectly heated. The fuel gas generated in the pyrolyzer is then used to heat the gas turbine air further before it enters the gas turbine. The project is currently in Phase 2, which includes engineering analysis, laboratory testing and pilot plant testing. Research and development is being done on the HIPPS systems that are not commercial or being developed on other projects. Pilot plant testing of the pyrolyzer subsystem and the char combustion subsystem are being done separately, and after each experimental program has been completed, a larger scale pyrolyzer will be tested at the Power Systems Development Facility (PSDF) in Wilsonville, Al. The facility is equipped with a gas turbine and a topping combustor, and as such, will provide an opportunity to evaluate integrated pyrolyzer and turbine operation. The design of the char burner was completed during this quarter. The burner is designed for arch-firing and has a maximum capacity of 30 MMBtu/hr. This size represents a half scale version of a typical commercial burner. The burner is outfitted with

  3. Thermal energy storage for integrated gasification combined-cycle power plants

    SciTech Connect

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

    1990-07-01

    There are increasingly strong indications that the United States will face widespread electrical power generating capacity constraints in the 1990s; most regions of the country could experience capacity shortages by the year 2000. The demand for new generating capacity occurs at a time when there is increasing emphasis on environmental concerns. The integrated gasification combined-cycle (IGCC) power plant is an example of an advanced coal-fired technology that will soon be commercially available. The IGCC concept has proved to be efficient and cost-effective while meeting all current environmental regulations on emissions; however, the operating characteristics of the IGCC system have limited it to base load applications. The integration of thermal energy storage (TES) into an IGCC plant would allow it to meet cyclic loads while avoiding undesirable operating characteristics such as poor turn-down capability, impaired part-load performance, and long startup times. In an IGCC plant with TES, a continuously operated gasifier supplies medium-Btu fuel gas to a continuously operated gas turbine. The thermal energy from the fuel gas coolers and the gas turbine exhaust is stored as sensible heat in molten nitrate salt; heat is extracted during peak demand periods to produce electric power in a Rankine steam power cycle. The study documented in this report was conducted by Pacific Northwest Laboratory (PNL) and consists of a review of the technical and economic feasibility of using TES in an IGCC power plant to produce intermediate and peak load power. The study was done for the US Department of Energy's (DOE) Office of Energy Storage and Distribution. 11 refs., 5 figs., 18 tabs.

  4. The development of a coal-fired combustion system for industrial process heating applications

    SciTech Connect

    Not Available

    1992-07-16

    PETC has implemented a number of advanced combustion research projects that will lead to the establishment of a broad, commercially acceptable engineering data base for the advancement of coal as the fuel of choice for boilers, furnaces, and process heaters. Vortec Corporation's Coal-Fired Combustion System for Industrial Process Heating Applications has been selected for Phase III development under contract DE-AC22-91PC91161. This advanced combustion system research program is for the development of innovative coal-fired process heaters which can be used for high temperature melting, smelting, recycling, and refining processes. The process heater concepts to be developed are based on advanced glass melting and ore smelting furnaces developed and patented by Vortec Corporation. The process heater systems to be developed have multiple use applications; however, the Phase HI research effort is being focused on the development of a process heater system to be used for producing glass frits and wool fiber from boiler and incinerator ashes. The primary objective of the Phase III project is 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 marketability. The economic evaluation of commercial scale CMS processes has begun. In order to accurately estimate the cost of the primary process vessels, preliminary designs for 25, 50, and 100 ton/day systems have been started under Task 1. This data will serve as input data for life cycle cost analysis performed as part of techno-economic evaluations. The economic evaluations of commercial CMS systems will be an integral part of the commercialization plan.

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

    SciTech Connect

    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.

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

    SciTech Connect

    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.

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

    DOEpatents

    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.

  8. An Initial Assessment of Coal-Fired Ship Operations.

    DTIC Science & Technology

    1984-11-01

    coal bunker. This line can be used to spray seawater into the coal bunker. However, since there is no way to seal off the chutes at the bottom of the...plants. There was insufficient room for installing more fans and ductwork . The additional electrical load and ductwork volume would be a problem. The...imported steam coal from 1.5 million tons in 1980 to 17 million tons in 1986 -87. The new coal fired bulk carriers have been designed to "go anywhere

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

    SciTech Connect

    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.

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

    SciTech Connect

    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)

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

    SciTech Connect

    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)

  12. System studies of coal fired-closed cycle MHD for central station power plants

    NASA Technical Reports Server (NTRS)

    Zauderer, B.

    1976-01-01

    This paper presents a discussion of the closed-cycle MHD results obtained in a recent study of various advanced energy-conversion power systems. The direct coal-fired MHD topping-steam bottoming cycle was established as the current choice for central station power generation. Emphasis is placed on the background assumptions and the conclusions that can be drawn from the closed-cycle MHD analysis. It is concluded that closed-cycle MHD has efficiencies comparable to that of open-cycle MHD. Its cost will possibly be slightly higher than that of the open-cycle MHD system. Also, with reasonable fuel escalation assumptions, both systems can produce lower-cost electricity than conventional steam power plants. Suggestions for further work in closed-cycle MHD components and systems are made.

  13. Microfine coal firing results from a retrofit gas/oil-designed industrial boiler

    SciTech Connect

    Patel, R.; Borio, R.W.; Liljedahl, G.; Miller, B.G.; Scaroni, A.W.; McGowan, J.G.

    1995-12-31

    The development of a High Efficiency Advanced Coal Combustor (HEACC) has been in progress since 1987 and the ABB Power Plant Laboratories. The initial work on this concept produced an advanced coal firing system that was capable of firing both water-based and dry pulverized coal in an industrial boiler environment. Economics may one day dictate that it makes sense to replace oil or natural gas with coal in boilers that were originally designed to burn these fuels. The objective of the current program is to demonstrate the technical and economic feasibility of retrofitting a gas/oil designed boiler to burn micronized coal. In support of this overall objective, the following specific areas were targeted: A coal handling/preparation system that can meet the technical requirements for retrofitting microfine coal on a boiler designed for burning oil or natural gas; Maintaining boiler thermal performance in accordance with specifications when burning oil or natural gas; Maintaining NOx emissions at or below 0.6 lb/MBtu; Achieving combustion efficiencies of 98% or higher; and Calculating economic payback periods as a function of key variables. The overall program has consisted of five major tasks: (1) A review of current state-of-the-art coal firing system components; (2) Design and experimental testing of a prototype HEACC burner; (3) Installation and testing of a HEACC system in a commercial retrofit application; (4) Economic evaluation of the HEACC concept for retrofit applications; and (5) Long term demonstration under commercial user demand conditions. This paper will summarize the latest key experimental results (Task 3) and the economic evaluation (Task 4) of the HEACC concept for retrofit applications. 28 figs., 6 tabs.

  14. Emissions of sulfur trioxide from coal-fired power plants.

    PubMed

    Srivastava, R K; Miller, C A; Erickson, C; Jambhekar, R

    2004-06-01

    Emissions of sulfur trioxide (SO3) are a key component of plume opacity and acid deposition. Consequently, these emissions need to be low enough to not cause opacity violations and acid deposition. Generally, a small fraction of sulfur (S) in coal is converted to SO3 in coal-fired combustion devices such as electric utility boilers. The emissions of SO3 from such a boiler depend on coal S content, combustion conditions, flue gas characteristics, and air pollution devices being used. It is well known that the catalyst used in the selective catalytic reduction (SCR) technology for nitrogen oxides control oxidizes a small fraction of sulfur dioxide in the flue gas to SO3. The extent of this oxidation depends on the catalyst formulation and SCR operating conditions. Gas-phase SO3 and sulfuric acid, on being quenched in plant equipment (e.g., air preheater and wet scrubber), result in fine acidic mist, which can cause increased plume opacity and undesirable emissions. Recently, such effects have been observed at plants firing high-S coal and equipped with SCR systems and wet scrubbers. This paper investigates the factors that affect acidic mist production in coal-fired electric utility boilers and discusses approaches for mitigating emission of this mist.

  15. Bioremediation for coal-fired power stations using macroalgae.

    PubMed

    Roberts, David A; Paul, Nicholas A; Bird, Michael I; de Nys, Rocky

    2015-04-15

    Macroalgae are a productive resource that can be cultured in metal-contaminated waste water for bioremediation but there have been no demonstrations of this biotechnology integrated with industry. Coal-fired power production is a water-limited industry that requires novel approaches to waste water treatment and recycling. In this study, a freshwater macroalga (genus Oedogonium) was cultivated in contaminated ash water amended with flue gas (containing 20% CO₂) at an Australian coal-fired power station. The continuous process of macroalgal growth and intracellular metal sequestration reduced the concentrations of all metals in the treated ash water. Predictive modelling shows that the power station could feasibly achieve zero discharge of most regulated metals (Al, As, Cd, Cr, Cu, Ni, and Zn) in waste water by using the ash water dam for bioremediation with algal cultivation ponds rather than storage of ash water. Slow pyrolysis of the cultivated algae immobilised the accumulated metals in a recalcitrant C-rich biochar. While the algal biochar had higher total metal concentrations than the algae feedstock, the biochar had very low concentrations of leachable metals and therefore has potential for use as an ameliorant for low-fertility soils. This study demonstrates a bioremediation technology at a large scale for a water-limited industry that could be implemented at new or existing power stations, or during the decommissioning of older power stations.

  16. Controlling mercury emissions from coal-fired power plants

    SciTech Connect

    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.

  17. Heat pipe technology for coal-fired power systems

    SciTech Connect

    Uherka, K.L.; Holtz, R.E.; McLennan, G.A.; Koehl, E.R.

    1985-04-01

    This report summarizes the results of heat pipe R and D activities at Argonne National Laboratory (ANL) during the 1977 to 1984 time period. The heat pipe development efforts were associated with a variety of DOE supported projects involving coal-fired prime movers for stationary power generation. The role of heat pipes for these power systems is in their potential application as thermal transport systems for integrating fluidized bed combustors (FBC) with prime movers ranging from Stirling engines in total energy systems (approx.10 MWe) to closed-cycle gas turbines in central power plants (approx.1000 MWe). The results of initial investigations at ANL demonstrated that high-temperature sodium heat pipes provided the best heat exchanger technology for integrating Stirling engines with coal-fired FBC systems. A major accomplishment included the development and validation of a computer code (ANL/HTP) which calculates heat pipe operating limits and other significant characteristics necessary for power plant design. A number of developmental and prototype heat pipes were designed and fabricated through a subcontract effort with Thermacore, Inc., and delivered to ANL for performance testing. Preliminary test results from ANL's Heat Pipe Test Facility, using induction heating and a gas-water calorimeter to establish energy balances, are given in the report. Test data obtained to date are consistent with ANL/HTP code predictions. 47 refs., 53 figs., 22 tabs.

  18. FUEL LEAN BIOMASS REBURNING IN COAL-FIRED BOILERS

    SciTech Connect

    Jeffrey J. Sweterlitsch; Robert C. Brown

    2002-07-01

    This final technical report describes research conducted between July 1, 2000, and June 30, 2002, for the project entitled ''Fuel Lean Biomass Reburning in Coal-Fired Boilers,'' DOE Award No. DE-FG26-00NT40811. Fuel Lean Biomass Reburning is a method of staging fuel within a coal-fired utility boiler to convert nitrogen oxides (NOx) to nitrogen by creating locally fuel-rich eddies, which favor the reduction of NOx, within an overall fuel lean boiler. These eddies are created by injecting a supplemental fuel source, designated as the reburn fuel, downstream of the primary combustion zone. Chopped biomass was the reburn fuel for this project. Four parameters were explored in this research: the initial oxygen concentration ranged between 1%-6%, the amount of biomass used as the reburn fuel ranged between from 0%-23% of the total % energy input, the types of biomass used were low nitrogen switchgrass and high nitrogen alfalfa, and the types of carrier gases used to inject the biomass (nitrogen and steam). Temperature profiles and final flue gas species concentrations are presented in this report. An economic evaluation of a potential full-scale installation of a Fuel-Lean Biomass Reburn system using biomass-water slurry was also performed.

  19. 180 MW demonstration of advanced tangentially-fired combustion techniques for the reduction of nitrogen oxide (NO{sub x}) emissions from coal-fired boilers. Technical progress report second quarter, 1991

    SciTech Connect

    Not Available

    1991-12-31

    ABB CE`s Low NOx Bulk Furnace Staging (LNBFS) System and Low NOx Concentric Firing System (LNCFS) are demonstrated in stepwise fashion. These systems incorporate the concept of advanced overfire air (AOFA), clustered coal nozzles, and offset air. A complete description of the installed technologies is provided in the following section. The primary objective of the Plant Lansing Smith demonstration is to determine the long-term effects of commercially available tangentially-fired low NOx combustion technologies on NOx emissions and boiler performance. Short-term tests of each technology are also being performed to provide engineering information about emissions and performance trends. A target of achieving fifty percent NOx reduction using combustion modifications has been established for the project.

  20. 500 MW demonstration of advanced wall-fired combustion techniques for the reduction of nitrogen oxide (NO{sub x}) emissions from coal-fired boilers. Third quarterly progress report, 1992: Innovative Clean Coal Technology (ICCT)

    SciTech Connect

    Not Available

    1992-12-31

    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 particulatecharacteristics and boiler efficiency. Baseline, AOFA, and LNB without AOFA test segments have been completed. Analysis of the 94 days of LNB long-term data collected show the full-load NO{sub x} emission levels to be approximately 0.65 lb/MBtu. Flyash LOI values for the LNB configuration are approximately 8 percent at full-load. Corresponding values for the AOFA configuration are 0.94 lb/MBtu and approximately 10 percent. Abbreviated diagnostic tests for the LNB+AOFA configuration indicate that at 500 MWe, NO{sub x} emissions are approximately 0.55 lb/MBtu with corresponding flyash LOI values of approximately 11 percent. For comparison, the long-term full-load, baseline NO{sub x} emission level was approximately 1.24 lb/MBtu at 5.2 percent LOI. Comprehensive testing of the LNB+AOFA configuration will be performed when the stackparticulate emissions issue is resolved. Testing of a process optimization package on Plant Hammond Unit 4 was performed during this quarter. The software was configured to minimize NO{sub x} emissions using total combustion air flow and advanced overfire air distribution as the controlled parameters. Preliminary results from this testing indicate that this package shows promise in reducing NO{sub x} emissions while maintaining or improving other boiler performance parameters.

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

    SciTech Connect

    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.

  2. 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 3A, Low NO{sub x} burner tests

    SciTech Connect

    Not Available

    1993-03-15

    This Phase 3A test report summarizes the testing activities and results for the third 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 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. Described in this report are the test plans, data measurements, and data analyses performed during the Phase 3A effort. The present report also contains sufficient background material to provide an understanding of the overall program scope, the relationship of Phase 3A to the overall program, the testing methodologies, testing procedures, and unit configuration. Results from 66 short-term tests indicate increasing NO{sub x} emissions over the load range ranging from 0.5 lb/MBtu at 300 NM to around 0.65 lb/MBtu at 480 MW. Fly ash loss-on-ignition (LOI) for these loads ranged from 5.4 to 8.6 percent. Long-term test results indicated high load (480 MW) NO{sub x} emissions of approximately 0.65 lb/MBtu. At the 300 MW mid load point, the emissions dropped to 0.47 lb/MBtu which is slightly lower than the 0.50 lb/MBtu shown for the short-term data. The annual and 30-day average achievable NO{sub x} emissions were determined to be 0.55 and 0.64 lb/MBtu, respectively, for the load scenario experienced during the Phase 3A, long-term test period. Based on the long-term test results for Phase 3A, at full-load the low NO{sub x} burners (LNB) retrofit resulted in a NO{sub x} reduction of 48 percent from baseline, while at 300 MW the reduction was approximately 50 percent. A series of tests was also conducted to evaluate the effects of various burner equipment settings and mill coal flow biasing on both NO{sub x} and LOI emissions.

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

    SciTech Connect

    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

  4. 500 MW demonstration of advanced wall-fired combustion techniques for the reduction of nitrogen oxide (NO{sub x}) emissions from coal fired boilers. Second quarterly technical progress report, [April--June 1993

    SciTech Connect

    Not Available

    1993-12-31

    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. Baseline, AOFA, and LNB without AOFA test segments have been completed. Analysis of the 94 days of LNB long-term data collected show the full-load NO{sub x} emission levels to be approximately 0.65 lb/MBtu with flyash LOI values of approximately 8 percent. Corresponding values for the AOFA configuration are 0.94 lb/MBtu and approximately 10 percent. For comparison, the long-term full-load, baseline NO{sub x} emission level was approximately 1.24 lb/MBtu at 5.2 percent LOI. Comprehensive testing of the LNB plus AOFA configuration began in May 1993 and is scheduled to end during August 1993. As of June 30, the diagnostic, performance, chemical emissions tests segments for this configuration have been conducted and 29 days of long-term, emissions data collected. Preliminary results from the May--June 1993 tests of the LNB plus AOFA system show that the full load NO{sub x} emissions are approximately 0.42 lb/MBtu with corresponding fly ash LOI values near 8 percent. This is a substantial improvement in both NO{sub x} emissions and LOI values when compared to the results obtained during the February--March 1992 abbreviated testing of this system.

  5. Liquid-metal magnetohydrodynamic system evaluation. [coal-fired designs

    NASA Technical Reports Server (NTRS)

    Holman, R. R.; Lippert, T. E.

    1976-01-01

    The present study emphasizes a direct coal-fired design using a bubbly two-component flow of sodium and argon in the MHD generator and a Rankine steam-bottoming plant. Two basic cycles were studied, corresponding to argon temperatures of 922 and 1089 K at the duct inlet. The MHD duct system consisted of multiple ducts arranged in clusters and separated by iron magnet pole pieces. The ducts, each with an output of about 100 MW, were parallel to the flow, but were connected in series electrically to provide a higher MHD voltage. With channel efficiencies of 80%, a pump efficiency of 90%, and a 45% efficient steam-bottoming plant, the overall efficiency of the 1089 K liquid-metal MHD power plant was 43%.

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

    DOEpatents

    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.

  7. Electrode materials for coal-fired MHD generators

    NASA Astrophysics Data System (ADS)

    Perkins, R. A.

    1980-10-01

    Metallic materials are evaluated as electrodes for coal fired MHD generators. A laboratory test that simulates the electrochemical and corrosive environment was developed and used to characterize electrode behavior in a diffuse current flow (nonarcing) mode of operation. High current density requires that an electron transport mechanism of current flow be maintained. With inert, stable electrodes, anode polarization occurs and ionic conduction prevails, limiting current to low values. The nature of this behavior and approaches to overcoming anodic polarization are studied as a function of electrode material, slag composition, and temperature. By operating at high temperatures and with controlled slag chemistries to produce a very fluid slag, depolarization may be achieved by mechanical mixing. Interrupted current flow are required to aid in breaking down anodic polarization.

  8. Coal fired power plant with pollution control and useful byproducts

    SciTech Connect

    Marten, J.H.; Lloyd, G.M.

    1990-04-17

    This patent describes a coal fired power plant. It comprises: coal gasification means for heating coal in the presence of an oxidant-lean atmosphere under partial coal-gasifying conditions; means for separating sulfur-containing compounds from the crude gas stream; means for converting the sulfur compound containing stream into elemental sulfur; energy-conversion means for burning a portion of the combustible gas stream and a portion of the carbonaceous char; flue gas desulfurization means for contacting the SO{sub 2}-containing flue gas with lime and limestone; gypsum desulfurization means for heating the gypsum and the remaining portion of carbonaceous char under reducing conditions utilizing burning of the remaining portion of the combustible gas stream; means for recycling the SO{sub 2}-containing gas stream to the coal gasification means.

  9. Southern thailand coal fired project: Feasibility study. Export trade information

    SciTech Connect

    1995-09-01

    This study, conducted by Black & Veatch International, was funded by the U.S. Trade and Development Agency. The report addresses various technical, environmental, and economic aspects of developing four 1,000 MW units of coal fired electric generating facilities at a site near Prachuap Khiri Khan. The study includes a cost estimate for the units and the fuel delivery port as well as the major conceptual design decisions made for the project. This volume of the report is the Feasibility Study and is divided into the following sections: (1) Introduction/Summary; (2) Generation Planning Study; (3) Site Selection Study; (4) Project Description; (5) Fuel Resource Assessment; (6) Water Resource Assessment; (7) Technical Information to Support the Environmental Impact Assessment; (8) Plant Conceptual Design; (9) Transmission Interconnection; (10) Project Capital Cost Estimate; (11) Project Schedule; (12) Project Implementation Plan; (13) Project Risk Analysis.

  10. Modeling of a coal-fired natural circulation boiler

    SciTech Connect

    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.

  11. Repowering a small coal-fired power plant

    SciTech Connect

    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.

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

    SciTech Connect

    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

  13. Biomass cofiring in full-sized coal-fired boilers

    SciTech Connect

    Plasynski, S.I.; Costello, R.; Hughes, E.; Tillman, D.

    1999-07-01

    Biomass cofiring represents one alternative for reducing greenhouse gas emissions of carbon dioxide from fossil sources. Realizing this opportunity, the Federal Energy Technology Center (FETC), a field site of the Department of Energy (DOE), along with the EPRI, initiated a Program around two-years ago to research the feasibility of coal-fired boilers in cofiring of biomass and other waste-derived fuels. The cooperative agreement between FETC and EPRI includes cofiring at six different electric utility sites and one steam generation site. Boilers include wall-fired, tangential, cyclone, and stokers ranging in size from 15 to 500 MWe. Biomass consisting of wood (usually) and switchgrass (in two cases) will be the fuel, and pulp and plastics may be used in some waste-derived fuels cofiring tests. This paper will focus only on the biomass cofired tests in electric utility boilers.

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

    SciTech Connect

    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.

  15. Corrosion probes for fireside monitoring in coal-fired boilers

    SciTech Connect

    Covino, Bernard S., Jr.; Bullard, Sophie J.; Ziomek-Moroz, M.; Holcomb, Gordon R.

    2005-01-01

    Corrosion probes are being developed and combined with an existing measurement technology to provide a tool for assessing the extent of corrosion of metallic materials on the fireside in coal-fired boilers. The successful development of this technology will provide power plant operators the ability to (1) accurately monitor metal loss in critical regions of the boiler, such as waterwalls, superheaters, and reheaters; and (2) use corrosion rates as process variables. In the former, corrosion data could be used to schedule maintenance periods and in the later, processes can be altered to decrease corrosion rates. The research approach involves laboratory research in simulated environments that will lead to field tests of corrosion probes in coal-fired boilers. Laboratory research has already shown that electrochemically-measured corrosion rates for ash-covered metals are similar to actual mass loss corrosion rates. Electrochemical tests conducted using a potentiostat show the corrosion reaction of ash-covered probes at 500?C to be electrochemical in nature. Corrosion rates measured are similar to those from an automated corrosion monitoring system. Tests of corrosion probes made with mild steel, 304L stainless steel (SS), and 316L SS sensors showed that corrosion of the sensors in a very aggressive incinerator ash was controlled by the ash and not by the alloy content. Corrosion rates in nitrogen atmospheres tended to decrease slowly with time. The addition of oxygen-containing gases, oxygen and carbon dioxide to nitrogen caused a more rapid decrease in corrosion rate, while the addition of water vapor increased the corrosion rate.

  16. Wabash River Coal Gasification Combined Cycle Repowering Project: Clean Coal Technology Program. Environmental Assessment

    SciTech Connect

    Not Available

    1993-05-01

    The proposed project would result in a combined-cycle power plant with lower emissions and higher efficiency than most existing coal-fired power plants of comparable size. The net plant heat rate (energy content of the fuel input per useable electrical generation output; i.e., Btu/kilowatt hour) for the new repowered unit would be a 21% improvement over the existing unit, while reducing SO{sub 2} emissions by greater than 90% and limiting NO{sub x} emissions by greater than 85% over that produced by conventional coal-fired boilers. The technology, which relies on gasified coal, is capable of producing as much as 25% more electricity from a given amount of coal than today`s conventional coal-burning methods. Besides having the positive environmental benefit of producing less pollutants per unit of power generated, the higher overall efficiency of the proposed CGCC project encourages greater utilization to meet base load requirements in order to realize the associated economic benefits. This greater utilization (i.e., increased capacity factor) of a cleaner operating plant has global environmental benefits in that it is likely that such power would replace power currently being produced by less efficient plants emitting a greater volume of pollutants per unit of power generated.

  17. A coal-fired combustion system for industrial process heating applications. Quarterly technical progress report, April 1993--June 1993

    SciTech Connect

    Not Available

    1993-07-30

    Vortec Corporation`s Phase III development contract DE-AC22-91PC91161 for a ``Coal-Fired Combustion System for Industrial Process Heating Applications`` is project funded under the DOE/PETC advanced combustion program. This advanced combustion system research program is for the development of innovative coal-fired process heaters which can be used for high temperature melting, smelting and waste vitrification processes. The process heater systems to be developed have multiple use applications; however, the Phase III research effort is being focused on the development of a process heater system to be used for producing value added vitrified glass products from boiler/incinerator ashes and industrial wastes. The primary objective of the Phase III project is 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 marketability. During the past quarter, the designs of the remaining major components of the integrated system were completed and the equipment was ordered. DOE has elected to modify the scope of the existing R&D program being conducted under this contract to include testing of a simulated TSCA incinerator ash. The modification will be in the form of an additional Task (Task 8 -- TSCA Ash Testing) to the original Statement of Work.

  18. COST OF SELECTIVE CATALYTIC REDUCTION (SCR) APPLICATION FOR NOX CONTROL ON COAL-FIRED BOILERS

    EPA Science Inventory

    The report provides a methodology for estimating budgetary costs associated with retrofit applications of selective catalytic reduction (SCR) technology on coal-fired boilers. SCR is a postcombustion nitrogen oxides (NOx) control technology capable of providing NOx reductions >90...

  19. MERCURY CONTROL IN MUNICIPAL WASTE COMBUSTORS AND COAL-FIRED UTILITIES

    EPA Science Inventory

    Control of mercury (Hg) emissions from municipal waste combustors (MWCs) and coal-fired utilities has attracted attention due to current and potential regulations. Among several techniques evaluated for Hg control, dry sorbent injection (primarily injection of activated carbon) h...

  20. Quantifying greenhouse gas emissions from coal fires using airborne and ground-based methods

    USGS Publications Warehouse

    Engle, M.A.; Radke, L.F.; Heffern, E.L.; O'Keefe, J. M. K.; Smeltzer, C.D.; Hower, J.C.; Hower, J.M.; Prakash, A.; Kolker, A.; Eatwell, R.J.; ter, Schure A.; Queen, G.; Aggen, K.L.; Stracher, G.B.; Henke, K.R.; Olea, R.A.; Roman-Colon, Y.

    2011-01-01

    Coal fires occur in all coal-bearing regions of the world and number, conservatively, in the thousands. These fires emit a variety of compounds including greenhouse gases. However, the magnitude of the contribution of combustion gases from coal fires to the environment is highly uncertain, because adequate data and methods for assessing emissions are lacking. This study demonstrates the ability to estimate CO2 and CH4 emissions for the Welch Ranch coal fire, Powder River Basin, Wyoming, USA, using two independent methods: (a) heat flux calculated from aerial thermal infrared imaging (3.7-4.4td-1 of CO2 equivalent emissions) and (b) direct, ground-based measurements (7.3-9.5td-1 of CO2 equivalent emissions). Both approaches offer the potential for conducting inventories of coal fires to assess their gas emissions and to evaluate and prioritize fires for mitigation. ?? 2011.

  1. Analysis of Flue Gas Desulfurization (FGD) Processes for Potential Use on Army Coal-Fired Boilers

    DTIC Science & Technology

    1980-09-01

    TECHNICAL REPORT N-93 September 1980 ANALYSIS OF FLUE GAS DESULFURIZATION (FGD) PROCESSES FOR POTENTIAL USE ON ARMY COAL-FIRED BOILERS TECHNICAL LIBRARY...REFERENCE: Technical Report N-93, Analysis of Flue Gas Desulfurization (FGD) Ppooesses for Potential Use on Army Coal-Fired Boilers Please take a few...REPORT DOCUMENTATION PAGE 1. REPORT NUMBER CERL-TR-N-93 2. GOVT ACCESSION NO «. TITLE (end Subtitle) ANALYSIS OF FLUE GAS DESULFURIZATION (FGD

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

    SciTech Connect

    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

  3. Development of a coal fired pulse combustor for residential space heating. Phase I, Final report

    SciTech Connect

    1988-04-01

    This report presents the results of the first phase of a program for the development of a coal-fired residential combustion system. This phase consisted of the design, fabrication, testing, and evaluation of an advanced pulse combustor sized for residential space heating requirements. The objective was to develop an advanced pulse coal combustor at the {approximately} 100,000 Btu/hr scale that can be integrated into a packaged space heating system for small residential applications. The strategy for the development effort included the scale down of the feasibility unit from 1-2 MMBtu/hr to 100,000 Btu/hr to establish a baseline for isolating the effect of scale-down and new chamber configurations separately. Initial focus at the residential scale was concentrated on methods of fuel injection and atomization in a bare metal unit. This was followed by incorporating changes to the advanced chamber designs and testing of refractory-lined units. Multi-fuel capability for firing oil or gas as a secondary fuel was also established. Upon completion of the configuration and component testing, an optimum configuration would be selected for integrated testing of the pulse combustor unit. The strategy also defined the use of Dry Ultrafine Coal (DUC) for Phases 1 and 2 of the development program with CWM firing to be a product improvement activity for a later phase of the program.

  4. ESTIMATION OF NEAR SUBSURFACE COAL FIRE GAS EMISSIONS BASED ON GEOPHYSICAL INVESTIGATIONS

    NASA Astrophysics Data System (ADS)

    Chen-Brauchler, D.; Meyer, U.; Schlömer, S.; Kus, J.; Gundelach, V.; Wuttke, M.; Fischer, C.; Rueter, H.

    2009-12-01

    Spontaneous and industrially caused subsurface coal fires are worldwide disasters that destroy coal resources, cause air pollution and emit a large amount of green house gases. Especially in developing countries, such as China, India and Malaysia, this problem has intensified over the last 15 years. In China alone, 10 to 20 million tons of coal are believed to be lost in uncontrolled coal fires. The cooperation of developing countries and industrialized countries is needed to enforce internationally concerted approaches and political attention towards the problem. The Clean Development Mechanism (CDM) under the framework of the Kyoto Protocol may provide an international stage for financial investment needed to fight the disastrous situation. A Sino-German research project for coal fire exploration, monitoring and extinction applied several geophysical approaches in order to estimate the annual baseline especially of CO2 emissions from near subsurface coal fires. As a result of this project, we present verifiable methodologies that may be used in the CDM framework to estimate the amount of CO2 emissions from near subsurface coal fires. We developed three possibilities to approach the estimation based on (1) thermal energy release, (2) geological and geometrical determinations as well as (3) direct gas measurement. The studies involve the investigation of the physical property changes of the coal seam and bedrock during different burning stages of a underground coal fire. Various geophysical monitoring methods were applied from near surface to determine the coal volume, fire propagation, temperature anomalies, etc.

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

    SciTech Connect

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

    2012-03-31

    degradation in Polaris membrane performance during two months of continuous operation in a simulated flue gas environment containing up to 1,000 ppm SO{sub 2}. A successful slipstream field test at the APS Cholla power plant was conducted with commercialsize Polaris modules during this project. This field test is the first demonstration of stable performance by commercial-sized membrane modules treating actual coal-fired power plant flue gas. Process design studies show that selective recycle of CO{sub 2} using a countercurrent membrane module with air as a sweep stream can double the concentration of CO{sub 2} in coal flue gas with little energy input. This pre-concentration of CO{sub 2} by the sweep membrane reduces the minimum energy of CO{sub 2} separation in the capture unit by up to 40% for coal flue gas. Variations of this design may be even more promising for CO{sub 2} capture from NGCC flue gas, in which the CO{sub 2} concentration can be increased from 4% to 20% by selective sweep recycle. EPRI and WP conducted a systems and cost analysis of a base case MTR membrane CO{sub 2} capture system retrofitted to the AEP Conesville Unit 5 boiler. Some of the key findings from this study and a sensitivity analysis performed by MTR include: The MTR membrane process can capture 90% of the CO{sub 2} in coal flue gas and produce high-purity CO{sub 2} (>99%) ready for sequestration. CO{sub 2} recycle to the boiler appears feasible with minimal impact on boiler performance; however, further study by a boiler OEM is recommended. For a membrane process built today using a combination of slight feed compression, permeate vacuum, and current compression equipment costs, the membrane capture process can be competitive with the base case MEA process at 90% CO{sub 2} capture from a coal-fired power plant. The incremental LCOE for the base case membrane process is about equal to that of a base case MEA process, within the uncertainty in the analysis. With advanced membranes (5,000 gpu for

  6. Conceptual design of a coal-fired MHD retrofit plant. Topical report, Seed Regeneration System Study 2

    SciTech Connect

    Not Available

    1992-11-01

    Westinghouse Advanced Energy Systems (WAES), through Contract No. DE-AC22-87PC79668 funded by US DOE/PETC, is conducting a conceptual design study to evaluate a coal-fired magnetohydrodynamic (MHD) retrofit of a utility plant of sufficient size to demonstrate the technical and future economic viability of an MHD system operating within an electric utility environment. The objective of this topical report is to document continuing seed regeneration system application studies and the definition of will system integration requirements for the Scholz MHD retrofit plant design. MHD power plants require the addition of a seeding material in the form of potassium to enhance the ionization of the high temperature combustion gas in the MHD channel. This process has an added environmental advantage compared to other types of coal-fired power plants in that the potassium combines with the naturally occurring sulfur in the coal to form a potassium sulfate flyash (K{sub 2}SO{sub 4}) which can be removed from the process by appropriate particulate control equipment. Up to 100% of the Sulfur in the coal can be removed by this process thereby providing environmentally clean power plant operation that is better than required by present and anticipated future New Source Performance Standards (NSPS).

  7. Evaluation of technical feasibility of closed-cycle non-equilibrium MHD power generation with direct coal firing. Final report, Task 1

    SciTech Connect

    Not Available

    1981-11-01

    Program accomplishments in a continuing effort to demonstrate the feasibility of direct coal fired, closed cycle, magnetohydrodynamic power generation are detailed. These accomplishments relate to all system aspects of a CCMHD power generation system including coal combustion, heat transfer to the MHD working fluid, MHD power generation, heat and cesium seed recovery and overall systems analysis. Direct coal firing of the combined cycle has been under laboratory development in the form of a high slag rejection, regeneratively air cooled cyclone coal combustor concept, originated within this program. A hot bottom ceramic regenerative heat exchanger system was assembled and test fired with coal for the purposes of evaluating the catalytic effect of alumina on NO/sub x/ emission reduction and operability of the refractory dome support system. Design, procurement, fabrication and partial installation of a heat and seed recovery flow apparatus was accomplished and was based on a stream tube model of the full scale system using full scale temperatures, tube sizes, rates of temperature change and tube geometry. Systems analysis capability was substantially upgraded by the incorporation of a revised systems code, with emphasis on ease of operator interaction as well as separability of component subroutines. The updated code was used in the development of a new plant configuration, the Feedwater Cooled (FCB) Brayton Cycle, which is superior to the CCMHD/Steam cycle both in performance and cost. (WHK)

  8. Advanced design nuclear power plants: Competitive, economical electricity. An analysis of the cost of electricity from coal, gas and nuclear power plants

    SciTech Connect

    Not Available

    1992-06-01

    This report presents an updated analysis of the projected cost of electricity from new baseload power plants beginning operation around the year 2000. Included in the study are: (1) advanced-design, standardized nuclear power plants; (2) low emissions coal-fired power plants; (3) gasified coal-fired power plants; and (4) natural gas-fired power plants. This analysis shows that electricity from advanced-design, standardized nuclear power plants will be economically competitive with all other baseload electric generating system alternatives. This does not mean that any one source of electric power is always preferable to another. Rather, what this analysis indicates is that, as utilities and others begin planning for future baseload power plants, advanced-design nuclear plants should be considered an economically viable option to be included in their detailed studies of alternatives. Even with aggressive and successful conservation, efficiency and demand-side management programs, some new baseload electric supply will be needed during the 1990s and into the future. The baseload generating plants required in the 1990s are currently being designed and constructed. For those required shortly after 2000, the planning and alternatives assessment process must start now. It takes up to ten years to plan, design, license and construct a new coal-fired or nuclear fueled baseload electric generating plant and about six years for a natural gas-fired plant. This study indicates that for 600-megawatt blocks of capacity, advanced-design nuclear plants could supply electricity at an average of 4.5 cents per kilowatt-hour versus 4.8 cents per kilowatt-hour for an advanced pulverized-coal plant, 5.0 cents per kilowatt-hour for a gasified-coal combined cycle plant, and 4.3 cents per kilowatt-hour for a gas-fired combined cycle combustion turbine plant.

  9. Externally fired combined cycle demonstration

    SciTech Connect

    Orozco, N.J.; Young, S.; LaHaye, P.G.; Strom-Olsen, J.; Seger, J.L.; Pickup, H.

    1995-11-01

    Externally Fired Combined Cycles (EFCCs) can increase the amount of electricity produced from ash bearing fuels up to 40%, with overall powerplant efficiencies in excess of 45%. Achieving such high efficiencies requires high temperature-high pressure air heaters capable of driving modern gas turbines from gas streams containing the products of coal combustion. A pilot plant has been constructed in Kennebunk, Maine to provide proof of concept and evaluation of system components. Tests using pulverized Western Pennsylvania bituminous coal have been carried out since April, 1995. The ceramic air heater extracts energy from the products of coal combustion to power a gas turbine. This air heater has operated at gas inlet temperatures over 1,095 C and pressures over 7.0 atm without damage to the ceramic tube string components. Stable gas turbine operation has been achieved with energy input from the air heater and a supplementary gas fired combustor. Efforts are underway to fire the cycle on coal only, and to increase the duration of the test runs. Air heater improvements are being implemented and evaluated. These improvements include installation of a second pass of ceramic tubes and evaluation of corrosion resistant coatings on the ceramic tubes.

  10. Coal to electricity - Integrated gasification combined cycle

    NASA Astrophysics Data System (ADS)

    Corman, J. C.

    1982-04-01

    An advanced energy conversion system - the integrated gasification combined cycle (IGCC) - has been identified as an efficient and economical means of converting coal to electricity for utility application. Several demonstration projects on a near-commercial scale are approaching the construction stage. A coal conversion facility has been constructed to simulate the operational features of an IGCC. This process evaluation facility (PEF-scale) performs a dual function: (1) acquiring and processing data on the performance of the individual components - coal gasifier, gas clean up, and turbine simulator - that comprise the IGCC concept and (2) simulating the total system in an operational control mode that permits evaluation of system response to imposed load variations characteristic of utility operation. The results to date indicate that an efficient, economical IGCC can be designed so that the gasification/gas clean up plant and the power generation system operate compatibly to meet utility requirements in an environmentally acceptable manner.

  11. Condensing economizers for small coal-fired equipment

    SciTech Connect

    Butcher, T.A.; Litzke, W.

    1994-04-01

    Condensing economizers can be used to increase the thermal efficiency of boilers and furnaces. This study focuses on evaluating indirect contact economizers as applied to heating equipment burning coal-water mixtures although the results can be extended to other fuels. In addition to dry gas sensible heat, latent heat is recovered from flue gas water vapor, improving system efficiency markedly. In addition to improving thermal efficiency, condensing economizers can also capture particulates. In tests to date up to 98% total removal has been measured. The primary objectives of this project are to evaluate the most important mechanisms involved in particle capture and to enhance capture in practical systems. The intent of the work is to contribute to the ongoing program at the Department of Energy/Pittsburgh Energy Technology Center in the development of coal-fired combustion equipment. These results are expected to be most applicable to smaller scale equipment where the low temperature heat from the economizer can be used. However, interest in the use of condensing economizers for industrial and utility applications is increasing and this work certainly is relevant in these sections also. The approach involves determining thermal efficiency improvement and particulate removal efficiency (experimental), and developing models capable of predicting system performance under varied operating conditions (theoretical). Gas temperature and condensation profiles through the economizers have been predicted and overall predicted performance are consistent with test results. Mechanisms for particle removal are discussed in this paper and predicted removal efficiencies as a function of particle diameter are presented.

  12. Condensing economizers for small coal-fired equipment

    SciTech Connect

    Litzke, Wai Lin; Butcher, T.A.; Park, N.A.

    1992-05-01

    Condensing economizers can be used to increase the thermal efficiency of boilers and furnaces. This study focuses on evaluating indirect contact economizers as applied to heating equipment burning coal-water mixtures although the results can be extended to other fuels. In addition to dry gas sensible heat, latent heat is recovered from flue gas water vapor, improving system efficiency markedly. In addition to improving thermal efficiency, condensing economizers can also capture particulates. In tests to date up to 89% removal has been measured. The primary objectives of this project are to evaluate the most important mechanisms involved in particle capture and to enhance capture in practical systems. The intent of the work is to contribute to the ongoing program at the Department of Energy/Pittsburgh Energy Technology Center in the development of coal-fired combustion equipment. These results are expected to be most applicable to smaller scale equipment, where the low temperature heat from the economizer can be used. The approach involves determining thermal efficiency improvement and particulate removal efficiency (experimental), and developing models capable of predicting system performance under varied operating conditions (theoretical). Gas temperature and condensation profiles through the economizers have been predicted and overall predicted performance are consistent with test results. Mechanisms for particle removal are discussed in this paper and predicted removal efficiencies as a function of particle diameter are presented. 4 refs.

  13. Testing of a coal-fired diesel power plant

    SciTech Connect

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

    1993-01-01

    The POC coal-fired power plant consists of a Cooper-Bessemer LSC-6 engine (15.5 inch bore, 22 inch stroke) rated at 400 rev/min and 208 psi bmep producing approximately 1.8 MW of power. The power plant is fueled with `engine grade` coal slurry which has been physically cleaned to an ash level of approximately 1.5 to 2% (dry basis) and has a mean particle size of approximately 12 micron. CWS is injected directly into the combustion chamber through a fuel injector (one per cylinder) which was designed and developed to be compatible with the fuel. Each injector is fitted with a 19 orifice nozzle tip made with sapphire inserts in each orifice. The combustion chambers are fitted with twin diesel pilot injectors which provide a positive ignition source and substantially shorten the ignition delay period of the CWS fuel. Durable coatings (typically tungsten carbide) are used for the piston rings and cylinder liners to reduce wear rates. The emission control system consists of SCR for NO{sub x} control, sodium sorbent injection for SO{sub x} control, and a cyclone plus baghouse for particulate capture. The cyclone is installed upstream of the engine turbocharger which helps protect the turbine blades.

  14. Testing of a coal-fired diesel power plant

    SciTech Connect

    Wilson, R.P.; Balles, E.N.; Benedek, K.R.; Benson, C.E. , Inc., Cambridge, MA ); Rao, K.; Schaub, F. ); Kimberley, J. ); Itse, D. )

    1993-01-01

    The POC coal-fired power plant consists of a Cooper-Bessemer LSC-6 engine (15.5 inch bore, 22 inch stroke) rated at 400 rev/min and 208 psi bmep producing approximately 1.8 MW of power. The power plant is fueled with 'engine grade' coal slurry which has been physically cleaned to an ash level of approximately 1.5 to 2% (dry basis) and has a mean particle size of approximately 12 micron. CWS is injected directly into the combustion chamber through a fuel injector (one per cylinder) which was designed and developed to be compatible with the fuel. Each injector is fitted with a 19 orifice nozzle tip made with sapphire inserts in each orifice. The combustion chambers are fitted with twin diesel pilot injectors which provide a positive ignition source and substantially shorten the ignition delay period of the CWS fuel. Durable coatings (typically tungsten carbide) are used for the piston rings and cylinder liners to reduce wear rates. The emission control system consists of SCR for NO[sub x] control, sodium sorbent injection for SO[sub x] control, and a cyclone plus baghouse for particulate capture. The cyclone is installed upstream of the engine turbocharger which helps protect the turbine blades.

  15. CHALLENGES AND OPPORTUNITIES FOR EMISSION REDUCTIONS FROM THE COAL-FIRED POWER SECTOR IN GROWING ECONOMIES: THE CASE OF COAL-FIRED ELECTRIC UTILITY PLANTS IN RUSSIA

    EPA Science Inventory

    China, Russia and India together contribute over one-fourth of the total global greenhouse gas emissions from the combustion of fossil-fuels. This paper focuses on the Russian coal-fired power sector, and identifies potential opportunities for reducing emissions. The Russian powe...

  16. A coal-fired combustion system for industrial process heating applications. Quarterly technical progress report, April 1992--June 1992

    SciTech Connect

    Not Available

    1992-09-03

    PETC has implemented a number of advanced combustion research projects that will lead to the establishment of a broad, commercially acceptable engineering data base for the advancement of coal as the fuel of choice for boilers, furnaces, and process heaters. Vortec Corporation`s Phase III development contract DE-AC22-91PC91161 for a ``Coal-Fired Combustion System for Industrial Process Heating Applications`` is project funded under the DOE/PETC advanced combustion program. This advanced combustion system research program is for the development of innovative coal-fired process heaters which can be used for high temperature melting, smelling and waste vitrification processes. The process heater concepts to be developed are based on advanced glass melting and ore smelting furnaces developed and patented by Vortec Corporation. The process heater systems to be developed have multiple use applications; however, the Phase III research effort is being focused on the development of a process heater system to be used for producing value added vitrified glass products from boiler/incinerator ashes and industrial wastes. The primary objective of the Phase III project is 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 marketability. During the current reporting period, approval of Vortec`s Environmental Assessment (EA) required under the National Environmental Policy Act (NEPA) was approved. The EA approval cycle took approximately 9 months. The preliminary test program which was being held in abeyance pending approval of the EA was initiated. Six preliminary test runs were successfully competed during the period. Engineering and design activities in support of the Phase III proof of concept are continuing, and modifications to the existing test system configuration to allow performance of the preliminary tests were completed.

  17. Center for Hypersonic Combined Cycle Flow Physics

    DTIC Science & Technology

    2015-03-24

    AFRL-AFOSR-VA-TR-2015-0292 CENTER FOR HYPERSONIC COMBINED CYCLE FLOW PHYSICS James Mcdaniel UNIVERSITY OF VIRGINIA Final Report 03/24/2015...HYPERSONIC COMBINED CYCLE FLOW PHYSICS 5a. CONTRACT NUMBER 5b. GRANT NUMBER FA9550-09-1-0611 5c. PROGRAM ELEMENT NUMBER 6. AUTHOR(S) McDaniel, James C...DISTRIBUTION/AVAILABILITY STATEMENT Approved for Public Release 13. SUPPLEMENTARY NOTES 14. ABSTRACT Combined cycle flow physics were investigated using a

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

    SciTech Connect

    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.

  19. Speciation and mass distribution of mercury in a bituminous coal-fired power plant

    NASA Astrophysics Data System (ADS)

    Lee, Sung Jun; Seo, Yong-Chil; Jang, Ha-Na; Park, Kyu-Shik; Baek, Jeom-In; An, Hi-Soo; Song, Kwang-Chul

    Characterization and mass balance of mercury in a coal-fired power plant were carried out in a 500 MW, bituminous coal consuming electric utility boiler. This facility is equipped with a cold-side electrostatic precipitator (ESP) and a wet flue gas desulfurization (FGD) in series as air pollution control devices (APCDs). Mercury sampling points were selected at both the up and down streams of the ESP and outlet of the FGD, which is at stack. Two different types of sampling methods were employed, one is the Ontario Hydro (OH) method (ASTM D6784) and the other is US EPA101A. Various samples were collected from the coal-fired power plant such as fuel coals, fly ash in hopper, lime/lime stone, gypsum, and effluent water from FGD. These samples were analyzed by US EPA 7470A and 7471A to understand the behavior and mass balance of mercury in the process of a coal-fired power plant. There are no significant differences between the two sampling methods, but the OH method seems to have more advantages for Hg sampling from a coal-fired power plant because mercury speciation is quite an important factor to estimate the mercury emission and control efficiency from combustion flue gas. Approximate Hg mass balance could be obtained from various samples in the study; however, a series of long-term and comprehensive study is required to evaluate the reliable Hg mass distribution and behavior in a coal-fired power plant.

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

    SciTech Connect

    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

  1. Nighttime NOx Chemistry in Coal-Fired Power Plant Plumes

    NASA Astrophysics Data System (ADS)

    Fibiger, D. L.; McDuffie, E. E.; Dube, W. P.; Veres, P. R.; Lopez-Hilfiker, F.; Lee, B. H.; Green, J. R.; Fiddler, M. N.; Ebben, C. J.; Sparks, T.; Weinheimer, A. J.; Montzka, D.; Campos, T. L.; Cohen, R. C.; Bililign, S.; Holloway, J. S.; Thornton, J. A.; Brown, S. S.

    2015-12-01

    Nitrogen oxides (NOx = NO + NO2) play a key role in atmospheric chemistry. During the day, they catalyze ozone (O3) production, while at night they can react to form nitric acid (HNO3) and nitryl chloride (ClNO2) and remove O3 from the atmosphere. These processes are well studied in the summer, but winter measurements are more limited. Coal-fired power plants are a major source of NOx to the atmosphere, making up approximately 30% of emissions in the US (epa.gov). NOx emissions can vary seasonally, as well as plant-to-plant, with important impacts on the details of the plume chemistry. In particular, due to inefficient plume dispersion, nighttime NOx emissions from power plants are held in concentrated plumes, where rates of mixing with ambient O3 have a strong influence on plume evolution. We will show results from the aircraft-based WINTER campaign over the northeastern United States, where several nighttime intercepts of power plant plumes were made. Several of these intercepts show complete O3 titration, which can have a large influence on NOx lifetime, and thus O3 production, in the plume. When power plant NO emissions exceed background O3 levels, O3 is completely consumed converting NO to NO2. In the presence of O3, NO2 will be oxidized to NO3, which will then react with NO2 to form N2O5, which can then form HNO3 and/or ClNO2 and, ultimately, remove NOx from the atmosphere or provide next-day oxidant sources. If there is no O3 present, however, no further chemistry can occur and NO and NO2 will be transported until mixing with sufficient O3 for higher oxidation products. Modeling results of plume development and mixing, which can tell us more about this transport, will also be presented.

  2. Application of high temperature air heaters to advanced power generation cycles

    SciTech Connect

    Thompson, T R; Boss, W H; Chapman, J N

    1992-03-01

    Recent developments in ceramic composite materials open up the possibility of recuperative air heaters heating air to temperatures well above the feasible with metal tubes. A high temperature air heater (HTAH) has long been recognized as a requirement for the most efficient MHD plants in order to reach high combustor flame temperatures. The application of gas turbines in coal-fired plants of all types has been impeded because of the problems in cleaning exhaust gas sufficiently to avoid damage to the turbine. With a possibility of a HTAH, such plants may become feasible on the basis of air turbine cycles, in which air is compressed and heated in the HTAH before being applied to turbine. The heat exchanger eliminates the need for the hot gas cleanup system. The performance improvement potential of advanced cycles with HTAH application including the air turbine cycle in several variations such as the DOE program on ``Coal-Fired Air Furnace Combined Cycle...,`` variations originated by the authors, and the MHD combined cycle are presented. The status of development of ceramic air heater technology is included.

  3. Co-firing of asphalt fired dust in pulverized coal fired boiler

    SciTech Connect

    Kiga, Takashi; Watanabe, Shinjl

    1999-07-01

    In order to make clear whether the dust collected at the electrostatic precipitator (EP) of asphalt fired boilers can be co-fired in pulverized coal fired boilers, laboratory-scale and bench-scale tests have been conducted. Test results showed that although dust from asphalt firing had as only a little amount of volatile matter as semi-anthracite or anthracite had, it revealed burn-out properties like bituminous. When it was co-fired with pulverized coal by 2% by that input, a considerable increase in SO{sub 2} emission was noted, while NOx emission was somewhat decreased compared with coal firing. From these verifications, it was confirmed that the co-firing of dust from asphalt firing in pulverized coal fired boiler was applicable to actual plants so far as the De-SOx system permitted.

  4. Coal-fired propulsion system dynamics. Volume 1. Executive summary. Final report

    SciTech Connect

    Greenlee, T.L.; Pearsons, J.L.

    1982-12-01

    This volume summarizes the objectives, scope, and conclusions of an effort that was undertaken to develop and analyze a dynamic model/simulation of a coal-fired ship with steam turbine propulsion system. The General Dynamics CV-3600 self-unloading coal collier was used as the basis for this effort. The effort was jointly sponsored by General Dynamics and the U.S. Department of Transportation, Maritime Administration, for the purpose of investigating the responsiveness of coal-fired ships in maneuvering and in restricted-water operation. The volume concludes with a set of specification results that indicate the component/control system design trends that should be followed to obtain a rapidly responding coal-fired propulsion system.

  5. Preliminary evaluation of coal-fired fluid bed combustion-augmented compressed air energy storage power plants

    NASA Astrophysics Data System (ADS)

    Lessard, R. D.; Giramonti, A. J.; Merrick, D.

    1980-03-01

    This paper presents highlights of an ongoing study program to assess the technical and economic feasibility of advanced concepts for generating peak-load electric power from a compressed air energy storage (CAES) power plant incorporating a coal-fired fluid bed combustor (FBC). It reviews the analyses performed to select an FBC/CAES power plant system configuration for the subsequent conceptual design phase of the study. Included in this review are: the design and operating considerations involved with integrating either an atmospheric or a pressurized fluid bed combustor with a CAES system to yield practical system configurations; the integration of system configurations; the parametric performance of these system configurations; and the preliminary screening which considered performance, cost, and technical risk and led to the identification of an open-bed PFBC/CAES system as having the greatest near-term commercialization potential.

  6. Electrical resistivity of coal-bearing rocks under high temperature and the detection of coal fires using electrical resistance tomography

    NASA Astrophysics Data System (ADS)

    Shao, Zhenlu; Wang, Deming; Wang, Yanming; Zhong, Xiaoxing; Tang, Xiaofei; Xi, Dongdong

    2016-02-01

    Coal fires are severe hazards to environment, health and safety throughout the world. Efficient and economical extinguishing of these fires requires that the extent of the subsurface coal fires should be delineated. Electrical and electromagnetic methods have been used to detect coal fires in recent years. However, the resistivity change of coal-bearing rocks at high temperature is rarely investigated. The resistivity characteristics of coal fires at different temperatures and depths are seldomly researched as well. In this paper, we present the results of measurements of several coal-bearing rocks' resistivity and permeability under high temperature. Two major causes for the change in resistivity with increasing temperature are recognized, there are the increase of charge carriers and thermal fracturing, of which the first one is probably the dominant cause. A set of 2-D simulations is carried out to compare the relation of resolution and efficiency of coal fires detection to temperature and depth when adopting the electrical resistance tomography. The simulation results show that the resolution and efficiency decrease with the decrease of temperature and the increase of depth. Finally, the electrical resistance tomography is used to delineate coal fires in the Anjialing Open Pit Mine. Most low-resistivity regions are verified as coal-fire areas according to the long-term monitoring of borehole temperature. The results indicate that the electrical resistance tomography can be used as a tool for the detection of coal fires.

  7. An evaluation of physical coal cleaning plus FGD for coal fired utility applications

    SciTech Connect

    Newman, J.; Kantesaria, P.; Huettenhain, H.

    1994-12-31

    The Clean Air Act Amendment of 1990 (CAAA) requires utilities to reduce SO{sub 2} emissions from coal-fired power plants in two phases. Phase I takes effect January 1, 1995, requiring utilities to reduce SO{sub 2} emissions to 2.5 lb SO{sub 2}/MMBtu. Phase II becomes effective on January 1, 2000, requiring all plants above 25 MWe in capacity not to exceed SO{sub 2} emissions above 1.2 lb SO{sub 2}/MMBtu. Electric utilities who burn moderately high ash and sulfur bituminous coal and must develop a strategy to comply with the CAAA can choose from numerous options besides simple fuel switching or complete flue gas scrubbing. Below 2% Run of Mine (ROM) coal sulfur Strategy 2, conventional cleaning, provides the lowest cost. Below 4% sulfur in the ROM coal conventional cleaning plus confined zone dispersion (CZD), Strategy 7, is the best choice. The higher cost of advanced coal cleaning, promising an additional 12% SO{sub 2} reduction over the approximately 45% reduction by conventional cleaning, can only be justified for coals between 4 and 6% sulfur in the ROM coal. Strategy 8, advanced cleaning plus CZD has the lowest cost for this sulfur range. Higher sulfur coals require full scrubbing combined with conventional coal cleaning to achieve the lowest compliance cost for Phase I. For Phase II compliance advanced coal cleaning has no advantage over conventional cleaning. Full scrubbing will be required for ROM coals with more than 2% sulfur. Full scrubbing combined with conventional cleaning can achieve the lowest compliance cost compared to the other strategies.

  8. Emissions of mercury and other trace elements from coal-fired power plants in Japan.

    PubMed

    Ito, Shigeo; Yokoyama, Takahisa; Asakura, Kazuo

    2006-09-01

    To evaluate trace element emissions from modern coal-fired power plants into the atmospheric environment in Japan, trace elements in the coal used in electric utility boilers, stack concentrations, emission rates and emission ratios of coal-fired power plants, and proportions of trace elements in coal-fired power plants were studied. The elements were As, B, Be, Cd, Co, Cr, F, Hg, Mn, Ni, Pb, Sb, Se and V, which are designated in the Law of Pollutant Release and Transfer Register. The particulate trace elements were collected in an electrostatic precipitator and a wet desulfurization scrubber. Emissions into the atmosphere were lower than 1% of the quantity in coal, but the volatile trace elements showed somewhat higher emission ratios. For mercury, the mean concentration in coal was 0.045 ppm, the mean emission rate was 4.4 microg/kW h, and the mean emission ratio was 27%, the highest ratio among all elements in this study. The total annual emission of mercury from coal-fired power plants of the electric power industry in Japan was estimated to be 0.63 t/y. On the basis of these data, the atmospheric environment loads from a coal-fired power station were investigated. The calculation of stack gas dispersion showed that maximum annual mean ground level concentrations were in the order of 10(-2) to 10(-5) of the background concentrations, and that the adverse effect of the emissions from the coal-fired power station was small.

  9. Adapting sustainable low-carbon techologies to reduce carbon dioxide emissions from coal-fired power plants in China

    NASA Astrophysics Data System (ADS)

    Kuo, Peter Shyr-Jye

    1997-09-01

    The scientific community is deeply concerned about the effect of greenhouse-gases (GHGs) on global climate change. A major climate shift can result in tragic destruction to our world. Carbon dioxide (COsb2) emissions from coal-fired power plants are major anthropogenic sources that contribute to potential global warming. The People's Republic of China, with its rapidly growing economy and heavy dependence on coal-fired power plants for electricity, faces increasingly serious environmental challenges. This research project seeks to develop viable methodologies for reducing the potential global warming effects and serious air pollution arising from excessive coal burning. China serves as a case study for this research project. Major resolution strategies are developed through intensive literature reviews to identify sustainable technologies that can minimize adverse environmental impacts while meeting China's economic needs. The research thereby contributes technological knowledge to the field of Applied Sciences. The research also integrates modern power generation technologies with China's current and future energy requirements. With these objectives in mind, this project examines how China's environmental issues are related to China's power generation methods. This study then makes strategic recommendations that emphasize low-carbon technologies as sustainable energy generating options to be implemented in China. These low-carbon technologies consist of three options: (1) using cleaner fuels converted from China's plentiful domestic coal resources; (2) applying high-efficiency gas turbine systems for power generation; and (3) integrating coal gasification processes with energy saving combined cycle gas turbine systems. Each method can perform independently, but a combined strategy can achieve the greatest COsb2 reductions. To minimize economic impacts caused by technological changes, this study also addresses additional alternatives that can be implemented in

  10. Prediction of the furnace heat absorption by utilizing thermomechanical analysis for various kinds of coal firing

    SciTech Connect

    Ishinomori, T.; Watanabe, S.; Kiga, T.; Wall, T.F.; Gupta, R.P.; Gupta, S.K.

    1999-07-01

    In order to predict the furnace heat absorption, which is sensitive to coal properties, an attempt to make a model universally applicable for any kind of pulverized coal fired boiler is in progress. First of all, the heat absorption rates on to furnace wall were surveyed for 600MWe pulverized coal fired boiler, and they were ranked into four levels by indicating a furnace heat absorption index (FHAI). Some ash composition is relatively well related to the FHAI, while a new index from thermomechanical analysis (TMA) offers a good prediction of the furnace heat absorption.

  11. Carbon dioxide control costs for gasification combined-cycle plants in the United States

    SciTech Connect

    Brown, D.R.; Humphreys, K.K.; Vail, L.W.

    1993-06-01

    This study focused on evaluating the cost of recovering CO{sub 2} from coal gasification, combined-cycle (GCC) power plants and transporting the CO{sub 2} in pipelines for disposal in deep ocean water, depleted oil and gas reservoirs, or aquifers. Other fuels and conversion technologies were not evaluated. Technical feasibility, environmental acceptability, and other implementation issues were not addressed in detail. Ocean disposal of CO{sub 2} offers essentially unlimited capacity, but is distant from most US coal-fired power plants and presents environmental concerns at the disposal point. Depleted oil and gas reservoirs are also distant from most US coal-fired power plants and have a more limited disposal capacity,, but were calculated to have a potential capacity more than double that required to dispose of all CO{sub 2} from 830 GCC power plants (380-mwe each) for a period of 40 years. The existence of oil and gas reservoirs provides ``proof`` of the long-term CO{sub 2} confinement potential in these formations. In contrast, aquifer disposal is believed to be significantly riskier. Key concerns are lack of geologic knowledge at depths adequate for CO{sub 2} disposal; uncertainty about geochemical impacts from decreased water pH; and long-term confinement, which is unproven for non-petroleum formations. Carbon dioxide recovery at GCC plants increased the levelized energy cost (LEC) by about one third relative to a reference GCC plant without CO{sub 2} recovery. The transmission distance is the key factor affecting total CO{sub 2} control costs.

  12. The Strutjet Rocket Based Combined Cycle Engine

    NASA Technical Reports Server (NTRS)

    Siebenhaar, A.; Bulman, M. J.; Bonnar, D. K.

    1998-01-01

    The multi stage chemical rocket has been established over many years as the propulsion System for space transportation vehicles, while, at the same time, there is increasing concern about its continued affordability and rather involved reusability. Two broad approaches to addressing this overall launch cost problem consist in one, the further development of the rocket motor, and two, the use of airbreathing propulsion to the maximum extent possible as a complement to the limited use of a conventional rocket. In both cases, a single-stage-to-orbit (SSTO) vehicle is considered a desirable goal. However, neither the "all-rocket" nor the "all-airbreathing" approach seems realizable and workable in practice without appreciable advances in materials and manufacturing. An affordable system must be reusable with minimal refurbishing on-ground, and large mean time between overhauls, and thus with high margins in design. It has been suggested that one may use different engine cycles, some rocket and others airbreathing, in a combination over a flight trajectory, but this approach does not lead to a converged solution with thrust-to-mass, specific impulse, and other performance and operational characteristics that can be obtained in the different engines. The reason is this type of engine is simply a combination of different engines with no commonality of gas flowpath or components, and therefore tends to have the deficiencies of each of the combined engines. A further development in this approach is a truly combined cycle that incorporates a series of cycles for different modes of propulsion along a flight path with multiple use of a set of components and an essentially single gas flowpath through the engine. This integrated approach is based on realizing the benefits of both a rocket engine and airbreathing engine in various combinations by a systematic functional integration of components in an engine class usually referred to as a rocket-based combined cycle (RBCC) engine

  13. CONTROL OF NOX EMISSIONS FROM U.S. COAL-FIRED ELECTRIC UTILITY BOILERS

    EPA Science Inventory

    The paper discusses the control of nitrogen oxide (NOx) emissions from U.S. coal-fired electric utility boilers. (NOTE: In general, NOx control technologies are categorized as being either primary or secondary control technologies. Primary technologies reduce the amount of NOx pr...

  14. APPLICATION OF REBURNING TO COAL-FIRED INDUSTRIAL BOILERS IN TAIWAN

    EPA Science Inventory

    The paper gives an overview of the characteristics of coal-fired industrial boilers in Taiwan and projections of the cost and performance data for retrofitting several boilers with reburning. The impacts of reburning fuel type on the reburning system design and cost effectivenes...

  15. FUNDAMENTAL SCIENCE AND ENGINEERING OF MERCURY CONTROL IN COAL-FIRED POWER PLANTS

    EPA Science Inventory

    The paper discusses the existing knowledge base applicable to mercury (Hg) control in coal-fired boilers and outlines the gaps in knowledge that can be filled by experimentation and data gathering. Mercury can be controlled by existing air pollution control devices or by retrofit...

  16. Control of mercury emissions from coal fired electric uitlity boilers: An update

    EPA Science Inventory

    Coal-fired power plants in the U.S. are known to be the major anthropogenic source of domestic mercury emissions. The Environmental Protection Agency (EPA) has recently proposed to reduce emissions of mercury from these plants. In March 2005, EPA plans to promulgate final regulat...

  17. MENU OF NOX EMISSION CONTROL OPTIONS FOR COAL-FIRED ELECTRIC UTILITY BOILERS

    EPA Science Inventory

    The paper reviews NOx control options for coal-fired electric utility boilers. (NOTE: Acid Rain NOx regulations, the Ozone Transport Commission's NOx Budget Program, revision of the New Source Performance Standards (NSPS) for NOx emissions from utility sources, and Ozone Transpor...

  18. Development and testing of industrial scale, coal fired combustion system, Phase 3

    SciTech Connect

    Zauderer, B.

    1993-02-15

    A major part of the work in this quarter was on the combustor tests in task 2. Three of the six planned tests in this task were completed. The first two were parametric tests of nominal one shift, (8 hour) duration on coal. Due to failure of the UV detector in the first test only several hours of coal fired operation were completed. In the second test, coal fired operation continued for the planned one shift until the 4 ton coal bin was empty. After reviewing this work with DOE, it was decided to focus the remaining test on longer duration operation with each test at one optimum condition. The third test was planned for two shift coal fired operation. Due to a problem with the pilot gas ignitor, combustion was delayed by 5 hours from 7 AM to Noon. As a result coal fired operation was limited to one shift between 3 PM and 11 PM. Throughout this period the combustor remained at one fixed condition with the use of computer control. Results for these three tests are presented in this report. Most of the work on the task 4 design and cost of a 20 MW combined gas-steam turbine power plant using the air cooled combustor was completed in the previous quarter. The results obtained by the A/E subcontractor on the installation desip and cost were evaluated in the present quarter and they are summarized in this report.

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

    PubMed

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

    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/10(6) Btu.

  20. PROTOTYPE SCALE TESTING OF LIMB TECHNOLOGY FOR A PULVERIZED-COAL-FIRED BOILER

    EPA Science Inventory

    The report summarizes results of an evaluation of furnace sorbent injection (FSI) to control sulfur dioxide (SO2) emissions from coal-fired utility boilers. (NOTE: FSI of calcium-based sorbents has shown promise as a moderate SO2 removal technology.) The Electric Power Research I...

  1. EPA Research Highlights: Minimizing SO3 Emissions from Coal-Fired Power Plants

    EPA Science Inventory

    There have been substantial reductions in emissions of particulate matter, nitrogen oxides, and sulfur dioxide through the application of control technologies and strategies. The installation of control technologies has added to the complexity of coal-fired boilers and their ope...

  2. NOVEL ECONOMICAL HG(0) OXIDATION REAGENT FOR MERCURY EMISSIONS CONTROL FROM COAL-FIRED BOILERS

    EPA Science Inventory

    The authors have developed a novel economical additive for elemental mercury (Hg0) removal from coal-fired boilers. The oxidation reagent was rigorously tested in a lab-scale fixed-bed column with the Norit America's FGD activated carbon (DOE's benchmark sorbent) in a typical PRB...

  3. NOVEL MERCURY OXIDANT AND SORBENT FOR MERCURY EMISSIONS CONTROL FROM COAL-FIRED POWER PLANTS

    EPA Science Inventory

    The authors have successfully developed novel efficient and cost-effective sorbent and oxidant for removing mercury from power plant flue gases. These sorbent and oxidant offer great promise for controlling mercury emissions from coal-fired power plants burning a wide range of c...

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

    SciTech Connect

    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).

  5. CHARACTERIZATION AND MANAGEMENT OF RESIDUES FROM COAL-FIRED POWER PLANTS

    EPA Science Inventory

    The U.S. Environmental Protection Agency (EPA) determined on December 15, 2000, that regulations are needed to control the risks of mercury air emissions from coal-fired power plants. The thrust of these new regulations is to remove mercury from the air stream of fossil-fuel-fire...

  6. Evaluating the fate of metals in air pollution control residues from coal-fired power plants

    EPA Science Inventory

    Changes in air pollution control at coal-fired power plants are shifting mercury (Hg) and other metals from the flue gas at electric utilities to the coal ash. This paper presents data from the characterization of73 coal combustion residues (CCRs) evaluating the composition and c...

  7. Does proximity to coal-fired power plants influence fish tissue mercury?

    PubMed

    Sackett, Dana K; Aday, D Derek; Rice, James A; Cope, W Gregory; Buchwalter, David

    2010-11-01

    Much of the mercury contamination in aquatic biota originates from coal-fired power plants, point sources that release mercury into the atmosphere. Understanding mercury dynamics is primarily important because of the toxic threat mercury poses to wildlife and humans through the consumption of contaminated fish. In this study, we quantified the relative importance of proximity to coal-fired power plants on mercury accumulation in two fish species of different trophic positions. Fish, water and sediment were collected and analyzed from 14 lakes, seven near to (<10 km) and seven far from (>30 km) coal-fired power plants. Lower tissue mercury and higher tissue selenium concentrations were measured in fish collected near power plants. Moreover, mercury accumulation in fish was driven by biotic characteristics (e.g., trophic position, total length, age), waterbody characteristics (e.g., pH, dissolved organic carbon and sulfate) and distance from power plants. Proximity to an atmospheric point-source of mercury and selenium, such as a coal-fired power plant, affects the quantities of mercury and selenium accumulated in fish tissue. Differences in accumulation are hypothesized to be driven in part by selenium-mitigated reductions in fish tissue mercury near power plants. Although reduced fish tissue mercury in systems near power plants may decrease mercury-specific risks to human consumers, these benefits are highly localized and the relatively high selenium associated with these tissues may compromise ecological health.

  8. Innovative Clean Coal Technology (ICCT): 500-MW demonstration of advanced wall-fired cmbustion techniques for the reduction of nitrogen oxide (NO{sub x}) emissions from coal-fired boilers. Field chemical emissions monitoring, Overfire air and overfire air/low NO{sub x} burner operation: Final report

    SciTech Connect

    1993-12-31

    This report summarizes data gathered by Radian Corporation at a coal-fired power plant, designated Site 16, for a program sponsored by the United States Department of Energy (DOE), Southern Company Services (SCS), and the Electric Power Research Institute (EPRI). Concentrations of selected inorganic and organic substances were measured in the process and discharge streams of the plant operating under two different types of combustion modifications: overfire air (OFA) and a combination of overfire air with low-NO{sub x} burners (OFA/LNB). Information contained in this report will allow DOE and EPRI to determine the effects of low-NO{sub x} modifications on plant emissions and discharges. Sampling was performed on an opposed wall-fired boiler burning medium-sulfur bituminous coal. Emissions were controlled by electrostatic precipitators (ESPs). The testing was conducted in two distinct sampling periods, with the OFA test performed in March of 1991 and the OFA/LNB test performed in May of 1993. Specific objectives were: to quantify emissions of target substances from the stack; to determine the efficiency of the ESPs for removing the target substances; and to determine the fate of target substances in the various plant discharge streams.

  9. A Study on Spreading Direction of Coal-fire Based with TIR Remote Sensing in Wuda Coalfield from 2000 to 2006, Northern China

    NASA Astrophysics Data System (ADS)

    Huo, H.-Y.; Jiang, X.-G.; Song, X.-F.; Ni, Z.-Y.; Gao, C.-X.; Zhang, Y.-Z.; Liu, L.

    2014-03-01

    Coal fires are a common and serious problem in most coal producing countries. Coal fires could not only lead to a huge loss of non-renewable energy resources, but it also can cause many environmental problems such as GHG emission, land subsidence and increment of surface temperature. So it is very important to monitor the dynamic changes of coal fires. As far as large scale coal field, remote sensing provided researchers with a new and useful technique for coal fire detection. This paper developed a research over coal fire spreading direction using a multi-temporal TIR remote sensing approach. The results successfully showed that the direction of coal fire spreading and predicted the coal fire direction of development on a regional scale or on a whole coal field scale, and a quantitative analysis of coal fires was made in the research. The results showed that the coal fires had an average annual increase of 0.5 million square meters from 1999 to 2006, and the TIR remote sensing proved to be an available tool for coal fire mapping and prediction of coal fire development.

  10. [Emission Characteristics of Water-Soluble Ions in Fumes of Coal Fired Boilers in Beijing].

    PubMed

    Hu, Yue-qi; Ma, Zhao-hui; Feng, Ya-jun; Wang, Chen; Chen, Yuan-yuan; He, Ming

    2015-06-01

    Selecting coal fired boilers with typical flue gas desulfurization and dust extraction systems in Beijing as the study objects, the issues and characteristics of the water-soluble ions in fumes of coal fired boilers and theirs influence factors were analyzed and evaluated. The maximum mass concentration of total water-soluble ions in fumes of coal fired boilers in Beijing was 51.240 mg x m(-3) in the benchmark fume oxygen content, the minimum was 7.186 mg x m(-3), and the issues of the water-soluble ions were uncorrelated with the fume moisture content. SO4(2-) was the primary characteristic water-soluble ion for desulfurization reaction, and the rate of contribution of SO4(2-) in total water-soluble ions ranged from 63.8% to 81.0%. F- was another characteristic water-soluble ion in fumes of thermal power plant, and the rate of contribution of F- in total water-soluble ions ranged from 22.2% to 32.5%. The fume purification technologies significantly influenced the issues and the emission characteristics of water-soluble ions in fumes of coal fired boilers. Na+ was a characteristic water-soluble ion for the desulfurizer NaOH, NH4+ and NO3+ were characteristic for the desulfurizer NH4HCO3, and Mg2+ was characteristic for the desulfurizer MgO, but the Ca2+ emission was not increased by addition of the desulfurizer CaO or CaCO3 The concentrations of NH4+ and NO3- in fumes of thermal power plant were lower than those in fumes of industrial or heating coal fired boilers. The form of water-soluble ions was significantly correlated with fume temperature. The most water-soluble ions were in superfine state at higher fume temperature and were not easily captured by the filter membrane.

  11. Mercury emission trend influenced by stringent air pollutants regulation for coal-fired power plants in Korea

    NASA Astrophysics Data System (ADS)

    Pudasainee, Deepak; Kim, Jeong-Hun; Seo, Yong-Chil

    2009-12-01

    Regulatory control of mercury emission from anthropogenic sources has become a global concern in the recent past. Coal-fired power plants are one of the largest sources of anthropogenic mercury emission into the atmosphere. This paper summarizes the current reducing trend of mercury emission as co-beneficial effect by more stringent regulation changes to control primary air pollutants with introducing test results from the commercial coal-fired facilities and suggesting a guideline for future regulatory development in Korea. On average, mercury emission concentrations ranged 16.3-2.7 μg Sm -3, 2.4-1.1 μg Sm -3, 3.1-0.7 μg Sm -3 from anthracite coal-fired power plants equipped with electrostatic precipitator (ESP), bituminous coal-fired power plants with ESP + flue gas desulphurization (FGD) and bituminous coal-fired power plants with selective catalytic reactor (SCR) + cold side (CS) - ESP + wet FGD, respectively. Among the existing air pollution control devices, the best configuration for mercury removal in coal-fired power plants was SCR + CS - ESP + wet FGD, which were installed due to the stringent regulation changes to control primary air pollutants emission such as SO 2, NOx and dust. It was estimated that uncontrolled and controlled mercury emission from coal-fired power plants as 10.3 ton yr -1 and 3.2 ton yr -1 respectively. After the installation of ESP, FGD and SCR system, following the enforcement of the stringent regulation, 7.1 ton yr -1 of mercury emission has been reduced (nearly 69%) from coal-fired power plants as a co-benefit control. Based on the overall study, a sample guideline including emission limits were suggested which will be applied to develop a countermeasure for controlling mercury emission from coal-fired power plants.

  12. A combined cycle engine test facility

    NASA Astrophysics Data System (ADS)

    Engers, R.; Cresci, D.; Tsai, C.

    Rocket-Based Combined-Cycle (RBCC) engines intended for missiles and/or space launch applications incorporate features of rocket propulsion systems operating in concert with airbreathing engine cycles. Performance evaluation of these types of engines, which are intended to operate from static sea level take-off to supersonic cruise or accerlerate to orbit, requires ground test capabilities which integrate rocket component testing with airbreathing engine testing. A combined cycle engine test facility has been constructed in the General Applied Science Laboratories, Inc. (GASL) Aeropropulsion Test Laboratory to meet this requirement. The facility was designed to support the development of an innovative combined cycle engine concept which features a rocket based ramjet combustor. The test requirements included the ability to conduct tests in which the propulsive force was generated by rocket only, the ramjet only and simultaneous rocket and ramjet power (combined cycle) to evaluate combustor operation over the entire engine cycle. The test facility provides simulation over the flight Mach number range of 0 to 8 and at various trajectories. The capabilities of the combined cycle engine test facility are presented.

  13. A combined cycle engine test facility

    SciTech Connect

    Engers, R.; Cresci, D.; Tsai, C.

    1995-09-01

    Rocket-Based Combined-Cycle (RBCC) engines intended for missiles and/or space launch applications incorporate features of rocket propulsion systems operating in concert with airbreathing engine cycles. Performance evaluation of these types of engines, which are intended to operate from static sea level take-off to supersonic cruise or accerlerate to orbit, requires ground test capabilities which integrate rocket component testing with airbreathing engine testing. A combined cycle engine test facility has been constructed in the General Applied Science Laboratories, Inc. (GASL) Aeropropulsion Test Laboratory to meet this requirement. The facility was designed to support the development of an innovative combined cycle engine concept which features a rocket based ramjet combustor. The test requirements included the ability to conduct tests in which the propulsive force was generated by rocket only, the ramjet only and simultaneous rocket and ramjet power (combined cycle) to evaluate combustor operation over the entire engine cycle. The test facility provides simulation over the flight Mach number range of 0 to 8 and at various trajectories. The capabilities of the combined cycle engine test facility are presented.

  14. CHARACTERIZATION AND MODELING OF THE FORMS OF MERCURY FROM COAL-FIRED POWER PLANTS

    SciTech Connect

    Dennis L. Laudal

    2001-08-01

    The 1990 Clean Air Act Amendments (CAAAs) required the U.S. Environmental Protection Agency (EPA) to determine whether the presence of mercury in the stack emissions from fossil fuel-fired electric utility power plants poses an unacceptable public health risk. EPA's conclusions and recommendations were presented in the Mercury Study Report to Congress (1) and the Utility Air Toxics Report to Congress (1). The first report addressed both the human health and environmental effects of anthropogenic mercury emissions, while the second addressed the risk to public health posed by the emission of mercury and other hazardous air pollutants from steam-electric generating units. Given the current state of the art, these reports did not state that mercury controls on coal-fired electric power stations would be required. However, they did indicate that EPA views mercury as a potential threat to human health. In fact, in December 2000, the EPA issued an intent to regulate for mercury from coal-fired boilers. However, it is clear that additional research needs to be done in order to develop economical and effective mercury control strategies. To accomplish this objective, it is necessary to understand mercury behavior in coal-fired power plants. The markedly different chemical and physical properties of the different mercury forms generated during coal combustion appear to impact the effectiveness of various mercury control strategies. The original Characterization and Modeling of the Forms of Mercury from Coal-Fired Power Plants project had two tasks. The first was to collect enough data such that mercury speciation could be predicted based on relatively simple inputs such as coal analyses and plant configuration. The second was to field-validate the Ontario Hydro mercury speciation method (at the time, it had only been validated at the pilot-scale level). However, after sampling at two power plants (the Ontario Hydro method was validated at one of them), the EPA issued an

  15. ASSESSMENT OF CONTROL TECHNOLOGIES FOR REDUCING EMISSIONS OF SO2 AND NOX FROM EXISTING COAL-FIRED UTILITY BOILERS

    EPA Science Inventory

    The report reviews information and estimated costs on 15 emissioncontrol technology categories applicable to existing coal-fired electric utility boilers. he categories include passive controls such as least emission dispatching, conventional processes, and emerging technologies ...

  16. Combined cycle power plant incorporating coal gasification

    DOEpatents

    Liljedahl, Gregory N.; Moffat, Bruce K.

    1981-01-01

    A combined cycle power plant incorporating a coal gasifier as the energy source. The gases leaving the coal gasifier pass through a liquid couplant heat exchanger before being used to drive a gas turbine. The exhaust gases of the gas turbine are used to generate both high pressure and low pressure steam for driving a steam turbine, before being exhausted to the atmosphere.

  17. Impact of fuel properties on advanced power systems

    SciTech Connect

    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.

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

    SciTech Connect

    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.

  19. Aspects of the electrical system design of the colmi 660 mw coal-fired power plant

    SciTech Connect

    Aguilar, J. ); Fernandez, J.H. )

    1992-01-01

    The conceptual design of the electrical systems for Mexico's Commission Federal de Electricidad (CFE) COLMI 660-MW coal-fired power plant builds on Bechtel's experience with nuclear, gas and coal-fired generating plants. The COLMI conceptual design incorporates a combination of new equipment applications and design considerations that make it more economical when compared to traditional alternatives. Also it provides a reliable state-of-the-art distribution system that is flexible enough for any unit in the 400-900 MW range. Alternative approaches were studied for the system design and equipment arrangement. This paper reviews the approach taken to arrive at the conceptual design and describes the equipment selected and the advantages they provide. Exact sizing and determination of characteristics of the equipment are not given because these were not determined during the conceptual design. These will be determined during the detailed design phase of the project.

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

    SciTech Connect

    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. Selection and adaptation of microalgae to growth in 100% unfiltered coal-fired flue gas.

    PubMed

    Aslam, Ambreen; Thomas-Hall, Skye R; Mughal, Tahira Aziz; Schenk, Peer M

    2017-06-01

    Microalgae have been considered for biological carbon capture and sequestration to offset carbon emissions from fossil fuel combustion. This study shows that mixed biodiverse microalgal communities can be selected for and adapted to tolerate growth in 100% flue gas from an unfiltered coal-fired power plant that contained 11% CO2. The high SOx and NOx emissions required slow adaptation of microalgae over many months, with step-wise increases from 10% to 100% flue gas supplementation and phosphate buffering at higher concentrations. After a rapid decline in biodiversity over the first few months, community profiling revealed Desmodesmus spp. as the dominant microalgae. To the authors' knowledge this work is the first to demonstrate that up 100% unfiltered flue gas from coal-fired power generation can be used for algae cultivation. Implementation of serial passages over a range of photobioreactors may contribute towards the development of microalgal-mediated carbon capture and sequestration processes.

  2. Potential of hybrid geothermal/coal fired power plants in Arizona

    SciTech Connect

    White, D.H.; Goldstone, L.A.

    1982-08-01

    The City of Burbank and the Ralph M. Parsons Company studies showed several advantages for hybrid geothermal/coal fired power plants, as follows: (1) the estimated cost of producing electricity in hybrid plant is about 18.3 mills/kWh, compared to 19.3 mills/kWh in an all-coal fired power plant; (2) the coal requirements for a given plant can be reduced about 12 to 17%; and (3) the geothermal brines can be used for power plant cooling water, and in some cases, as boiler feedwater. The pertinent results of the City of Burbank studies are summarized and applied to the geothermal and coal resources of Arizona for possible future utilization.

  3. Chemical, aerosol, and optical measurements in the plumes of three midwestern coal-fired power plants

    SciTech Connect

    Richards, L.W.; Anderson, J.A.; Blumenthal, D.L.; McDonald, J.A.; Macias, E.S.

    1985-01-01

    Airborne measurements were made in and near the plumes of the followiing midwestern coal-fired power plants in 1981: Kincaid in central Illinois in February, LaCygne near Kansas City in March, and Labadie near St. Louis in August and September. One objective of these measurements was to obtain data (reported elsewhere) to be used for the evaluation of plume visibility models. The results of the chemical and aerosol measurements are reported here.

  4. Coal-fired power plant and its emission reduction in Indonesia

    SciTech Connect

    Kuntjoro, D.

    1994-12-31

    Power generation availability is one important key to the rapid growth of Indonesia`s industrial sector. To secure future national energy needs, coal-fired power generation has been set up as a primary energy source. There are environmental concerns related to the emission of gases, particulates, and ash resulting from coal combustion. This paper discusses emission controls from burning high calorie, low sulfur coal and the national strategy to reduce emissions.

  5. Study on the effect of the operating condition on a pulverized coal-fired furnace using computational fluid dynamics commercial code

    SciTech Connect

    Manish Kumar; Santi Gopal Sahu . man_manna@yahoo.com

    2007-12-15

    Computer models for coal combustion are not sufficiently accurate to enable the design of pulverized coal fired furnaces or the selection of coal based on combustion behavior. Most comprehensive combustion models can predict with reasonable accuracy flow fields and heat transfer but usually with a much lesser degree of accuracy than the combustion of coal particles through char burnout. Computational fluid dynamics (CFD) modeling is recognized widely to be a cost-effective, advanced tool for optimizing the design and operating condition of the pulverized coal-fired furnaces for achieving cleaner and efficient power generation. Technologists and researchers are paying remarkable attention to CFD because of its value in the pulverized fuel fired furnace technology and its nonintrusiveness, sophistication, and ability to significantly reduce the time and expense involved in the design, optimization, trouble-shooting, and repair of power generation equipment. An attempt to study the effect of one of the operating conditions, i.e., burner tilts on coal combustion mechanisms, furnace exit gas temperature (FEGT), and heat flux distribution pattern, within the furnace has been made in this paper by modeling a 210 MW boiler using commercial CFD code FLUENT. 5 refs., 8 figs.

  6. Frequency comparative study of coal-fired fly ash acoustic agglomeration.

    PubMed

    Liu, Jianzhong; Wang, Jie; Zhang, Guangxue; Zhou, Junhu; Cen, Kefa

    2011-01-01

    Particulate pollution is main kind of atmospheric pollution. The fine particles are seriously harmful to human health and environment. Acoustic agglomeration is considered as a promising pretreatment technology for fine particle agglomeration. The mechanisms of acoustic agglomeration are very complex and the agglomeration efficiency is affected by many factors. The most important and controversial factor is frequency. Comparative studies between high-frequency and low-frequency sound source to agglomerate coal-fired fly ash were carried out to investigate the influence of frequency on agglomeration efficiency. Acoustic agglomeration theoretical analysis, experimental particle size distributions (PSDs) and orthogonal design were examined. The results showed that the 20 kHz high-frequency sound source was not suitable to agglomerate coal-fired fly ash. Only within the size ranging from 0.2 to 0.25 microm the particles agglomerated to adhere together, and the agglomerated particles were smaller than 2.5 microm. The application of low-frequency (1000-1800 Hz) sound source was proved as an advisable pretreatment with the highest agglomeration efficiency of 75.3%, and all the number concentrations within the measuring range decreased. Orthogonal design L16 (4)3 was introduced to determine the optimum frequency and optimize acoustic agglomeration condition. According to the results of orthogonal analysis, frequency was the dominant factor of coal-fired fly ash acoustic agglomeration and the optimum frequency was 1400 Hz.

  7. Coal fire mapping of East Basuria Colliery, Jharia coalfield using vertical derivative technique of magnetic data

    NASA Astrophysics Data System (ADS)

    Pal, S. K.; Vaish, Jitendra; Kumar, Sahadev; Bharti, Abhay Kumar

    2016-02-01

    The present study deals with the coal fire mapping of East Basuria Colliery, Jharia coalfield, India, using the magnetic method. It is based on the fact that rise in temperature would result significant changes in magnetic susceptibility and thermo-remanent magnetization (TRM) of the overlying rocks. Magnetism increases slowly with the rise of temperature until the Curie temperature. Generally, rock/ overburden loses magnetization and becomes paramagnetic due to heating to Curie temperature, which results with significant reduction in magnetic susceptibility. However, magnetism increases significantly after cooling below the Curie temperature. Several data processing methods such as diurnal correction, reduction to pole (RTP), first and second vertical derivatives have been used for analysis of magnetic data and their interpretation. It is observed that the total magnetic field intensity anomaly of the area varies approximately from 44850 to 47460 nT and the residual magnetic anomaly varies approximately from -1323 to 1253 nT. The range of the magnetic anomaly after RTP is approximately 1050-1450 nT. About 20 low magnetic anomaly zones have been identified associated with active coal fire regions and 11 high magnetic anomaly zones have been identified associated with non-coal fire regions using vertical derivative techniques.

  8. Characteristics of NOx emission from Chinese coal-fired power plants equipped with new technologies

    NASA Astrophysics Data System (ADS)

    Ma, Zizhen; Deng, Jianguo; Li, Zhen; Li, Qing; Zhao, Ping; Wang, Liguo; Sun, Yezhu; Zheng, Hongxian; Pan, Li; Zhao, Shun; Jiang, Jingkun; Wang, Shuxiao; Duan, Lei

    2016-04-01

    Coal combustion in coal-fired power plants is one of the important anthropogenic NOx sources, especially in China. Many policies and methods aiming at reducing pollutants, such as increasing installed capacity and installing air pollution control devices (APCDs), especially selective catalytic reduction (SCR) units, could alter NOx emission characteristics (NOx concentration, NO2/NOx ratio, and NOx emission factor). This study reported the NOx characteristics of eight new coal-fired power-generating units with different boiler patterns, installed capacities, operating loads, and coal types. The results showed that larger units produced less NOx, and anthracite combustion generated more NOx than bitumite and lignite combustion. During formation, the NOx emission factors varied from 1.81 to 6.14 g/kg, much lower than those of older units at similar scales. This implies that NOx emissions of current and future units could be overestimated if they are based on outdated emission factors. In addition, APCDs, especially SCR, greatly decreased NOx emissions, but increased NO2/NOx ratios. Regardless, the NO2/NOx ratios were lower than 5%, in accordance with the guidelines and supporting the current method for calculating NOx emissions from coal-fired power plants that ignore NO2.

  9. Co-combustion of solid recovered fuels in coal-fired power plants.

    PubMed

    Thiel, Stephanie; Thomé-Kozmiensky, Karl Joachim

    2012-04-01

    Currently, in ten coal-fired power plants in Germany solid recovered fuels from mixed municipal waste and production-specific commercial waste are co-combusted and experiments have been conducted at other locations. Overall, in 2010 approximately 800,000 tonnes of these solid recovered fuels were used. In the coming years up to 2014 a slight decline in the quantity of materials used in co-combustions is expected. The co-combustion activities are in part significantly influenced by increasing power supply from renewable sources of energy and their impact on the regime of coal-fired power plants usage. Moreover, price trends of CO₂ allowances, solid recovered fuels as well as imported coal also have significant influence. In addition to the usage of solid recovered fuels with biogenic content, the co-combustion of pure renewable biofuels has become more important in coal-fired power plants. The power plant operators make high demands on the quality of solid recovered fuels. As the operational experience shows, a set of problems may be posed by co-combustion. The key factors in process engineering are firing technique and corrosion. A significant ecological key factor is the emission of pollutants into the atmosphere. The results of this study derive from research made on the basis of an extensive literature search as well as a survey on power plant operators in Germany. The data from operators was updated in spring 2011.

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

    SciTech Connect

    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.

  11. High Black Carbon Concentrations and Atmospheric Pollution Around Indian Coal Fired Thermal Power Plants

    NASA Astrophysics Data System (ADS)

    Singh, R. P.; Singh, A. K.; Kumar, S.; Takemura, T.

    2013-12-01

    Emissions from coal-fired Thermal Power Plants (TPPs) are among major sources of black carbon (BC) aerosols in the atmosphere and air quality degradation. Knowledge of BC emissions from TPPs is important in characterizing regional carbonaceous particulate emissions, associated with regional climate forcing as well as effects on human health. Furthermore, elevated BC concentrations, over the Indo-Gangetic Plains (IGP) and the Himalayan foothills, has emerged as an important subject to estimate effects of deposition and atmospheric warming of BC on the accelerated melting of snow and glaciers in the Himalaya. For the first time, this study reports BC concentrations and aerosol characterization near coal-fired power plants in the IGP. Coal-fired TPPs are also recognized as major point-sources of other atmospheric pollutants such as high NO2 hotspots in the IGP, as evident from the OMI Aura satellite observations. In-situ measurements were carried out in Kanpur (central IGP) and Singrauli (eastern IGP), during January and March 2013. We show detailed spatial variability of BC within ~10 km from TPPs, that indicate BC variations up to 95 μg/m3, with strong diurnal variations associated with BC concentration peaks during early morning and evening hours. BC concentrations were measured to be significantly higher in close proximity to the coal-fired TPPs (as high as 200μg/m3), compared to the outside domain of our study region. Co-located ground-based sunphotometer measurements of aerosols also show significant spatial variability around the TPPs, with aerosol optical depth (AOD) in the range 0.38-0.58, and the largest AOD of 0.7 - 0.95 near the TPPs (similar to the peak BC concentrations). Additionally, the Angstrom Exponent was found to be in the range 0.4 - 1.0 (maximum in the morning time) and highest in the vicinity of TPPs (~1.0) suggesting abundance of fine particulates, whereas lowest recorded over the surrounding coal mining fields. We also inter-compare global

  12. Simulation of a combined-cycle engine

    NASA Technical Reports Server (NTRS)

    Vangerpen, Jon

    1991-01-01

    A FORTRAN computer program was developed to simulate the performance of combined-cycle engines. These engines combine features of both gas turbines and reciprocating engines. The computer program can simulate both design point and off-design operation. Widely varying engine configurations can be evaluated for their power, performance, and efficiency as well as the influence of altitude and air speed. Although the program was developed to simulate aircraft engines, it can be used with equal success for stationary and automative applications.

  13. Gasification combined cycle R&A assessment

    NASA Astrophysics Data System (ADS)

    Witt, J. H.; Neely, M. C.

    This paper describes the development and application of a methodology for assessing the reliability and availability of coal gasification combined cycle (GCC) power plant designs. The methodology was developed for and applied to a design of an 1100-megawatt baseload GCC power plant. The specific objectives of the analysis were to obtain baseline reliability and availability values for the GCC plant design and to develop criticality rankings of the plant's components based on their impact on the system's reliability and availability measures

  14. Commercial development of advanced PFBC technology

    SciTech Connect

    McClung, J.D.

    1995-12-31

    In the 1970s, the coal-fired power generation industry recognized that the declining price of electricity over the previous five decades was coming to an end. Maximum use had been made of existing cycle efficiencies and scale-up. As researchers looked for a new approach, the focus shifted from the fully developed Rankine cycle to a new array of coal-fired plants using combined-cycle technology. Now, coal-fired combined-cycle plants are being introduced that shift power production to the Brayton cycle. Integrated Gasification Combined Cycle (IGCC) and Pressurized Fluidized Bed Combustion (PFBC) are two technologies at the forefront of this approach. The PFBC approach burns coal in a fluidized bed combustor at elevated pressure. The plant generates electricity from a gas turbine (expanding the hot, pressurized products of combustion) in addition to the conventional steam (bottoming) cycle. Such a plant can achieve thermal efficiencies of about 40 percent and have a levelized busbar cost below any competing coal-based technology. In addition to the economic benefits, the {open_quotes}built-in{close_quotes} feature of environmental control (SO{sub 2} and NO{sub x}) in the combustion process eliminates the need for external gas cleanup such as scrubbers. A PFBC can burn a wider range of coals than a pulverized-coal-fired (PCF) boiler and is simpler to operate and maintain than an IGCC power plant.

  15. Applications of the diesel coal combined cycle

    SciTech Connect

    Davis, T.P.; Shelor, F.M.

    1994-12-31

    The proprietary process known as the Diesel Coal Combined Cycle (DCCC) is examined for its application to new cogeneration plants and independent power production facilities as well as repowering of existing plants. High-cycle thermal efficiency with a heat rate in the range of 9,000 Btu/kWh (HHV) can be achieved by combining prime-mover diesel engine generators that have inherently high efficiency with boilers, specially designed burners, and a conventional Rankine steam cycle. Plants using the DCCC process can cleanly and efficiently use a variety of fuels including natural gas, which is prevalent in combustion turbine combined-cycle designs. The DCCC offers a power plant design that can use lower-cost fuels such as high-sulfur residual oil and coal. The diesel engine prime mover provides a high cycle efficiency over a wider load range than does a combustion turbine to meet today`s increasing needs for operational flexibility and dispatchability of the steam and power outputs. These needs can be fulfilled with a DCCC power plant at a lower capital cost ($1,000 to $1,200/kW) than conventional steam power plants and other clean coal technologies. DCCC plants are practical from the smallest industrial plants to those with over 200 MW of capacity. These plants will provide more wide-range efficiency and flexibility than combustion turbine combined cycles and operate at lower expense overall because of the fuel cost savings.

  16. Establishment of a database of emission factors for atmospheric pollutants from Chinese coal-fired power plants

    NASA Astrophysics Data System (ADS)

    Zhao, Yu; Wang, Shuxiao; Nielsen, Chris P.; Li, Xinghua; Hao, Jiming

    2010-04-01

    Field measurements and data investigations were conducted for developing an emission factor database for inventories of atmospheric pollutants from Chinese coal-fired power plants. Gaseous pollutants and particulate matter (PM) of different size fractions were measured using a gas analyzer and an electric low-pressure impactor (ELPI), respectively, for ten units in eight coal-fired power plants across the country. Combining results of field tests and literature surveys, emission factors with 95% confidence intervals (CIs) were calculated by boiler type, fuel quality, and emission control devices using bootstrap and Monte Carlo simulations. The emission factor of uncontrolled SO 2 from pulverized combustion (PC) boilers burning bituminous or anthracite coal was estimated to be 18.0S kg t -1 (i.e., 18.0 × the percentage sulfur content of coal, S) with a 95% CI of 17.2S-18.5S. NO X emission factors for pulverized-coal boilers ranged from 4.0 to 11.2 kg t -1, with uncertainties of 14-45% for different unit types. The emission factors of uncontrolled PM 2.5, PM 10, and total PM emitted by PC boilers were estimated to be 0.4A (where A is the percentage ash content of coal), 1.5A and 6.9A kg t -1, respectively, with 95% CIs of 0.3A-0.5A, 1.1A-1.9A and 5.8A-7.9A. The analogous PM values for emissions with electrostatic precipitator (ESP) controls were 0.032A (95% CI: 0.021A-0.046A), 0.065A (0.039A-0.092A) and 0.094A (0.0656A-0.132A) kg t -1, and 0.0147A (0.0092-0.0225A), 0.0210A (0.0129A-0.0317A), and 0.0231A (0.0142A-0.0348A) for those with both ESP and wet flue-gas desulfurization (wet-FGD). SO 2 and NO X emission factors for Chinese power plants were smaller than those of U.S. EPA AP-42 database, due mainly to lower heating values of coals in China. PM emission factors for units with ESP, however, were generally larger than AP-42 values, because of poorer removal efficiencies of Chinese dust collectors. For units with advanced emission control technologies, more field

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

    SciTech Connect

    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.

  18. Comparison of Integrated Gasifier-Combined Cycle and AFB-steam turbine systems for industrial cogeneration

    NASA Technical Reports Server (NTRS)

    Nainiger, J. J.; Abbott, J. M.; Burns, R. K.

    1981-01-01

    In the cogeneration technology alternatives study (CTAS) a number of advanced coal fired systems were examined and systems using a integrated coal gasifier IGCC or a fluid bed combustor AFB were found to yield attractive cogeneration results in industrial cogeneration applications. A range of site requirements and cogeneration sizing strategies using ground rules based on CTAS were used in comparing an IGCC and an AFB. The effect of time variations in site requirements and the sensitivity to fuel and electricity price assumptions are examined. The economic alternatives of industrial or utility ownership are also considered. The results indicate that the IGCC system has potentially higher fuel and emission savings and could be an attractive option for utility ownership. The AFB steam turbine system has a potentially higher return on investment and could be attractive assuming industrial ownership.

  19. Comparison of Integrated Gasifier-Combined Cycle and AFB-steam turbine systems for industrial cogeneration

    NASA Astrophysics Data System (ADS)

    Nainiger, J. J.; Abbott, J. M.; Burns, R. K.

    In the cogeneration technology alternatives study (CTAS) a number of advanced coal fired systems were examined and systems using a integrated coal gasifier IGCC or a fluid bed combustor AFB were found to yield attractive cogeneration results in industrial cogeneration applications. A range of site requirements and cogeneration sizing strategies using ground rules based on CTAS were used in comparing an IGCC and an AFB. The effect of time variations in site requirements and the sensitivity to fuel and electricity price assumptions are examined. The economic alternatives of industrial or utility ownership are also considered. The results indicate that the IGCC system has potentially higher fuel and emission savings and could be an attractive option for utility ownership. The AFB steam turbine system has a potentially higher return on investment and could be attractive assuming industrial ownership.

  20. Cogeneration Technology Alternatives Study (CTAS). Volume 6: Computer data. Part 1: Coal-fired nocogeneration process boiler, section A

    NASA Technical Reports Server (NTRS)

    Knightly, W. F.

    1980-01-01

    Various advanced energy conversion systems (ECS) are compared with each other and with current technology systems for their savings in fuel energy, costs, and emissions in individual plants and on a national level. About fifty industrial processes from the largest energy consuming sectors were used as a basis for matching a similar number of energy conversion systems that are considered as candidates which can be made available by the 1985 to 2000 time period. The sectors considered included food, textiles, lumber, paper, chemicals, petroleum, glass, and primary metals. The energy conversion systems included steam and gas turbines, diesels, thermionics, stirling, closed cycle and steam injected gas turbines, and fuel cells. Fuels considered were coal, both coal and petroleum based residual and distillate liquid fuels, and low Btu gas obtained through the on-site gasification of coal. Computer generated reports of the fuel consumption and savings, capital costs, economics and emissions of the cogeneration energy conversion systems (ECS's) heat and power matched to the individual industrial processes are presented for coal fired process boilers. National fuel and emissions savings are also reported for each ECS assuming it alone is implemented.

  1. Cogeneration Technology Alternatives Study (CTAS). Volume 6: Computer data. Part 1: Coal-fired nocogeneration process boiler, section A

    NASA Astrophysics Data System (ADS)

    Knightly, W. F.

    1980-05-01

    Various advanced energy conversion systems (ECS) are compared with each other and with current technology systems for their savings in fuel energy, costs, and emissions in individual plants and on a national level. About fifty industrial processes from the largest energy consuming sectors were used as a basis for matching a similar number of energy conversion systems that are considered as candidates which can be made available by the 1985 to 2000 time period. The sectors considered included food, textiles, lumber, paper, chemicals, petroleum, glass, and primary metals. The energy conversion systems included steam and gas turbines, diesels, thermionics, stirling, closed cycle and steam injected gas turbines, and fuel cells. Fuels considered were coal, both coal and petroleum based residual and distillate liquid fuels, and low Btu gas obtained through the on-site gasification of coal. Computer generated reports of the fuel consumption and savings, capital costs, economics and emissions of the cogeneration energy conversion systems (ECS's) heat and power matched to the individual industrial processes are presented for coal fired process boilers. National fuel and emissions savings are also reported for each ECS assuming it alone is implemented.

  2. The development of a coal-fired combustion system for industrial process heating applications. Quarterly technical progress report, January 1992--March 1992

    SciTech Connect

    Not Available

    1992-07-16

    PETC has implemented a number of advanced combustion research projects that will lead to the establishment of a broad, commercially acceptable engineering data base for the advancement of coal as the fuel of choice for boilers, furnaces, and process heaters. Vortec Corporation`s Coal-Fired Combustion System for Industrial Process Heating Applications has been selected for Phase III development under contract DE-AC22-91PC91161. This advanced combustion system research program is for the development of innovative coal-fired process heaters which can be used for high temperature melting, smelting, recycling, and refining processes. The process heater concepts to be developed are based on advanced glass melting and ore smelting furnaces developed and patented by Vortec Corporation. The process heater systems to be developed have multiple use applications; however, the Phase HI research effort is being focused on the development of a process heater system to be used for producing glass frits and wool fiber from boiler and incinerator ashes. The primary objective of the Phase III project is 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 marketability. The economic evaluation of commercial scale CMS processes has begun. In order to accurately estimate the cost of the primary process vessels, preliminary designs for 25, 50, and 100 ton/day systems have been started under Task 1. This data will serve as input data for life cycle cost analysis performed as part of techno-economic evaluations. The economic evaluations of commercial CMS systems will be an integral part of the commercialization plan.

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

    SciTech Connect

    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.

  4. Overview of the Turbine Based Combined Cycle Discipline

    NASA Technical Reports Server (NTRS)

    Thomas, Scott R.; Walker, James F.; Pittman, James L.

    2009-01-01

    The NASA Fundamental Aeronautics Hypersonics project is focused on technologies for combined cycle, airbreathing propulsions systems to enable reusable launch systems for access to space. Turbine Based Combined Cycle (TBCC) propulsion systems offer specific impulse (Isp) improvements over rocket-based propulsion systems in the subsonic takeoff and return mission segments and offer improved safety. The potential to realize more aircraft-like operations with expanded launch site capability and reduced system maintenance are additional benefits. The most critical TBCC enabling technologies as identified in the National Aeronautics Institute (NAI) study were: 1) mode transition from the low speed propulsion system to the high speed propulsion system, 2) high Mach turbine engine development, 3) transonic aero-propulsion performance, 4) low-Mach-number dual-mode scramjet operation, 5) innovative 3-D flowpath concepts and 6) innovative turbine based combined cycle integration. To address several of these key TBCC challenges, NASA s Hypersonics project (TBCC Discipline) initiated an experimental mode transition task that includes an analytic research endeavor to assess the state-of-the-art of propulsion system performance and design codes. This initiative includes inlet fluid and turbine performance codes and engineering-level algorithms. This effort has been focused on the Combined Cycle Engine Large-Scale Inlet Mode Transition Experiment (CCE LIMX) which is a fully integrated TBCC propulsion system with flow path sizing consistent with previous NASA and DoD proposed Hypersonic experimental flight test plans. This experiment is being tested in the NASA-GRC 10 x 10 Supersonic Wind Tunnel (SWT) Facility. The goal of this activity is to address key hypersonic combined-cycle-engine issues: (1) dual integrated inlet operability and performance issues unstart constraints, distortion constraints, bleed requirements, controls, and operability margins, (2) mode

  5. Solid oxide fuel cell combined cycles

    SciTech Connect

    Bevc, F.P.; Lundberg, W.L.; Bachovchin, D.M.

    1996-12-31

    The integration of the solid oxide fuel cell and combustion turbine technologies can result in combined-cycle power plants, fueled with natural gas, that have high efficiencies and clean gaseous emissions. Results of a study are presented in which conceptual designs were developed for 3 power plants based upon such an integration, and ranging in rating from 3 to 10 MW net ac. The plant cycles are described and characteristics of key components summarized. Also, plant design-point efficiency estimates are presented as well as values of other plant performance parameters.

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

    SciTech Connect

    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

  7. Demonstration of Selective Catalytic Reduction Technology to Control Nitrogen Oxide Emissions From High-Sulfur, Coal-Fired Boilers: A DOE Assessment

    SciTech Connect

    Federal Energy Technology Center

    1999-12-01

    The goal of the U.S. Department of Energy (DOE) Clean Coal Technology (CCT) program is to furnish the energy marketplace with a number of advanced, more efficient, and environmentally responsible coal utilization technologies through demonstration projects. These projects seek to establish the commercial feasibility of the most promising advanced coal technologies that have developed beyond the proof-of-concept stage. This document serves as a DOE post-project assessment of a project selected in CCT Round 2. The project is described in the report ''Demonstration of Selective Catalytic Reduction (SCR) Technology for the Control of Nitrogen Oxide (NO{sub x}) Emissions from High-Sulfur, Coal-Fired Boilers'' (Southern Company Services 1990). In June 1990, Southern Company Services (Southern) entered into a cooperative agreement to conduct the study. Southern was a cofunder and served as the host at Gulf Power Company's Plant Crist. Other participants and cofunders were EPRI (formerly the Electric Power Research Institute) and Ontario Hydro. DOE provided 40 percent of the total project cost of $23 million. The long-term operation phase of the demonstration was started in July 1993 and was completed in July 1995. This independent evaluation is based primarily on information from Southern's Final Report (Southern Company Services 1996). The SCR process consists of injecting ammonia (NH{sub 3}) into boiler flue gas and passing the 3 flue gas through a catalyst bed where the NO{sub x} and NH{sub 3} react to form nitrogen and water vapor. The objectives of the demonstration project were to investigate: Performance of a wide variety of SCR catalyst compositions, geometries, and manufacturing methods at typical U.S. high-sulfur coal-fired utility operating conditions; Catalyst resistance to poisoning by trace metal species present in U.S. coals but not present, or present at much lower concentrations, in fuels from other countries; and Effects on the balance-of-plant equipment

  8. Performance potential of combined cycles integrated with low-Btu gasifiers for future electric utility applications

    NASA Technical Reports Server (NTRS)

    Nainiger, J. J.; Burns, R. K.

    1977-01-01

    A comparison and an assessment of 10 advanced utility power systems on a consistent basis and to a common level of detail were analyzed. Substantial emphasis was given to a combined cycle systems integrated with low-Btu gasifiers. Performance and cost results from that study were presented for these combined cycle systems, together with a comparative evaluation. The effect of the gasifier type and performance and the interface between the gasifier and the power system were discussed.

  9. Export of reactive nitrogen from coal-fired power plants in the U.S.: Estimates from a plume-in-grid modeling study

    NASA Astrophysics Data System (ADS)

    Vijayaraghavan, Krish; Zhang, Yang; Seigneur, Christian; Karamchandani, Prakash; Snell, Hilary E.

    2009-02-01

    The export of reactive nitrogen (nitrogen oxides and their oxidation products, collectively referred to as NOy) from coal-fired power plants in the U.S. to the rest of the world could have a significant global contribution to ozone. Traditional Eulerian gridded air quality models cannot characterize accurately the chemistry and transport of plumes from elevated point sources such as power plant stacks. A state-of-the-science plume-in-grid (PinG) air quality model, a reactive plume model embedded in an Eulerian gridded model, is used to estimate the export of NOy from 25 large coal-fired power plants in the U.S. (in terms of NOx and SO2 emissions) in July 2001 to the global atmosphere. The PinG model used is the Community Multiscale Air Quality Model with Advanced Plume Treatment (CMAQ-APT). A benchmark simulation with only the gridded model, CMAQ, is also conducted for comparison purposes. The simulations with and without advanced plume treatment show differences in the calculated export of NOy from the 25 plants considered reflecting the effect of using a detailed and explicit treatment of plume transport and chemistry. The advanced plume treatment results in 31% greater simulated export of NOy compared to the purely grid-based modeling approach. The export efficiency of NOy (the fraction of NOy emitted that is exported) is predicted to be 21% without APT and 27% with APT. When considering only export through the eastern boundary across the Atlantic, CMAQ-APT predicts that the export efficiency is 24% and that 2% of NOy is exported as NOx, 49% as inorganic nitrate, and 25% as PAN. These results are in reasonably good agreement with an analysis reported in the literature of aircraft measurements over the North Atlantic.

  10. Computational prediction of tube erosion in coal fired power utility boilers

    SciTech Connect

    Lee, B.E.; Fletcher, C.A.J.; Behnia, M.

    1999-10-01

    Erosion of boiler tubes causes serious operational problems in many pulverized coal-fired utility boilers. A new erosion model has been developed in the present study for the prediction of boiler tube erosion. The Lagrangian approach is employed to predict the behavior of the particulate phase. The results of computational prediction of boiler tube erosion and the various parameters causing erosion are discussed in this paper. Comparison of the numerical predictions for a single tube erosion with experimental data shows very good agreement.

  11. Effect of deposits on corrosion of materials exposed in the Coal-Fired Flow Facility

    SciTech Connect

    Natesan, K.

    1993-05-01

    Candidate heat exchanger materials tested in the Low Mass Flow train at the Coal-Fired Flow Facility (CFFF) at Tullahoma, TN. were analyzed to evaluate their corrosion performance. Tube specimens obtained at each foot of the 14-ft-long Unbend tubes were analyzed for corrosion-scale morphologies, scale thicknesses, and internal penetration depths. Results developed on 1500- and 2000- h exposed specimens were correlated with exposure temperature. In addition, deposit materials collected at several locations in the CFFF were analyzed in detail to characterize the chemical and physical properties of the deposits and their influence on corrosion performance of tube materials.

  12. Evaluation of electricity generation from underground coal fires and waste banks

    SciTech Connect

    Chiasson, A.D.; Yavuzturk, C.; Walrath, D.E.

    2007-06-15

    A temperature response factors model of vertical thermal energy extraction boreholes is presented to evaluate electricity generation from underground coal fires and waste banks. Sensitivity and life-cycle cost analyses are conducted to assess the impact of system parameters on the production of 1 MW of electrical power using a theoretical binary-cycle power plant. Sensitivity analyses indicate that the average underground temperature has the greatest impact on the exiting fluid temperatures from the ground followed by fluid flow rate and ground thermal conductivity. System simulations show that a binary-cycle power plant may be economically feasible at ground temperatures as low as 190 {sup o}C.

  13. Study of N2 CARS spectra of a coal-fired flow facility

    NASA Astrophysics Data System (ADS)

    Singh, Jagdish P.; Yueh, Fang-Yu

    1993-07-01

    A comparative study of N2 CARS spectra was performed at a coal-fired flow facility diffuser and aerodynamic duct. Spectra recorded at the diffuser have atypical feature near V = 1-2 N2 CARS vibrational transition. Atypical feature intensity decreases in the aerodynamic duct spectra. N2 CARS spectra at the aerodynamic duct show the laser-produced C2 absorption around the fundamental band. The CARS inferred temperature at the diffuser is estimated to be +/- 100 K where as at the aerodynamic duct it is +/- 250 K. The error in the inferred temperature with different interference in the CARS spectrum was also studied.

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

    SciTech Connect

    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.

  15. CO sub 2 emissions from coal-fired and solar electric power plants

    SciTech Connect

    Keith, F.; Norton, P.; Brown, D.

    1990-05-01

    This report presents estimates of the lifetime carbon dioxide emissions from coal-fired, photovoltaic, and solar thermal electric power plants in the United States. These CO{sub 2} estimates are based on a net energy analysis derived from both operational systems and detailed design studies. It appears that energy conservation measures and shifting from fossil to renewable energy sources have significant long-term potential to reduce carbon dioxide production caused by energy generation and thus mitigate global warming. The implications of these results for a national energy policy are discussed. 40 refs., 8 figs., 23 tabs.

  16. Effect of coal-fired power generation on visibility in a nearby national park

    NASA Astrophysics Data System (ADS)

    Terhorst, Jonathan; Berkman, Mark

    2010-07-01

    The Mohave coal-fired power plant has long been considered a major contributor to visibility impairment in Grand Canyon National Park. The permanent closure of the plant in 2005 provides the opportunity to test this assertion. Although this analysis, based on data from the Interagency Monitoring of Protected Environments (IMPROVE) Aerosol Network, shows that fine sulfate levels in the park dropped following the closure, no statistically significant improvement in visibility resulted. Difference-in-differences estimation was used to control for other influences. This finding has important implications for the methods generally employed to attribute visibility reductions to air pollution sources.

  17. ASSESSING THE MERCURY HEALTH RISKS ASSOCIATED WITH COAL-FIRED POWER PLANTS: ISSUES IN ATMOSPHERIC PROCESSES.

    SciTech Connect

    LIPFERT, F.; SULLIVAN, T.; RENNINGER, S.

    2004-03-28

    The rationale for regulating air emissions of mercury from U.S. coal-fired power plants largely depends on mathematical dispersion modeling, including the atmospheric chemistry processes that affect the partitioning of Hg emissions into elemental (Hg{sub 0}) and the reactive (RGM) forms that may deposit more rapidly near sources. This paper considers and evaluates the empirical support for this paradigm. We consider the extant experimental data at three spatial scales: local (< 30 km), regional (< {approx}300 km), and national (multi-state data). An additional issue involves the finding of excess Hg levels in urban areas.

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

    SciTech Connect

    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.

  19. Numerical thermodynamic optimization of supercritical coal fired power plant with support of IPSEpro software

    NASA Astrophysics Data System (ADS)

    Elsner, Witold; Kowalczyk, Łukasz; Marek, Maciej

    2012-09-01

    The paper presents a thermodynamic optimization of supercritical coal fired power plant. The aim of the study was to optimize part of the thermal cycle consisted of high-pressure turbine and two chosen highpressure feed water heaters. Calculations were carried out using IPSEpro software combined with MATLAB, where thermal efficiency and gross power generation efficiency were chosen as objective functions. It was shown that the optimization with newly developed framework is sufficiently precise and its main advantage is the reduction of computation time on comparison to the classical method. The calculations have shown the tendency of the increase in efficiency, with the rise of a number of function variables.

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

    DOEpatents

    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.

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

    SciTech Connect

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

    2002-07-28

    This is the eighth 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. CFD modeling studies of RRI in a full scale utility boiler have been performed that provide further insight into the NOx reduction process that occurs if the furnace is not adequately staged. In situ reactivity data indicate thus far that titania sulfates under SCR conditions but there is no indication of vanadia sulfation in agreement with some, but not most literature results. Additional analysis and advanced diagnostics are under way to confirm this result and determine its accuracy. Construction of a catalyst characterization reactor system is nearly complete, with a few remaining details discussed in this report. Shakedown testing of the SCR field reactor was completed at the University of Utah pilot-scale coal furnace. The CEM system has been ordered. Talks continued with American Electric Power about hosting a demonstration at their Rockport plant.

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

    SciTech Connect

    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.

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

    SciTech Connect

    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

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

    SciTech Connect

    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.

  5. INTEGRATED PYROLYSIS COMBINED CYCLE BIOMASS POWER SYSTEM CONCEPT DEFINITION

    SciTech Connect

    Eric Sandvig; Gary Walling; Robert C. Brown; Ryan Pletka; Desmond Radlein; Warren Johnson

    2003-03-01

    Advanced power systems based on integrated gasification/combined cycles (IGCC) are often presented as a solution to the present shortcomings of biomass as fuel. Although IGCC has been technically demonstrated at full scale, it has not been adopted for commercial power generation. Part of the reason for this situation is the continuing low price for coal. However, another significant barrier to IGCC is the high level of integration of this technology: the gas output from the gasifier must be perfectly matched to the energy demand of the gas turbine cycle. We are developing an alternative to IGCC for biomass power: the integrated (fast) pyrolysis/ combined cycle (IPCC). In this system solid biomass is converted into liquid rather than gaseous fuel. This liquid fuel, called bio-oil, is a mixture of oxygenated organic compounds and water that serves as fuel for a gas turbine topping cycle. Waste heat from the gas turbine provides thermal energy to the steam turbine bottoming cycle. Advantages of the biomass-fueled IPCC system include: combined cycle efficiency exceeding 37 percent efficiency for a system as small as 7.6 MW{sub e}; absence of high pressure thermal reactors; decoupling of fuel processing and power generation; and opportunities for recovering value-added products from the bio-oil. This report provides a technical overview of the system including pyrolyzer design, fuel clean-up strategies, pyrolysate condenser design, opportunities for recovering pyrolysis byproducts, gas turbine cycle design, and Rankine steam cycle. The report also reviews the potential biomass fuel supply in Iowa, provide and economic analysis, and present a summery of benefits from the proposed system.

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

    SciTech Connect

    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.

  7. Westinghouse fuel cell combined cycle systems

    SciTech Connect

    Veyo, S.

    1996-12-31

    Efficiency (voltage) of the solid oxide fuel cell (SOFC) should increase with operating pressure, and a pressurized SOFC could function as the heat addition process in a Brayton cycle gas turbine (GT) engine. An overall cycle efficiency of 70% should be possible. In cogeneration, half of the waste heat from a PSOFC/GT should be able to be captured in process steam and hot water, leading to a fuel effectiveness of about 85%. In order to make the PSOFC/GT a commercial reality, satisfactory operation of the SOFC at elevated pressure must be verified, a pressurized SOFC generator module must be designed, built, and tested, and the combined cycle and parameters must be optimized. A prototype must also be demonstrated. This paper describes progress toward making the PSOFC/GT a reality.

  8. Effect of occupation on lipid peroxidation and antioxidant status in coal-fired thermal plant workers

    PubMed Central

    Kaur, Sandeep; Gill, Manmeet Singh; Gupta, Kapil; Manchanda, KC

    2013-01-01

    Background: Air pollution from coal-fired power units is large and varied, and contributes to a significant number of negative environmental and health effects. Reactive oxygen species (ROS) have been implicated in the pathogenesis of coal dust-induced toxicity in coal-fired power plants. Aim: The aim of the study was to measure free radical damage and the antioxidant activity in workers exposed to varying levels of coal dust. Material and Methods: The study population consisted of workers in coal handling unit, turbine unit, and boiler unit (n = 50 each), working in thermal power plant; and electricians (n = 50) from same department were taken as controls. Lipid peroxidation was measured by malondialdehyde (MDA) levels and antioxidant activity was determined by superoxide dismutase (SOD) and glutathione peroxidase (GPx) levels. Statistical analysis was carried out by Student's unpaired t-test. Result: MDA levels showed significant increase (P > 0.001) in the thermal power plant workers than the electricians working in the city. The levels of SOD and GPx were significantly higher (P > 0.001) in electricians as compared to subjects working in thermal plant. Among the thermal plant workers, the coal handling unit workers showed significant increase (P > 0.001) in MDA and significant decrease in SOD and GPx than the workers of boiler and turbine unit workers. Conclusion: Oxidative stress due to increase in lipid peroxidation and decrease in antioxidant activity results from exposure to coal dust and coal combustion products during thermal plant activities. PMID:24083143

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

    SciTech Connect

    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.

  10. Lichens as biomonitors around a coal-fired power station in Israel.

    PubMed

    Garty, Jacob; Tomer, Sharon; Levin, Tal; Lehr, Haya

    2003-03-01

    In the present study epiphytic lichens were applied as biomonitors of air pollution to determine the environmental impact of a coal-fired power station. Thalli of the lichen Ramalina lacera (With.) J.R. Laund. growing on carob twigs (Ceratonia siliqua L.) were collected with their substrate in July 2000 in a relatively unpolluted forest near HaZorea, Ramoth Menashe, Northeast Israel, and transplanted to 10 biomonitoring sites in the vicinity of the coal-fired power station Oroth Rabin near the town of Hadera. The lichens were retrieved in January 2001. We examined the following parameters of lichen vitality: (a) potential quantum yield of photosynthesis expressed as fluorescence ratio F(v)/F(m), (b) stress-ethylene production, and (c) electric conductivity expressing integrity of cell membranes. Following an exposure of 7 months, the lichens were retrieved and physiological parameters and data of elemental content were analyzed comparatively. Electric conductivity values correlated positively with B, Fe, Mg, Mn, Na, Pb, S, Sn, and Ti content. Concentrations of stress-ethylene correlated positively with Al, Ba, Pb, S, and V content and negatively with Cu and Sn. F(v)/F(m) ratios correlated negatively with S content. Some of the heavy metals reached lower levels than those reported in the relevant literature despite a wind regime that should have blown pollutants toward the biomonitoring sites.

  11. Applicability of the mixture of bituminous coal and anthracite to conventional pulverized coal firing boiler

    SciTech Connect

    Takano, Shin-Ichi; Kiga, Takashi; Miyamae, Shigehiro

    1994-12-31

    In some future, it is expected for Japanese power stations to be hard to get a high-grade coal like a bituminous coal. We conducted therefore pilot scale tests of pulverized blends of bituminous coal and anthracite using a 1.2MWt tunnel furnace in order to evaluate the applicability of the blends of bituminous coal and anthracite to conventional pulverized coal firing boilers. One kind of bituminous coal and two kinds of anthracite, one was of low ash content and another was of high ash content, were prepared for the test. Previously to pilot scale tests, coal properties and ash properties of the blends of bituminous coal and anthracite were analyzed to estimate the characteristics of combustion, ash deposition, and so on. In the test, we investigated the combustion efficiency, NOx emission, characteristics of ignition stability and grindability changing the blend rate of anthracite. Results of our study indicated that the critical restrictions on the blending rate of anthracite were unburnt carbon in fly ash and NOx emission as for coals tested. The acceptable limitation on blending rate of anthracite was 10 and 20%, respectively for two kinds of conventional pulverized coal fired boiler. Concerning to the grindability, it became worse with increasing the blending rate of anthracite from grindability test using a roller mill, while it became better estimating from HGI.

  12. [Emission characteristics of PM10 from coal-fired industrial boiler].

    PubMed

    Li, Chao; Li, Xing-Hua; Duan, Lei; Zhao, Meng; Duan, Jing-Chun; Hao, Ji-Ming

    2009-03-15

    Through ELPI (electrical low-pressure impactor) based dilution sampling system, the emission characteristics of PM10 and PM2.5 was studied experimentally at the inlet and outlet of dust catchers at eight different coal-fired industrial boilers. Results showed that a peak existed at around 0.12-0.20 microm of particle size for both number size distribution and mass size distribution of PM10 emitted from most of the boilers. Chemical composition analysis indicated that PM2.5 was largely composed of organic carbon, elementary carbon, and sulfate, with mass fraction of 3.7%-21.4%, 4.2%-24.6%, and 1.5%-55.2% respectively. Emission factors of PM10 and PM2.5 measured were 0.13-0.65 kg x t(-1) and 0.08-0.49 kg x t(-1) respectively for grate boiler using raw coal, and 0.24 kg x t(-1) and 0.22 kg x t(-1) for chain-grate boiler using briquette. In comparison, the PM2.5 emission factor of fluidized bed boiler is 1.14 kg x t(-1), much her than that of grate boiler. Due to high coal consumption and low efficiency of dust separator, coal-fired industrial boiler may become the most important source of PM10, and should be preferentially controlled in China.

  13. Estimation of NO{sub x} emissions from pulverized coal-fired utility boilers. Final report

    SciTech Connect

    Wildman, D.J.; Smouse, S.M.

    1995-05-01

    The formation of nitrogen oxides (NO{sub x}) during pulverized-coal combustion in utility boilers is governed by many factors, including the boiler`s design characteristics and operating conditions, and coal properties. Presently, no simple, reliable method is publicly available to estimate NO{sub x} emissions from any coal-fired boiler. A neural network back-propagation algorithm was previously developed using a small data set of boiler design characteristics and operating conditions, and coal properties for tangentially fired boilers. This initial effort yielded sufficient confidence in the use of neural network data analysis techniques to expand the data base to other boiler firing modes. A new neural network-based algorithm has been developed for all major pulverized coal-firing modes (wall, opposed-wall, cell, and tangential) that accurately predicts NO{sub x} emissions using 11 readily available data inputs. A sensitivity study, which was completed for all major input parameters, yielded results that agree with conventional wisdom and practical experience. This new algorithm is being used by others, including the Electric Power Research Institute (EPRI). EPRI has included the algorithm in its new software for making emissions compliance decisions, the Clean Air Technology Workstation.

  14. Synergistic mercury removal by conventional pollutant control strategies for coal-fired power plants in China.

    PubMed

    Wang, Shuxiao; Zhang, Lei; Wu, Ye; Ancora, Maria Pia; Zhao, Yu; Hao, Jiming

    2010-06-01

    China's 11th 5-yr plan has regulated total sulfur dioxide (SO2) emissions by installing flue gas desulfurization (FGD) devices and shutting down small thermal power units. These control measures will not only significantly reduce the emission of conventional pollutants but also benefit the reduction of mercury emissions from coal-fired power plants. This paper uses the emission factor method to estimate the efficiencies of these measures on mercury emission abatement. From 2005 to 2010, coal consumption in power plants will increase by 59%; however, the mercury emission will only rise from 141 to 155 t, with an increase of 10%. The average emission rate of mercury from coal burning will decrease from 126 mg Hg/t of coal to 87 mg Hg/t of coal. The effects of the three desulfurization measures were assessed and show that wet FGD will play an important role in mercury removal. Mercury emissions in 2015 and 2020 are also projected under different policy scenarios. Under the most probable scenario, the total mercury emission in coal-fired power plants in China will decrease to 130 t by 2020, which will benefit from the rapid installation of fabric filters and selective catalytic reduction.

  15. Selenium Partitioning and Removal Across a Wet FGD Scrubber at a Coal-Fired Power Plant.

    PubMed

    Senior, Constance L; Tyree, Corey A; Meeks, Noah D; Acharya, Chethan; McCain, Joseph D; Cushing, Kenneth M

    2015-12-15

    Selenium has unique fate and transport through a coal-fired power plant because of high vapor pressures of oxide (SeO2) in flue gas. This study was done at full-scale on a 900 MW coal-fired power plant with electrostatic precipitator (ESP) and wet flue gas desulfurization (FGD) scrubber. The first objective was to quantify the partitioning of selenium between gas and condensed phases at the scrubber inlet and outlet. The second objective was to determine the effect of scrubber operation conditions (pH, mass transfer, SO2 removal) on Se removal in both particulate and vapor phases. During part of the testing, hydrated lime (calcium hydroxide) was injected upstream of the scrubber. Gas-phase selenium and particulate-bound selenium were measured as a function of particle size at the inlet and outlet of the scrubber. The total (both phases) removal of Se across the scrubber averaged 61%, and was enhanced when hydrated lime sorbent was injected. There was evidence of gas-to-particle conversion of selenium across the scrubber, based on the dependence of selenium concentration on particle diameter downstream of the scrubber and on thermodynamic calculations.

  16. Plume wash-out near a coal-fired power plant: Measurements and model calculations

    NASA Astrophysics Data System (ADS)

    Ten Brink, H. M.; Janssen, A. J.; Slanina, J.

    The contribution of plume wash-out to the wet deposition of pollutants in the vicinity of a 1000 MWe coal-fired power plant in The Netherlands has been investigated. Whereas the extra wet deposition of heavy metals, emitted in the form of fly-ash, is not of importance as compared to the background deposition, drastically increased wet deposition of Cl -, F - and especially B-compounds was observed. Little extra deposition of S compounds was found, due to the fact that increased acidity in precipitation, associated with wash-out of HCl and (to a lesser extent) HF, limits the uptake of SO 2. The results of the experiments near the 1000 MWe installation were used to test and validate a wash-out model developed to study and predict wet removal of the major pollutants from a plume. Annual wet deposition patterns of these constituents due to plume wash-out have been calculated for a more characteristic 600 MWe coal-fired power plant. Very locally, at short distances from the stack, plume washout may nearly double local acid deposition under conditions prevalent in The Netherlands. This is mainly the result of wash-out of HCl, whereas the contribution of SO 2 is negligible. Significant plume contributions to the deposition of HF, B-compounds, Al, Ti and Br may be expected. Application of desulfurization units ('scrubbers') will reduce the emission and deposition of acids.

  17. CO2 post-combustion capture in coal-fired power plants integrated with solar systems

    NASA Astrophysics Data System (ADS)

    Carapellucci, R.; Giordano, L.; Vaccarelli, M.

    2015-11-01

    The majority of the World's primary energy consumption is still based on fossil fuels, representing the largest source of global CO2 emissions. According to the Intergovernmental Panel on Climate Change (IPCC), such emissions must be significantly reduced in order to avoid the dramatic consequences of global warming. A potential way to achieve this ambitious goal is represented by the implementation of CCS (Carbon Capture and Storage) technologies. However, the significant amount of energy required by the CCS systems still represents one the major barriers for their deployment. Focusing on post-combustion capture based on amine absorption, several interesting options have been investigated to compensate the energy losses due to solvent regeneration, also using renewable energy sources. One of the most promising is based on the use of concentrating solar power (CSP), providing a part of the energy requirement of the capture island. In this study the integration of a CSP system into a coal-fired power plant with CO2 postcombustion capture is investigated. Basically, a CSP system is used to support the heat requirement for amine regeneration, by producing saturated steam at low temperature. This allows to reduce or even eliminate the conventional steam extraction from the main power plant, affecting positively net power production and efficiency. The energy analysis of the whole system is carried out using the GateCycle software to simulate the coal-fired power plant and ChemCad platform for the CO2 capture process based on amine absorption.

  18. How to control fugitive dust emissions from coal-fired plants

    SciTech Connect

    Kestner, M.O.

    1987-06-01

    Until coal-mining and -preparation methods are capable of producing a dust-free fuel supply, coal-fired powerplants will require controls for fugitive emissions. Fortunately, dust-control costs pale in comparison to costs for sulfur dioxide, nitrogen oxides, and stack particulate controls. Nor do dust controls penalize power production or combustion efficiency, as can the others. In this context, dust control is the least expensive and complex of all the environmental technologies enlisted by coal-fired plants. Coal is dusty by nature and, as fuel-supply departments know, each coal is unique. The dustiness of coal depends primarily on its surface moisture and size distribution. Plants handling dry and fine-particle fuels will have the most severe problems with dust emissions. The susceptibility of the fuel to oxidation and its friability also influence dustiness. Generally, western coals are dustier than eastern coals-the latter being higher rank fuels that are often washed. Western coals usually degrade more rapidly on exposure to the elements during storage, and typically contain less surface moisture.

  19. Coal-fired combustion system for industrial process heating applications. Quarterly technical progress report, April 1995--June 1995

    SciTech Connect

    1995-08-01

    PETC has implemented a number of advanced combustion research projects that will lead to the establishment of a broad, commercially acceptable engineering data base for the advancement of coal as the fuel of choice for boilers, furnaces, and process heaters. This includes new installations and those existing installations that were originally designed for oil or gas firing. The data generated by these projects must be sufficient for private-sector decisions on the feasibility of using coal as the fuel of choice. This work should also provide incentives for the private sector to continue and expand the development, demonstration, and application of these combustion systems. Vortec Corporation`s Coal-Fired Combustion System for Industrial Process Heating Applications is being developed under contract DE-AC22-91PC91161 as part of this DOE development program. The current contract represents the third phase of a three-phase development program. Phase I of the program addressed the technical and economic feasibility of the process, and was initiated in 1987 and completed 1989. Phase II was initiated in 1989 and completed in 1990. During Phase II of the development, design improvements were made to critical components and the test program addressed the performance of the process using several different feedstocks. Phase III of the program was initiated September 1991 and is scheduled for completion in 1994. The Phase III research effort is being focused on the development of a process heater system to be used for producing value-added vitrified glass products from boiler/incinerator ashes and selected industrial wastes.

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

    SciTech Connect

    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

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

    SciTech Connect

    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

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

    SciTech Connect

    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

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

    SciTech Connect

    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

  4. Coal combined cycle system study. Volume I. Summary

    SciTech Connect

    Not Available

    1980-04-01

    The potential advantages for proceeding with demonstration of coal-fueled combined cycle power plants through retrofit of a few existing utility steam plants have been evaluated. Two combined cycle concepts were considered: Pressurized Fluidized Bed (PFB) combined cycle and gasification combined cycle. These concepts were compared with AFB steam plants, conventional steam plants with Flue Gas Desulfurization (FGD), and refueling such as with coal-oil mixtures. The ultimate targets are both new plants and conversion of existing plants. Combined cycle plants were found to be most competitive with conventional coal plants and offered lower air emissions and less adverse environmental impact. A demonstration is a necessary step toward commercialization.

  5. Heat Exchanger Design in Combined Cycle Engines

    NASA Astrophysics Data System (ADS)

    Webber, H.; Feast, S.; Bond, A.

    Combined cycle engines employing both pre-cooled air-breathing and rocket modes of operation are the most promising propulsion system for achieving single stage to orbit vehicles. The air-breathing phase is purely for augmentation of the mission velocity required in the rocket phase and as such must be mass effective, re-using the components of the rocket cycle, whilst achieving adequate specific impulse. This paper explains how the unique demands placed on the air-breathing cycle results in the need for sophisticated thermodynamics and the use of a series of different heat exchangers to enable precooling and high pressure ratio compression of the air for delivery to the rocket combustion chambers. These major heat exchanger roles are; extracting heat from incoming air in the precooler, topping up cycle flow temperatures to maintain constant turbine operating conditions and extracting rejected heat from the power cycle via regenerator loops for thermal capacity matching. The design solutions of these heat exchangers are discussed.

  6. Status of the Combined Cycle Engine Rig

    NASA Technical Reports Server (NTRS)

    Saunders, Dave; Slater, John; Dippold, Vance

    2009-01-01

    Status for the past year is provided of the turbine-based Combined-Cycle Engine (CCE) Rig for the hypersonic project. As part of the first stage propulsion of a two-stage-to-orbit vehicle concept, this engine rig is designed with a common inlet that supplies flow to a turbine engine and a dual-mode ramjet / scramjet engine in an over/under configuration. At Mach 4 the inlet has variable geometry to switch the airflow from the turbine to the ramjet / scramjet engine. This process is known as inlet mode-transition. In addition to investigating inlet aspects of mode transition, the rig will allow testing of turbine and scramjet systems later in the test series. Fully closing the splitter cowl "cocoons" the turbine engine and increases airflow to the scramjet duct. The CCE Rig will be a testbed to investigate integrated propulsion system and controls technology objectives. Four phases of testing are planned to 1) characterize the dual inlet database, 2) collect inlet dynamics using system identification techniques, 3) implement an inlet control to demonstrate mode-transition scenarios and 4) demonstrate integrated inlet/turbine engine operation through mode-transition. Status of the test planning and preparation activities is summarized with background on the inlet design and small-scale testing, analytical CFD predictions and some details of the large-scale hardware. The final stages of fabrication are underway.

  7. Computational investigation of rocket based combined cycle

    NASA Astrophysics Data System (ADS)

    Zhang, Xiao-bo; Wang, Zhan-xue; Liu, Zeng-wen

    2013-03-01

    Based on Computational Fluid Dynamic technology, the mixing process of Rocket Based Combined Cycle (RBCC) propulsion system is researched. The idea of RBCC propulsion system means combining rocket engine with ramjet engine effectively, which can flight from sea level to high altitude in wide Mach ranges. In order to analyze how the length of the mixing part affects mixing process, different length of mixing part are researched. As it is indicated, with a constant Mach number, increasing the length of mixing part makes main flow and second flow mix more evenly. Moreover, the length of mixing part has a slight impact on the thrust. Obviously the main consequence of increasing the length of mixing part is promoting the mix of main flow and second flow. Therefore, in order to decrease the weight of aircraft, it is of importance to reduce the length. Through comparing distribution of different cases, when working in the situation of maximum power, the flow in the nozzle of rocket engine is under expansion, while that in the nozzle is fully expanded. Nevertheless, in the case of high altitude and high Mach number, there exists a vortex in the nozzle of rocket engine because of over expansion; meanwhile, the flow in the nozzle is under expansion. Therefore, it is necessary to adjust nozzle throat area in order to increase the thrust of RBCC at high altitude.

  8. Low Cost, High Capacity Regenerable Sorbent for Carbon Dioxide Capture from Existing Coal-fired Power Plants

    SciTech Connect

    Alptekin, Gokhan; Jayaraman, Ambalavanan; Dietz, Steven

    2016-03-03

    In this project TDA Research, Inc (TDA) has developed a new post combustion carbon capture technology based on a vacuum swing adsorption system that uses a steam purge and demonstrated its technical feasibility and economic viability in laboratory-scale tests and tests in actual coal derived flue gas. TDA uses an advanced physical adsorbent to selectively remove CO2 from the flue gas. The sorbent exhibits a much higher affinity for CO2 than N2, H2O or O2, enabling effective CO2 separation from the flue gas. We also carried out a detailed process design and analysis of the new system as part of both sub-critical and super-critical pulverized coal fired power plants. The new technology uses a low cost, high capacity adsorbent that selectively removes CO2 in the presence of moisture at the flue gas temperature without a need for significant cooling of the flue gas or moisture removal. The sorbent is based on a TDA proprietary mesoporous carbon that consists of surface functionalized groups that remove CO2 via physical adsorption. The high surface area and favorable porosity of the sorbent also provides a unique platform to introduce additional functionality, such as active groups to remove trace metals (e.g., Hg, As). In collaboration with the Advanced Power and Energy Program of the University of California, Irvine (UCI), TDA developed system simulation models using Aspen PlusTM simulation software to assess the economic viability of TDA’s VSA-based post-combustion carbon capture technology. The levelized cost of electricity including the TS&M costs for CO2 is calculated as $116.71/MWh and $113.76/MWh for TDA system integrated with sub-critical and super-critical pulverized coal fired power plants; much lower than the $153.03/MWhand $147.44/MWh calculated for the corresponding amine based systems. The cost of CO2 captured for TDA’s VSA based system is $38

  9. RETROFIT COSTS FOR SO2 AND NOX CONTROL OPTIONS AT 200 COAL-FIRED PLANTS, VOLUME I - INTRODUCTION AND METHODOLOGY

    EPA Science Inventory

    The report gives results of a study, the objective of which was to significantly improve engineering cost estimates currently being used to evaluate the economic effects of applying SO2 and NOx controls at 200 large SO2-emitting coal-fired utility plants. To accomplish the object...

  10. Cloud modification by man-made pollutants: Effects of a coal-fired power plant on cloud drop spectra

    NASA Astrophysics Data System (ADS)

    Pueschel, R. F.; Barrett, E. W.; Wellman, D. L.; McGuire, J. A.

    1981-03-01

    Pollutants from coal-fired power plants increase the drop modal radii and broaden the drop spectra of stratocumulus clouds. Additional water from the coal combustion leads to a measurable increase of the liquid water content of polluted clouds. Implied consequences are an increase of the coalescence efficiency, and an increase in acidity, of affected clouds.

  11. LOW CONCENTRATION MERCURY SORPTION MECHANISMS AND CONTROL BY CALCIUM-BASED SORBENTS; APPLICATION IN COAL-FIRED PROCESSES

    EPA Science Inventory

    The capture of elemental mercury (Hgo) and mercuric chloride (HgCl2) by three types of calcium (Ca)-based sorbents was examined in this bench-scale study under conditions prevalent in coal fired utilities. Ca-based sorbent performances were compared to that of an activated carbon...

  12. The safety and economics of high ash anthracite fired mixing with petroleum-coke in pulverized coal-fired furnace

    SciTech Connect

    Zhang, Z.; Sun, X.; Li, F.

    1996-12-31

    Petroleum-coke was fired only in CFB because of its content of high S and low volatile matter. It will bring environmental and flame stability problems if petroleum-coke is fired in a pulverized coal-fired furnace. Low rank anthracite is fired in many pulverized coal-fired furnaces without flame stability problems. Here the authors blend high ash anthracite with petroleum-coke as the fuel for a pulverized coal-fired furnace to decrease the ash content in the fuel. Experimental results had shown that in mixing with petroleum-coke, the combustion behavior of the blended fuel was improved and ash deposition characteristic would not change compared with high ash anthracite. Using coal/petroleum-coke as the fuel for furnace can bring great benefits for the environment and furnace. But S content in blended fuel must be controlled under the regulation of S content in coal and the volatile content should not decrease too low for the coal-fired furnace design to avoid the environmental and flame stability problems.

  13. DEVELOPMENT OF COST-EFFECTIVE NONCARBON SORBENTS FOR HG0 REMOVAL FROM COAL-FIRED POWER PLANTS

    EPA Science Inventory

    Noncarbon materials or mineral oxides (silica gel, alumina, molecular sieves, zeolites, and montmorillonite) were modified with various functional groups such as amine, amide, thiol, urea and active additives such as elemental mercury (Hg0) vapor at coal-fired utility ...

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

    SciTech Connect

    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)

  15. Novel approach for extinguishing large-scale coal fires using gas-liquid foams in open pit mines.

    PubMed

    Lu, Xinxiao; Wang, Deming; Qin, Botao; Tian, Fuchao; Shi, Guangyi; Dong, Shuaijun

    2015-12-01

    Coal fires are a serious threat to the workers' security and safe production in open pit mines. The coal fire source is hidden and innumerable, and the large-area cavity is prevalent in the coal seam after the coal burned, causing the conventional extinguishment technology difficult to work. Foams are considered as an efficient means of fire extinguishment in these large-scale workplaces. A noble foam preparation method is introduced, and an original design of cavitation jet device is proposed to add foaming agent stably. The jet cavitation occurs when the water flow rate and pressure ratio reach specified values. Through self-building foaming system, the high performance foams are produced and then infused into the blast drilling holes at a large flow. Without complicated operation, this system is found to be very suitable for extinguishing large-scale coal fires. Field application shows that foam generation adopting the proposed key technology makes a good fire extinguishment effect. The temperature reduction using foams is 6-7 times higher than water, and CO concentration is reduced from 9.43 to 0.092‰ in the drilling hole. The coal fires are controlled successfully in open pit mines, ensuring the normal production as well as the security of personnel and equipment.

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

    SciTech Connect

    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

  17. DEVELOPMENT OF ANALYTICAL METHODS FOR THE QUANTIFICATION OF THE CHEMICAL FORMS OF MERCURY AND OTHER TARGET POLLUTANTS IN COAL-FIRED BOILER FLUE GAS

    SciTech Connect

    Terence J. McManus, Ph.D.

    1999-06-30

    Since approximately 55% of the electrical power produced in the U. S. is generated by coal-based power utility plants, there is serious concern about the massive amounts of coal combustion products emitted into the atmosphere annually. Furthermore, Title III of the 1990 Clean Air Act Amendments (CAAA) requires the measurement and inventory of a possible 189 hazardous air pollutants (HAPs) from any stationary source producing more than 10 tons per year of any one pollutant or more than 25 tons per year of total pollutants. Although power utilities are not presently included on the list of source categories, the CAAA requires the U. S. Environmental Protection Agency to carry out a study of emissions from electricity generation using fossil fuels. Since many of these HAPs are known to be present in coal derived flue gas, coal-fired electric power utilities may be subject to regulation following these studies if Congress considers it necessary. In a cooperative effort with the U. S. Environmental Protection Agency (EPA), the U. S. Department of Energy (DOE) through its Federal Energy Technology Center (FETC) initiated such a study in 1991. DOE-FETC commissioned five primary contractors to conduct emission studies at eight different coal-fired electric utilities. The eight sites represented a cross section of feed coal type, boiler designs, and particulate and gaseous pollutant control technologies. The major goal of these studies was to determine the sampling and analytical methodologies that could be used efficiently to perform these emission tests while producing representative and reliable emission data. The successful methodology could then be recommended to the EPA for use in compliance testing in the event the regulation of air toxic emissions from coal-fired power plants is implemented. A secondary purpose of the testing was to determine the effectiveness of the control technologies in reducing target hazardous air pollutants. Advanced Technology Systems, Inc

  18. A coal-fired combustion system for industrial process heating applications. Quarterly technical progress report, July 1993--September 1993

    SciTech Connect

    Not Available

    1993-10-30

    This advanced combustion system research program is for the development of innovative coal-fired process heaters which can be used for high temperature melting, smelting and waste vitrification processes. The process heater systems to be developed have multiple use applications; however, the Phase 3 research effort is being focused on the development of a process heater system to be used for producing value added vitrified glass products from boiler/incinerator ashes and industrial wastes. The primary objective of the Phase 3 project is 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 marketability. During the past quarter, the major effort was completing some of the system modification installation designs, completing industry funded testing, developing a surrogate TSCA ash composition, and completing the TSCA ash Test Plan. The installation designs will be used for the equipment modifications planned for the end of CY 93. The industry funded testing consisted of vitrifying Spent Aluminum Potliner (SPL) which is a listed hazardous waste. This testing has verified that SPL can be vitrified into a safe, recyclable glass product. Some results from this testing are provided in Section 2.2.1. The surrogate TSCA ash composition was developed with input from various DOE laboratories and subcontractors. The surrogate ash consists of a mixture of MSW fly ash and bottom ash spiked with heavy metal contaminants. The levels of metal additives are sufficient to ascertain the partitioning of the contaminants between the glass and effluent flow streams. Details of the surrogate composition and the planned testing is provided in Section 4.2.2.

  19. The NASA ASTP Combined-Cycle Propulsion Database Project

    NASA Technical Reports Server (NTRS)

    Hyde, Eric H.; Escher, Daric W.; Heck, Mary T.; Roddy, Jordan E.; Lyles, Garry (Technical Monitor)

    2000-01-01

    The National Aeronautics and Space Administration (NASA) communicated its long-term R&D goals for aeronautics and space transportation technologies in its 1997-98 annual progress report (Reference 1). Under "Pillar 3, Goal 9" a 25-year-horizon set of objectives has been stated for the Generation 3 Reusable Launch Vehicle ("Gen 3 RLV") class of space transportation systems. An initiative referred to as "Spaceliner 100" is being conducted to identify technology roadmaps in support of these objectives. Responsibility for running "Spaceliner 100" technology development and demonstration activities have been assigned to NASA's agency-wide Advanced Space Transportation Program (ASTP) office located at the Marshall Space Flight Center. A key technology area in which advances will be required in order to meet these objectives is propulsion. In 1996, in order to expand their focus beyond "allrocket" propulsion systems and technologies (see Appendix A for further discussion), ASTP initiated technology development and demonstration work on combined-cycle airbreathing/rocket propulsion systems (ARTT Contracts NAS8-40890 through 40894). Combined-cycle propulsion (CCP) activities (see Appendix B for definitions) have been pursued in the U.S. for over four decades, resulting in a large documented knowledge base on this subject (see Reference 2). In the fall of 1999 the Combined-Cycle Propulsion Database (CCPD) project was established with the primary purpose of collecting and consolidating CCP related technical information in support of the ASTP's ongoing technology development and demonstration program. Science Applications International Corporation (SAIC) was selected to perform the initial development of the Database under its existing support contract with MSFC (Contract NAS8-99060) because of the company's unique combination of capabilities in database development, information technology (IT) and CCP knowledge. The CCPD is summarized in the descriptive 2-page flyer appended

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

    SciTech Connect

    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

  1. An approach of surface coal fire detection from ASTER and Landsat-8 thermal data: Jharia coal field, India

    NASA Astrophysics Data System (ADS)

    Roy, Priyom; Guha, Arindam; Kumar, K. Vinod

    2015-07-01

    Radiant temperature images from thermal remote sensing sensors are used to delineate surface coal fires, by deriving a cut-off temperature to separate coal-fire from non-fire pixels. Temperature contrast of coal fire and background elements (rocks and vegetation etc.) controls this cut-off temperature. This contrast varies across the coal field, as it is influenced by variability of associated rock types, proportion of vegetation cover and intensity of coal fires etc. We have delineated coal fires from background, based on separation in data clusters in maximum v/s mean radiant temperature (13th band of ASTER and 10th band of Landsat-8) scatter-plot, derived using randomly distributed homogeneous pixel-blocks (9 × 9 pixels for ASTER and 27 × 27 pixels for Landsat-8), covering the entire coal bearing geological formation. It is seen that, for both the datasets, overall temperature variability of background and fires can be addressed using this regional cut-off. However, the summer time ASTER data could not delineate fire pixels for one specific mine (Bhulanbararee) as opposed to the winter time Landsat-8 data. The contrast of radiant temperature of fire and background terrain elements, specific to this mine, is different from the regional contrast of fire and background, during summer. This is due to the higher solar heating of background rocky outcrops, thus, reducing their temperature contrast with fire. The specific cut-off temperature determined for this mine, to extract this fire, differs from the regional cut-off. This is derived by reducing the pixel-block size of the temperature data. It is seen that, summer-time ASTER image is useful for fire detection but required additional processing to determine a local threshold, along with the regional threshold to capture all the fires. However, the winter Landsat-8 data was better for fire detection with a regional threshold.

  2. Current status and prediction of major atmospheric emissions from coal-fired power plants in Shandong Province, China

    NASA Astrophysics Data System (ADS)

    Xiong, Tianqi; Jiang, Wei; Gao, Weidong

    2016-01-01

    Shandong is considered to be the top provincial emitter of air pollutants in China due to its large consumption of coal in the power sector and its dense distribution of coal-fired plants. To explore the atmospheric emissions of the coal-fired power sector in Shandong, an updated emission inventory of coal-fired power plants for the year 2012 in Shandong was developed. The inventory is based on the following parameters: coal quality, unit capacity and unit starting year, plant location, boiler type and control technologies. The total SO2, NOx, fine particulate matter (PM2.5) and mercury (Hg) emissions are estimated at 705.93 kt, 754.30 kt, 63.99 kt and 10.19 kt, respectively. Larger units have cleaner emissions than smaller ones. The coal-fired units (≥300 MW) are estimated to account for 35.87% of SO2, 43.24% of NOx, 47.74% of PM2.5 and 49.83% of Hg emissions, which is attributed primarily to the improved penetration of desulfurization, LNBs, denitration and dust-removing devices in larger units. The major regional contributors are southwestern cities, such as Jining, Liaocheng, Zibo and Linyi, and eastern cities, such as Yantai and Qindao. Under the high-efficiency control technology (HECT) scenario analysis, emission reductions of approximately 58.61% SO2, 80.63% NOx, 34.20% PM2.5 and 50.08% Hg could be achieved by 2030 compared with a 2012 baseline. This inventory demonstrates why it is important for policymakers and researchers to assess control measure effectiveness and to supply necessary input for regional policymaking and the management of the coal-fired power sector in Shandong.

  3. Atomic-Based-Combined-Cycle Analysis

    NASA Technical Reports Server (NTRS)

    Han, Samuel S.

    1999-01-01

    Atomic-based-combined-cycle (ABCC) engine combines an air-breathing ramjet engine with an atomic reactor to increase the mission-averaged specific impulse and thereby increasing the dry-mass ratio. ABCC engine is similar to RBCC engine except that energy needed for the propulsive power is derived from nuclear reaction rather than chemical combustion used in the RBCC engine. The potential performance improvement of an ABCC engine over a RBCC engine comes from two factors. Firstly, the energy density of nuclear reaction is several order of magnitudes higher than the chemical combustion. Secondly, hydrogen can produce much higher nozzle exit velocity because of its small molecular weight. A one-dimensional, transient numerical model was used to analyze a generic RBCC engine and it is used as a baseline to evaluate an imaginary ABCC engine performance. A nuclear reactor is treated as a black box energy source that replaces the role of the primary rocket and the chemical combustion chamber in a RBCC engine. The performance of a generic ABCC engine along a flight path (q0 =10 (exp 3) lbf per square ft) shows that the mission averaged-specific impulse is about twice larger than RBCC engine and the dry mass-ratio is about 50% larger. Results of the present ABCC engine performance are based on the assumptions that the flow passage of working fluids is identical to that of RBCC engine and that a nuclear reactor is treated as an energy black box. Preliminary heat transfer calculation shows that the rate of heat transfer to the working fluids is within the limit of turbulent convective heat transfer regimes. The flow passage of realistic ABCC engine must be known for a better prediction of ABCC engine performance. Also, critical heat transfer calculations must be performed for the ejector mode and ramjet mode operations. This is possible only when the details of a reactor configuration are available.

  4. Atomic-Based-Combined-Cycle Analysis

    NASA Technical Reports Server (NTRS)

    Han, Sam; Bai, Don; Schmidt, George

    2000-01-01

    Atomic-based-combined-cycle (ABCC) engine combines an air-breathing ramjet engine with an atomic reactor to increase the mission-averaged specific impulse and thereby increasing the dry-mass ratio. ABCC engine is similar to RBCC engine except that energy needed for the propulsive power is derived from nuclear reaction rather than chemical combustion used in the RBCC engine. The potential performance improvement of an ABCC engine over a RBCC engine comes from two factors. Firstly, the energy density of nuclear reaction is several order of magnitudes higher than the chemical combustion. Secondly, hydrogen can produce much higher nozzle exit velocity because of its small molecular weight. A one-dimensional, transient numerical model was used to analyze a generic scramjet engine and it is used as a baseline to evaluate an imaginary ABCC engine performance. A nuclear reactor is treated as a black box energy source that replaces the role of the primary rocket and the chemical combustion chamber in a RBCC engine. Hydrogen is heated by the reactor and accelerated to produce high-speed ejection velocity. The ejection velocity up 10,000 m/sec is theoretically possible because of high energy density from the reactor and large gas constant of the hydrogen. Oxygen contained in the entrained air reacts with hydrogen and produces propulsive power for ejector mode operation. To provide enough thrust for initial acceleration, relatively large amount of hydrogen must be pumped through the reactor. Amount of oxygen contained in the entrained air may not be sufficient to burn all hydrogen and consequently combustion could occur at the end of exit nozzle. It is assumed that this combustion process is constant-pressure combustion at 1.0 atmospheric pressure and thus not affects the nozzle exit condition.

  5. Survey of European technology developments of SO/sub x//NO/sub x/ flue gas clean up for coal-fired boilers, also free piston stirling engines and coal tar burning diesel engines

    SciTech Connect

    Not Available

    1980-10-01

    In an effort to identify advanced RD and D projects as candidates for joint ventures and/or introduction to the US, European technology developments in the area of flue gas cleanup were surveyed. This survey covers both wet and dry scrubbers for coal-fired boilers and includes advanced systems for removal of SO/sub x/ or combined SO/sub x//NO/sub x/ removal. Information on lime/limestone scrubbers is limited to a tabulation of commercial sized installations. Emphasis is based on demonstrations and suggestions are provided as to why the particular projects are considered to be in advance of US technology. Areas of Europe covered are Austria, Belgium, Denmark, France, Germany, Italy, Netherlands, Norway and Sweden. With a lower priority, Austria, Spain, and Switzerland were screened for the existence of relevant work. This survey allows the following tentative conclusions: (1) the most relevant work is performed in Germany and Scandinavia (Denmark, Norway and Sweden). Work of some relevance was identified in the Netherlands and Italy; and (2) except for Germany, where FGD is applied commercially, no coal-fired lime/limestone scrubbers are operating commercially in the surveyed countries. (Outside Germany, the only operating lime/limestone scrubber is a 35 MW oil-fired unit in Stockholm). Four processes examined in Germany are described in some detail.

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

    SciTech Connect

    Constance Senior

    2004-10-29

    This is the seventh 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, 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.

  7. ASSESSMENT OF LOW COST NOVEL SORBENTS FOR COAL-FIRED POWER PLANT MERCURY CONTROL

    SciTech Connect

    Trevor Ley

    2003-07-01

    This is a Technical Report under a program funded by the Department of Energy's National Energy Technology Laboratory (NETL) to obtain the necessary information to assess the viability of lower cost alternatives to commercially available activated carbon for mercury control in coal-fired utilities. During this reporting period, ongoing tests and analysis on samples from Powerton and Valley to yield waste characterization results for the COHPAC long-term tests were conducted. A draft final report for the sorbent evaluations at Powerton was submitted. Sorbent evaluations at Valley Power Plant were completed on April 24, 2003. Data analysis and reporting for the Valley evaluations are continuing. A statement of work for sorbent evaluations at We Energies' Pleasant Prairie Power Plant was submitted and approved. Work will begin late August 2003. A no cost time extension was granted by DOE/NETL.

  8. Coal-Fired Power Plant (Western Coal): Environmental characterization information report

    NASA Astrophysics Data System (ADS)

    1981-01-01

    The latest available environmental and technical information on coal-fired power plants was collected from a number of sources. The typical plant chosen for characterization was a 500/MWe pulverized-coal plant burning western low-sulfur coal. The plant uses an electrostatic precipitator, a lime/limestone scrubber, and a wet, mechanical draft cooling tower. The plant fuel is supplied from offsite mines by unit-train deliveries with surface mined, thick seam coal, which undergoes minimum preparation prior to pulverization. The process, plant operating parameters, resources needed, and environmental residuals and products associated with the power plant are presented. Annual resource usage and pollutant discharges are given, assuming an annual plant capacity factor of 80 percent. Quantities are given in terms of ten to the twelth power Btu's of electric energy produced. Several plants are discussed individually. Environmental regulations are discussed. The overall physical requirements of the plant for land and water are discussed.

  9. Polychlorinated biphenyls in fly ashes collected from five coal-fired power plants in North China

    NASA Astrophysics Data System (ADS)

    Li, Zhiyong; Li, Xu; Ma, Huiqiao; Fan, Lin

    2017-01-01

    The 5 coal fly ash samples (CFA) were systematically collected from 5 coal-fired power plants (CFPPs) in North China for analysis of 86 PCB congeners. The predominant PCB congeners were PCB-6, -4/10, -28, -18, -19 and -16/32, which belonged to lighter molecular weight (LMW) congeners. The Σ86PCBs for 5 CFPPs ranged from 10.93 to 32.06 ng/g with the mean value as 16.01 ng/g. The PCBs in CFA were dominated by LMW-PCBs with 2-, 3- and 4-Cl PCBs contributed 34.80%, 39.18% and 9.21% to the Σ86PCBs. The TEQ concentrations for 5 CFPPs was 42.54 pg/g higher than 4 pg/g designed by Canada for soil quality, indicated the using of CFA as soil amendment should be cautioned.

  10. Florida coal-fired plant first zero-discharge water system in East

    SciTech Connect

    Not Available

    1982-03-01

    The first coal-fired power plant to achieve a zero-discharge water capacity is located in Gainsville, Florida. A brine concentrator treats waste flow from ash pond blowdown, cooling tower blowdown, and periodic demineralizer waste. The plant requires only 50,000 of the 350,000 gallons of ultrapure water produced daily, but hopes to market the rest. The system was designed for arid regions, but is of equal importance to environmentally fragile areas. A description of the Deerhaven unit notes that it may produce a $14 million profit in 1982 unless lower oil prices cancel some of its price advantages. A hybrid electronic-pneumatic control system makes the plant both responsive and reliable. 7 figures. (DCK)

  11. Detection, Analysis and Risk Assessment of Coal Fires in Northern China

    NASA Astrophysics Data System (ADS)

    Fischer, Christian; Li, Jing; Wu, Jianjun; Erhler, Christoph; Jiang, Weiguo; Guo, Shan; Yang, Bo

    2013-01-01

    Uncontrolled combustion of coal is a serious problem on a global scale. Since coal can easily be oxidized and often has a prominent “self-heating” capacity, many coal types have a tendency to combust spontaneously once sufficient oxygen is available and natural cooling is prevented. The rapid expansion of uncontrolled small-scale coal mining activities during the last 30-40 years and the increasing amount of not adequate closed down and now abandoned coal mine sites are supposed to have led to an increase of human-induced coal fires. Thus, coalfield fires need to be not only inventoried at regional scales through rapid and cost effective methods, but also assessed, monitored and secured, wherever appropriate. This leads to major research and technological development objectives: Easy-to-use, routine remote and in-situ monitoring techniques, based on airborne and space borne imagery, to become part in an integrated long-term monitoring framework.

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

    SciTech Connect

    Rubin, E.S.

    1988-06-01

    This is the third 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 April 1, 1988 to June 30, 1988. Our efforts during the last quarter focused on, (1) completion of a sulfuric acid plant model (used in conjunction with by-product recovery processes for SO{sub 2}/NO{sub x} removal) and, (2) an update the NOXSO process model. Other accomplishments involved revision and expansion of the enthalpy data algorithms used for process energy balances. The sections below present the details of these developments. References are included at the end of each section.

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

    SciTech Connect

    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.

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

    SciTech Connect

    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.

  15. Development and testing of commercial-scale, coal-fired combustion systems, Phase 3

    SciTech Connect

    Not Available

    1990-01-01

    The US Department of Energy's Pittsburgh Energy Technology Center (PETC) is actively pursuing the development and testing of coal-fired combustion systems for residential, commercial, and industrial market sectors. In response, MTCI initiated the development of a new combustor technology based on the principle of pulse combustion under the sponsorship of PETC (Contract No. AC22-83PC60419). The initial pulse combustor development program was conducted in three phases (MTCI, Development of a Pulsed Coal Combustor Fired with CWM, Phase III Final Report, DOE Contract No. AC22-83PC60419, November 1986). Phase I included a review of the prior art in the area of pulse combustion and the development of pulse combustor design concepts. It led to the conclusion that pulse combustors offer technical and base-of-operation advantages over conventional burners and also indicated favorable economics for replacement of oil- and gas-fired equipment.

  16. [Hazard evaluation modeling of particulate matters emitted by coal-fired boilers and case analysis].

    PubMed

    Shi, Yan-Ting; Du, Qian; Gao, Jian-Min; Bian, Xin; Wang, Zhi-Pu; Dong, He-Ming; Han, Qiang; Cao, Yang

    2014-02-01

    In order to evaluate the hazard of PM2.5 emitted by various boilers, in this paper, segmentation of particulate matters with sizes of below 2. 5 microm was performed based on their formation mechanisms and hazard level to human beings and environment. Meanwhile, taking into account the mass concentration, number concentration, enrichment factor of Hg, and content of Hg element in different coal ashes, a comprehensive model aimed at evaluating hazard of PM2.5 emitted by coal-fired boilers was established in this paper. Finally, through utilizing filed experimental data of previous literatures, a case analysis of the evaluation model was conducted, and the concept of hazard reduction coefficient was proposed, which can be used to evaluate the performance of dust removers.

  17. Mercury emissions of a coal-fired power plant in Germany

    NASA Astrophysics Data System (ADS)

    Weigelt, Andreas; Slemr, Franz; Ebinghaus, Ralf; Pirrone, Nicola; Bieser, Johannes; Bödewadt, Jan; Esposito, Giulio; van Velthoven, Peter F. J.

    2016-11-01

    Hg / SO2, Hg / CO, NOx / SO2 (NOx being the sum of NO and NO2) emission ratios (ERs) in the plume of the coal-fired power plant (CFPP), Lippendorf, near Leipzig, Germany, were determined within the European Tropospheric Mercury Experiment (ETMEP) aircraft campaign in August 2013. The gaseous oxidized mercury (GOM) fraction of mercury emissions was also assessed. Measured Hg / SO2 and Hg / CO ERs were within the measurement uncertainties consistent with the ratios calculated from annual emissions in 2013 reported by the CFPP operator, while the NOx / SO2 ER was somewhat lower. The GOM fraction of total mercury emissions, estimated using three independent methods, was below ˜ 25 %. This result is consistent with other findings and suggests that GOM fractions of ˜ 40 % of CFPP mercury emissions in current emission inventories are overestimated.

  18. A study of toxic emissions from a coal-fired gasification plant

    SciTech Connect

    Williams, A.; Behrens, G.

    1995-11-01

    Toxic emissions were measured in the gaseous, solid and aqueous effluent streams in a coal-fired gasification plant. Several internal process streams were also characterized to assess pollution control device effectiveness. The program, consisted of three major phases. Phase I was the toxics emission characterization program described above. phase II included the design, construction and shakedown testing of a high-temperature, high-pressure probe for collecting representative trace composition analysis of hot (1200{degrees}F) syngas. Phase III consisted of the collection of hot syngas samples utilizing the high-temperature probe. Preliminary results are presented which show the emission factors and removal efficiencies for several metals that are on the list of compounds defined by the Clean Air Act Amendments of 1990.

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

    SciTech Connect

    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.

  20. Economic and environmental costs of regulatory uncertainty for coal-fired power plants.

    PubMed

    Patiño-Echeverri, Dalia; Fischbeck, Paul; Kriegler, Elmar

    2009-02-01

    Uncertainty about the extent and timing of CO2 emissions regulations for the electricity-generating sector exacerbates the difficulty of selecting investment strategies for retrofitting or alternatively replacing existent coal-fired power plants. This may result in inefficient investments imposing economic and environmental costs to society. In this paper, we construct a multiperiod decision model with an embedded multistage stochastic dynamic program minimizing the expected total costs of plant operation, installations, and pollution allowances. We use the model to forecast optimal sequential investment decisions of a power plant operator with and without uncertainty about future CO2 allowance prices. The comparison of the two cases demonstrates that uncertainty on future CO2 emissions regulations might cause significant economic costs and higher air emissions.

  1. [Characterization of arsenic emissions from a coal-fired power plant].

    PubMed

    Guo, Xin; Zheng, Chu-guang; Cheng, Dan

    2006-04-01

    An emissions study for arsenic was conducted at a 300 MW coal-fired plant equipped with an electrostatic precipitator. The input and output streams such as coal, slag, ESP ash, and flue gas containing the post-ESP particulates were collected. Gaseous arsenic was sampled using EPA method 29 and the arsenic concentrations in the samples were measured using inductively coupled plasma atomic emission spectrometry (HG-ICP-AES). The mass balance recovery of arsenic estimated in this study was 87.2%. Arsenic concentration in stack gas was 2.5 microg/m3. Approximately 0.53% of the coal-derived arsenic was incorporated into slag, 84.6% of the arsenic was found on the fly ash collected by electrostatic precipitators, and 2.16% was found in the vapor phase. The relationship between arsenic concentration and ash particle size was also assessed, and arsenic is significantly concentrated in the small sized particles.

  2. Study of seed reporcessing systems for open cycle coal fired MHD power plants

    SciTech Connect

    1980-07-01

    If open-cycle coal-fired MHD power generation is to be commercially competitive, a large fraction of the potassium seed must be recycled. Cost of processing the seed for recycle must not be excessive and must be less than the cost of make up seed. A preliminary evaluation of the following processes was performed: PERC; formate; aqueous carbonate; modified tampella; scrubber, with and without removal of ash from spent seed; Tomlinson - Tampella; and electrodialysis and electrodialysis - deionization. Criteria considered in the evaluation included cost, state of development, seed loss, power requirements, availability, durability, key component risk, environmental impact, safety, controllability, and impurities buildup. None of the processes is fully proven for this type recycle operation. All require some degree of development. Results are presented in detail, and recommendations are included. (WHK)

  3. USA B and W`s IR-CFB coal-fired boiler operating experiences

    SciTech Connect

    Kavidass, S.; Maryamchik, M.; Kanoria, M.; Price, C.S.

    1998-12-31

    This paper updates 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 and is designed for 35 MWt output for cogeneration application, utilizing high sulfur, low ash Illinois coal. The second boiler is located at Kanoria Chemicals and Industries Ltd. (KCIL) in Renukoot, India and is designed for 81 MWt output for captive power requirements, firing high ash, low sulfur coal. This boiler was supplied by Thermax B and W (TBW) Ltd., a joint venture company of B and W and Thermax in India. The CFB technology is selected for these two units based on the fuel and environmental considerations. This paper discusses the various aspects of the two IR-CFB boilers` design features, performance, and operating experience including emissions.

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

    SciTech Connect

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

    SciTech Connect

    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.

  6. ASSESSMENT OF LOW COST NOVEL SORBENTS FOR COAL-FIRED POWER PLANT MERCURY CONTROL

    SciTech Connect

    Sharon Sjostrom

    2004-03-01

    The injection of sorbents upstream of a particulate control device is one of the most promising methods for controlling mercury emissions from coal-fired utility boilers with electrostatic precipitators and fabric filters. Studies carried out at the bench-, pilot-, and full-scale have shown that a wide variety of factors may influence sorbent mercury removal effectiveness. These factors include mercury species, flue gas composition, process conditions, existing pollution control equipment design, and sorbent characteristics. The objective of the program is to obtain the necessary information to assess the viability of lower cost alternatives to commercially available activated carbon for mercury control in coal-fired utilities. Prior to injection testing, a number of sorbents were tested in a slipstream fixed-bed device both in the laboratory and at two field sites. Based upon the performance of the sorbents in a fixed-bed device and the estimated cost of mercury control using each sorbent, seventeen sorbents were chosen for screening in a slipstream injection system at a site burning a Western bituminous coal/petcoke blend, five were chosen for screening at a site burning a subbituminous Powder River Basin (PRB) coal, and nineteen sorbents were evaluated at a third site burning a PRB coal. Sorbents evaluated during the program were of various materials, including: activated carbons, treated carbons, other non-activated carbons, and non-carbon material. The economics and performance of the novel sorbents evaluated demonstrate that there are alternatives to the commercial standard. Smaller enterprises may have the opportunity to provide lower price mercury sorbents to power generation customers under the right set of circumstances.

  7. An intelligent emissions controller for fuel lean gas reburn in coal-fired power plants.

    PubMed

    Reifman, J; Feldman, E E; Wei, T Y; Glickert, R W

    2000-02-01

    The application of artificial intelligence techniques for performance optimization of the fuel lean gas reburn (FLGR) system is investigated. A multilayer, feedforward artificial neural network is applied to model static nonlinear relationships between the distribution of injected natural gas into the upper region of the furnace of a coal-fired boiler and the corresponding oxides of nitrogen (NOx) emissions exiting the furnace. Based on this model, optimal distributions of injected gas are determined such that the largest NOx reduction is achieved for each value of total injected gas. This optimization is accomplished through the development of a new optimization method based on neural networks. This new optimal control algorithm, which can be used as an alternative generic tool for solving multidimensional nonlinear constrained optimization problems, is described and its results are successfully validated against an off-the-shelf tool for solving mathematical programming problems. Encouraging results obtained using plant data from one of Commonwealth Edison's coal-fired electric power plants demonstrate the feasibility of the overall approach. Preliminary results show that the use of this intelligent controller will also enable the determination of the most cost-effective operating conditions of the FLGR system by considering, along with the optimal distribution of the injected gas, the cost differential between natural gas and coal and the open-market price of NOx emission credits. Further study, however, is necessary, including the construction of a more comprehensive database, needed to develop high-fidelity process models and to add carbon monoxide (CO) emissions to the model of the gas reburn system.

  8. Mercury emissions and coal-fired power plants: Understanding the problems and identifying solutions

    SciTech Connect

    Davis, S.E.

    1997-12-31

    Electric utility emissions contribute to an array of air quality concerns, most notably ground-level ozone, acid deposition, global warming, and fine particulate pollution. More recently, electric utility emissions of air toxics such as mercury have been linked to serious ecological health effects, especially in fish-eating birds. Another issue that is gaining attention is that of eutrophication in marine waters from nitrogen oxide emissions. Coal-fired power plants warrant special consideration, particularly in regards to mercury. Coal-fired power plants currently represent over 30% of controllable anthropogenic emissions in the US and are expected to emit nearly half of all anthropogenic emissions in the US by 2010. However, because the human health threshold for mercury is not known with certainty and mercury control technologies such as activated carbon injection are extremely expensive, mercury emissions from electric utilities have not been addressed in the US through either regulation or voluntary initiatives. The Center is beginning to evaluate the viability of no- or low-regrets measures that may be more consistent with the current state of the science on human and ecological health effects. The Center is also looking at options to reduce eutophication. Specifically, the Center has: hosted a workshop to assess the viability of low-cost mercury control options for electric utilities, developed a proposal to undertake a mercury banking initiative, worked to reduce compliance costs associated with multiple and conflicting regulations, and investigated the potential benefits and workability of NOx trading between air and water sources These activities are described in greater detail in the Center`s paper.

  9. Elemental composition of saltcedar (Tamarix chinensis) impacted by efflents from a coal-fired power plant

    SciTech Connect

    Dreesen, D.R.; Wangen, L.E.

    1981-09-01

    The riparian shrub, saltcedar (Tamarix chinensis), was sampled in channels receiving effluents from a coal-fired power plant. Sources of these effluents included decant from coal ash/scrubber sludge disposal ponds, seepage from these ponds, and blowdown from the cooling lake. In addition, saltcedar was collected from an ephemeral stream channel both upstream and downstream from the input of these effluents. Green-leaf and branch material was analyzed for B, Cu, K, Mg, Na, Li, Sr, Ti, Al, Si, Fe, Mn, P, V, Mo, and Zn in both washed and unwashed samples. The goals of this study were to determine if elevated concentrations of trace, minor, and major elements were present in this species growing adjacent to effluent streams and whether these elements were present in this species growing adjacent to effluent streams and whether these elements were present as surficial contaminants. Washed saltcedar samples were enriched in Mo, B, Cu, K, Mg, Li, Mn, P, and Zn for one or more effluent channel locations. Unwashed saltcedar samples were enriched in soil or coal ash matrix elements (Si, Al, Ti, Ba, and Fe). These elements appeared to be present in coal ash particles deposited on the plant surfaces. More than 80% of these surficial contaminants were removed by washing. In addition to these elements, unwashed saltcedar samples from effluent channels were enriched in Mo, B, Cu, K, Mg, Li, Mn, P, and Zn compared with upstream values. The elements Ca, Na, and Sr were depleted in this species growing in some effluent channels. The results of this study indicated that B is the coal ash contaminant most likely to be absorbed and translocated by plants exposed to such coal-fired power plant effluents.

  10. Semi-quantitative characterisation of ambient ultrafine aerosols resulting from emissions of coal fired power stations.

    PubMed

    Hinkley, J T; Bridgman, H A; Buhre, B J P; Gupta, R P; Nelson, P F; Wall, T F

    2008-02-25

    Emissions from coal fired power stations are known to be a significant anthropogenic source of fine atmospheric particles, both through direct primary emissions and secondary formation of sulfate and nitrate from emissions of gaseous precursors. However, there is relatively little information available in the literature regarding the contribution emissions make to the ambient aerosol, particularly in the ultrafine size range. In this study, the contribution of emissions to particles smaller than 0.3 mum in the ambient aerosol was examined at a sampling site 7 km from two large Australian coal fired power stations equipped with fabric filters. A novel approach was employed using conditional sampling based on sulfur dioxide (SO(2)) as an indicator species, and a relatively new sampler, the TSI Nanometer Aerosol Sampler. Samples were collected on transmission electron microscope (TEM) grids and examined using a combination of TEM imaging and energy dispersive X-ray (EDX) analysis for qualitative chemical analysis. The ultrafine aerosol in low SO(2) conditions was dominated by diesel soot from vehicle emissions, while significant quantities of particles, which were unstable under the electron beam, were observed in the high SO(2) samples. The behaviour of these particles was consistent with literature accounts of sulfate and nitrate species, believed to have been derived from precursor emissions from the power stations. A significant carbon peak was noted in the residues from the evaporated particles, suggesting that some secondary organic aerosol formation may also have been catalysed by these acid seed particles. No primary particulate material was observed in the minus 0.3 mum fraction. The results of this study indicate the contribution of species more commonly associated with gas to particle conversion may be more significant than expected, even close to source.

  11. The net climate impact of coal-fired power plant emissions

    NASA Astrophysics Data System (ADS)

    Shindell, D.; Faluvegi, G.

    2010-04-01

    Coal-fired power plants influence climate via both the emission of long-lived carbon dioxide (CO2) and short-lived ozone and aerosol precursors. Using a climate model, we perform the first study of the spatial and temporal pattern of radiative forcing specifically for coal plant emissions. Without substantial pollution controls, we find that near-term net global mean climate forcing is negative due to the well-known aerosol masking of the effects of CO2. Imposition of pollution controls on sulfur dioxide and nitrogen oxides leads to a rapid realization of the full positive forcing from CO2, however. Long-term global mean forcing from stable (constant) emissions is positive regardless of pollution controls. Emissions from coal-fired power plants until ~1970, including roughly 1/3 of total anthropogenic CO2 emissions, likely contributed little net global mean climate forcing during that period though they may have induce weak Northern Hemisphere mid-latitude (NHml) cooling. After that time many areas imposed pollution controls or switched to low-sulfur coal. Hence forcing due to emissions from 1970 to 2000 and CO2 emitted previously was strongly positive and contributed to rapid global and especially NHml warming. Most recently, new construction in China and India has increased rapidly with minimal application of pollution controls. Continuation of this trend would add negative near-term global mean climate forcing but severely degrade air quality. Conversely, following the Western and Japanese pattern of imposing air quality pollution controls at a later time could accelerate future warming rates, especially at NHmls. More broadly, our results indicate that due to spatial and temporal inhomogenaities in forcing, climate impacts of multi-pollutant emissions can vary strongly from region to region and can include substantial effects on maximum rate-of-change, neither of which are captured by commonly used global metrics. The method we introduce here to estimate

  12. Rock magnetic finger-printing of soil from a coal-fired thermal power plant.

    PubMed

    Gune, Minal; Harshavardhana, B G; Balakrishna, K; Udayashankar, H N; Shankar, R; Manjunatha, B R

    2016-05-01

    We present seasonal rock magnetic data for 48 surficial soil samples collected seasonally around a coal-fired thermal power plant on the southwest coast of India to demonstrate how fly ash from the power plant is transported both spatially and seasonally. Sampling was carried out during pre-monsoon (March), early-monsoon (June), monsoon (September) and post-monsoon (December) seasons. Low- and high-frequency magnetic susceptibility (χlf and χhf), frequency-dependent magnetic susceptibility (χfd), χfd %, isothermal remanent magnetization (IRM), "hard" IRM (HIRM), saturation IRM (SIRM) and inter-parametric ratios were determined for the samples. Scanning electron microscopy (SEM) was used on limited number of samples. NOAA HYSPLIT MODEL backward trajectory analysis and principal component analysis were carried out on the data. Fly ash samples exhibit an average HIRM value (400.07 × 10(-5) Am(2) kg(-1)) that is comparable to that of soil samples. The pre- and post-monsoon samples show a consistent reduction in the concentration of magnetically "hard" minerals with increasing distance from the power plant. These data suggest that fly ash has indeed been transported from the power plant to the sampling locations. Hence, HIRM may perhaps be used as a proxy for tracking fly ash from coal-fired thermal power plants. Seasonal data show that the distribution of fly ash to the surrounding areas is minimum during monsoons. They also point to the dominance of SP magnetite in early-monsoon season, whereas magnetic depletion is documented in the monsoon season. This seasonal difference is attributable to both pedogenesis and anthropogenic activity i.e. operation of the thermal power plant.

  13. Measurement of slurry droplets in coal-fired flue gas after WFGD.

    PubMed

    Wu, Xue-Cheng; Zhao, Hua-Feng; Zhang, Yong-Xin; Zheng, Cheng-Hang; Gao, Xiang

    2015-10-01

    China owns the world's largest capacity of coal-fired power units. By the end of 2012, the capacity of installed national thermal power has been 819.68 million kilowatts. The latest standard requires that newly built power plants emit SO2 in no more than 100 mg/m(3) and the emission of old ones be lower than 200 mg/m(3) while in some key areas the emission should be controlled under 50 mg/m(3). So by the end of 2012, 90% of the active coal-fired units have been equipped with flue gas desulfurization devices. Among the desulfurization methods adopted, limestone-gypsum wet flue gas desulphurization accounts for 92%, causing the problem of fine droplets in the exhaust gas after defogger, which may even form "gypsum rain." At present, sampling methods are widely used at home and abroad, such as magnesium ion tracer method, modified magnesium ion tracer method and chemical analysis. In addition, some scholars use aerodynamic methods, such as ELPI, to measure the diameter distribution and concentration. The methods mentioned above all have their own demerits, such as the inability to on-line, continuous measurements and the need of prolonged measuring time. Thus, in this paper some potential optical on-line methods are presented, such as Fraunhofer diffraction pattern analysis and wavelength-multiplexed laser extinction. Also brought up are their measuring scope and merits. These methods have already been utilized to measure small liquid droplets and their demonstrations and evaluations are as well stated. Finally, a 3D imaging method based on digital holographic microscope is proposed for in-line measurement of size and concentration of slurry droplets. The feasibility of this method is demonstrated by preliminary experimental investigation.

  14. Cost analysis of a coal-fired power plant using the NPV method

    NASA Astrophysics Data System (ADS)

    Kumar, Ravinder; Sharma, Avdhesh Kr.; Tewari, P. C.

    2015-06-01

    The present study investigates the impact of various factors affecting coal-fired power plant economics of 210 MW subcritical unit situated in north India for electricity generation. In this paper, the cost data of various units of thermal power plant in terms of power output capacity have been fitted using power law with the help of the data collected from a literature search. To have a realistic estimate of primary components or equipment, it is necessary to include the latest cost of these components. The cost analysis of the plant was carried out on the basis of total capital investment, operating cost and revenue. The total capital investment includes the total direct plant cost and total indirect plant cost. Total direct plant cost involves the cost of equipment (i.e. boiler, steam turbine, condenser, generator and auxiliary equipment including condensate extraction pump, feed water pump, etc.) and other costs associated with piping, electrical, civil works, direct installation cost, auxiliary services, instrumentation and controls, and site preparation. The total indirect plant cost includes the cost of engineering and set-up. The net present value method was adopted for the present study. The work presented in this paper is an endeavour to study the influence of some of the important parameters on the lifetime costs of a coal-fired power plant. For this purpose, parametric study with and without escalation rates for a period of 35 years plant life was evaluated. The results predicted that plant life, interest rate and the escalation rate were observed to be very sensitive on plant economics in comparison to other factors under study.

  15. The Net Climate Impact of Coal-Fired Power Plant Emissions

    NASA Technical Reports Server (NTRS)

    Shindell, D.; Faluvegi, G.

    2010-01-01

    Coal-fired power plants influence climate via both the emission of long-lived carbon dioxide (CO2) and short-lived ozone and aerosol precursors. Using a climate model, we perform the first study of the spatial and temporal pattern of radiative forcing specifically for coal plant emissions. Without substantial pollution controls, we find that near-term net global mean climate forcing is negative due to the well-known aerosol masking of the effects of CO2. Imposition of pollution controls on sulfur dioxide and nitrogen oxides leads to a rapid realization of the full positive forcing from CO2, however. Long-term global mean forcing from stable (constant) emissions is positive regardless of pollution controls. Emissions from coal-fired power plants until 1970, including roughly 1/3 of total anthropogenic CO2 emissions, likely contributed little net global mean climate forcing during that period though they may have induce weak Northern Hemisphere mid-latitude (NHml) cooling. After that time many areas imposed pollution controls or switched to low sulfur coal. Hence forcing due to emissions from 1970 to 2000 and CO2 emitted previously was strongly positive and contributed to rapid global and especially NHml warming. Most recently, new construction in China and India has increased rapidly with minimal application of pollution controls. Continuation of this trend would add negative near-term global mean climate forcing but severely degrade air quality. Conversely, following the Western and Japanese pattern of imposing air quality pollution controls at a later time could accelerate future warming rates, especially at NHmls. More broadly, our results indicate that due to spatial and temporal inhomogeneities in forcing, climate impacts of multi-pollutant emissions can vary strongly from region to region and can include substantial effects on maximum rate-of-change, neither of which are captured by commonly used global metrics. The method we introduce here to estimate

  16. Economic analysis of atmospheric mercury emission control for coal-fired power plants in China.

    PubMed

    Ancora, Maria Pia; Zhang, Lei; Wang, Shuxiao; Schreifels, Jeremy; Hao, Jiming

    2015-07-01

    Coal combustion and mercury pollution are closely linked, and this relationship is particularly relevant in China, the world's largest coal consumer. This paper begins with a summary of recent China-specific studies on mercury removal by air pollution control technologies and then provides an economic analysis of mercury abatement from these emission control technologies at coal-fired power plants in China. This includes a cost-effectiveness analysis at the enterprise and sector level in China using 2010 as a baseline and projecting out to 2020 and 2030. Of the control technologies evaluated, the most cost-effective is a fabric filter installed upstream of the wet flue gas desulfurization system (FF+WFGD). Halogen injection (HI) is also a cost-effective mercury-specific control strategy, although it has not yet reached commercial maturity. The sector-level analysis shows that 193 tons of mercury was removed in 2010 in China's coal-fired power sector, with annualized mercury emission control costs of 2.7 billion Chinese Yuan. Under a projected 2030 Emission Control (EC) scenario with stringent mercury limits compared to Business As Usual (BAU) scenario, the increase of selective catalytic reduction systems (SCR) and the use of HI could contribute to 39 tons of mercury removal at a cost of 3.8 billion CNY. The economic analysis presented in this paper offers insights on air pollution control technologies and practices for enhancing atmospheric mercury control that can aid decision-making in policy design and private-sector investments.

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

    SciTech Connect

    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

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

    SciTech Connect

    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

  19. Selecting the process arrangement for preparing the gas turbine working fluid for an integrated gasification combined-cycle power plant

    NASA Astrophysics Data System (ADS)

    Ryzhkov, A. F.; Gordeev, S. I.; Bogatova, T. F.

    2015-11-01

    Introduction of a combined-cycle technology based on fuel gasification integrated in the process cycle (commonly known as integrated gasification combined cycle technology) is among avenues of development activities aimed at achieving more efficient operation of coal-fired power units at thermal power plants. The introduction of this technology is presently facing the following difficulties: IGCC installations are characterized by high capital intensity, low energy efficiency, and insufficient reliability and availability indicators. It was revealed from an analysis of literature sources that these drawbacks are typical for the gas turbine working fluid preparation system, the main component of which is a gasification plant. Different methods for improving the gasification plant chemical efficiency were compared, including blast air high-temperature heating, use of industrial oxygen, and a combination of these two methods implying limited use of oxygen and moderate heating of blast air. Calculated investigations aimed at estimating the influence of methods for achieving more efficient air gasification are carried out taking as an example the gasifier produced by the Mitsubishi Heavy Industries (MHI) with a thermal capacity of 500 MW. The investigation procedure was verified against the known experimental data. Modes have been determined in which the use of high-temperature heating of blast air for gasification and cycle air upstream of the gas turbine combustion chamber makes it possible to increase the working fluid preparation system efficiency to a level exceeding the efficiency of the oxygen process performed according to the Shell technology. For the gasification plant's configuration and the GTU working fluid preparation system be selected on a well-grounded basis, this work should be supplemented with technical-economic calculations.

  20. 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

    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.

  1. Coal-fired high performance power generating system. Draft quarterly progress report, January 1--March 31, 1995

    SciTech Connect

    1995-10-01

    This report covers work carried out under Task 3, Preliminary R and D, under contract DE-AC22-92PC91155, ``Engineering Development of a Coal-Fired High Performance Power Generation System`` between DOE Pittsburgh Energy Technology Center and United Technologies Research Center. 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 {le} 25% NSPS; cost {ge}65% of heat input; all solid wastes benign. A crucial aspect of the authors design is the integration of the gas turbine requirements with the HITAF output and steam cycle requirements. In order to take full advantage of modern highly efficient aeroderivative gas turbines they have carried out a large number of cycle calculations to optimize their commercial plant designs for both greenfield and repowering applications.

  2. MHD coal-fired flow facility baseline water-quality study. Woods Reservoir, May 1979-April 1980

    SciTech Connect

    Cooper, J.

    1980-12-01

    The Department of Energy (DOE) Magnetohydrodynamics (MHD) Coal-Fired Flow Facility (CFFF) is located on Woods Reservoir at The University of Tennessee Space Institute (UTSI). Part of the role of UTSI, as participants in the DOE program, is to document environmental aspects of coal-fired MHD. In early 1979, prior to operation of the CFFF, a water quality program was initiated to establish baseline conditions for the reservoir. The study was designed to provide an accurate assessment of water quality which could be used as a basis for comparison to evaluate the impact, if any, of the plant operation on the aquatic environment. Results of a one year baseline study of water quality on Woods Reservoir are presented in this report. The key findings are that this reservoir is a eutrophic lake. Its predominant ions are calcium and bicarbonate and its pH is circumneutral.

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

    SciTech Connect

    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.

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

    SciTech Connect

    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

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

    SciTech Connect

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

    2009-06-30

    This report summarizes Year 1 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. Through the course of Year 1 activities, great progress was made toward understanding the issues associated with oxy-combustion retrofit of coal-fired boilers. All four Year 1 milestones and objectives have been, or will be, completed on schedule and within budget. Progress in the four milestone areas may be summarized as follows: • University of Utah has performed size segregated ash composition measurements in the Oxy-Fuel Combustor (OFC). These experiments indicate that oxy-combustion retrofit may impact ash aerosol mineral matter composition. Both flame temperature and flue gas composition have been observed to influence the concentration of calcium, magnesium and iron in the fine particulate. This could in turn impact boiler fouling and slagging. • Sandia National Labs has shown that char oxidation rate is dependent on particle size (for sizes between 60 and 100 microns) by performing fundamental simulations of reacting char particles. These predictions will be verified by making time-resolved optical measurements of char particle temperature, velocity and size in bench-scale experiments before the end of Year 1. • REI and Siemens have completed the design of an oxy-research burner that will be mounted on University of Utah’s pilot-scale furnace, the L1500. This burner will accommodate a wide range of O2, FGR and mixing strategies under conditions relevant for utility boiler operation. Through CFD modeling of the different burner designs, it was determined that the key factor influencing flame stabilization location is particle heat-up rate. The new oxy-research burner and associated equipment is scheduled for delivery before the end of Year 1. • REI has completed a literature survey of slagging and

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

    SciTech Connect

    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

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

    SciTech Connect

    Richard E. Johnson

    2004-07-30

    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 particle control device along with the other solid material, primarily fly ash. WE Energies has over 3,700 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} (TOXECON) system designed to clean the combined flue gases of units 7, 8, and 9 at the Presque Isle Power Plant. TOXECON is a patented process in which a fabric filter system (baghouse) installed down stream 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

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

    SciTech Connect

    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

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

    SciTech Connect

    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

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

    SciTech Connect

    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

  11. Escaping radioactivity from coal-fired power plants (CPPs) due to coal burning and the associated hazards: a review.

    PubMed

    Papastefanou, Constantin

    2010-03-01

    Coal, like most materials found in nature, contains trace quantities of the naturally occurring primordial radionuclides, i.e. of (40)K and of (238)U, (232)Th and their decay products. Therefore, the combustion of coal results in the released into the environment of some natural radioactivity (1.48 TBq y(-1)), the major part of which (99%) escapes as very fine particles, while the rest in fly ash. The activity concentrations of natural radionuclides measured in coals originated from coal mines in Greece varied from 117 to 435 Bq kg(-1) for (238)U, from 44 to 255 Bq kg(-1) for (226)Ra, from 59 to 205 Bq kg(-1) for (210)Pb, from 9 to 41 Bq kg(-1) for (228)Ra ((232)Th) and from 59 to 227 Bq kg(-1) for (40)K. Fly ash escapes from the stacks of coal-fired power plants in a percentage of 3-1% of the total fly ash, in the better case. The natural radionuclide concentrations measured in fly ash produced and retained or escaped from coal-fired power plants in Greece varied from 263 to 950 Bq kg(-1) for (238)U, from 142 to 605 Bq kg(-1) for (226)Ra, from 133 to 428 Bq kg(-1) for (210)Pb, from 27 to 68 Bq kg(-1) for (228)Ra ((232)Th) and from 204 to 382 Bq kg(-1) for (40)K. About 5% of the total ash produced in the coal-fired power plants is used as substitute of cement in concrete for the construction of dwellings, and may affect indoor radiation doses from external irradiation and the inhalation of radon decay products (internal irradiation) is the most significant. The resulting normalized collective effective doses were 6 and 0.5man-Sv(GWa)(-1) for typical old and modern coal-fired power plants, respectively.

  12. Experimental results of the UTSI coal-fired MHD generator and investigations of various power take-off schemes

    NASA Astrophysics Data System (ADS)

    Galanga, F. L.; Lineberry, J. T.; Wu, Y. C. L.; Scott, M. H.; Baucum, W. E.; Clemons, R. W.

    1981-01-01

    Tests were conducted at the University of Tennessee Space Institute, Energy Conversion Division, in support of technology development of coal-fired MHD generator systems. The primary objectives of the test series were to evaluate the overall electrical performance of the 60 deg DCW generator with vitiation heated oxidizer, to study the thermal behavior of capped versus solid frame electrodes, and to investigate various power take-off schemes. Results from the above-mentioned areas of investigation are presented and discussed.

  13. Primary air pollutant emissions of coal-fired power plants in China: Current status and future prediction

    NASA Astrophysics Data System (ADS)

    Zhao, Yu; Wang, Shuxiao; Duan, Lei; Lei, Yu; Cao, Pengfei; Hao, Jiming

    To explore the atmospheric emissions of coal-fired power sector in China, a unit-based method was developed based on detailed information of unit type, fuel quality, emission control technology, and geographical location. During 2000-2005, the period when power sector developed fastest in the past 20 years, SO 2, NO x and PM emissions of coal-fired power plants increased by 1.5, 1.7 and 1.2 times, respectively. The SO 2, emission of coal-fired power sector was estimated to be 16 097 kt in 2005, and would decrease to 11 801 kt in 2010, attributed mainly to the wide application of the flue gas desulfurization (FGD) technology. The NO x emission, however, would increase from 6965 kt in 2005 to 9680 kt in 2010, since few NO x control measures would be taken during the five years. The TSP, PM 10, and PM 2.5 emissions in 2005 were estimated to be 2774, 1842 and 994 kt, and the values would be 2540, 1824 and 1090 kt in 2010 respectively. The wet FGD would play an important role on dust emission removal. Through faithful implementation of closing small units and emission control policies in the acid rain and sulfur dioxide control zones, approximately 33%, 6% and 25% of SO 2, NO x, and TSP emissions respectively could be further reduced in 2010. Emissions in 2015 and 2020 of coal-fired power plants were predicted applying scenario analysis. For SO 2 and TSP, optimistic situation can be achieved through reasonable control policies; in contrast, NO x would probably be a more serious issue in future.

  14. The high moisture western coal processing system at the UTSI-DOE Coal Fired Flow Facility. Topical report

    SciTech Connect

    Sanders, M.E.

    1996-02-01

    The original eastern coal processing system at the Department of Energy`s Coal Fired Flow Facility (CFFF), located at the University of Tennessee Space Institute in Tullahoma, Tennessee, was modified to pulverize and dry Montana Rosebud, a western coal. Significant modifications to the CFFF coal processing system were required and the equipment selection criteria are reviewed. Coal processing system performance parameters are discussed. A summary of tests conducted and significant events are included.

  15. The fate and behavior of mercury in coal-fired power plants.

    PubMed

    Meij, Ruud; Vredenbregt, Leo H J; te Winkel, Henk

    2002-08-01

    For the past 22 years in the Netherlands, the behavior of Hg in coal-fired power plants has been studied extensively. Coal from all over the world is fired in Dutch power stations. First, the Hg concentrations in these coals were measured. Second, the fate of the Hg during combustion was established by performing mass balance studies. On average, 43 +/- 30% of the Hg was present in the flue gases downstream of the electrostatic precipitator (ESP; dust collector). In individual cases, this figure can vary between 1 and 100%. Important parameters are the Cl content of the fuel and the flue gas temperature in the ESP. On average, 54 +/- 24% of the gaseous Hg was removed in the wet flue-gas desulfurization (FGD) systems, which are present at all Dutch coal-power stations. In individual cases, this removal can vary between 8% (outlier) and 72%. On average, the fate of Hg entering the power station in the coal was as follows: <1% in the bottom ash, 49% in the pulverized fuel ash (ash collected in the ESP), 16.6% in the FGD gypsum, 9% in the sludge of the wastewater treatment plant, 0.04% in the effluent of the wastewater treatment plant, 0.07% in fly dust (leaving the stack), and 25% as gaseous Hg in the flue gases and emitted into the air. The distribution of Hg over the streams leaving the FGD depends strongly on the installation. On average, 75% of the Hg was removed, and the final concentration of Hg in the emitted flue gases of the Dutch power stations was only -3 microg/m3(STP) at 6% O2. During co-combustion with biomass, the removal of Hg was similar to that during 100% coal firing. Speciation of Hg is a very important factor. An oxidized form (HgCl2) favors a high degree of removal. The conversion from Hg0 to HgCl2 is positively correlated with the Cl content of the fuel. A catalytic DENOX (SCR) favors the formation of oxidized Hg, and, in combination with a wet FGD, the total removal can be as high as 90%.

  16. Mercury emissions from a coal-fired power plant in Japan

    PubMed

    Yokoyama; Asakura; Matsuda; Ito; Noda

    2000-10-02

    The emissions study for mercury was conducted at a 700 MW coal-fired plant for the combustion of three types of coal with mercury concentrations of 0.0063, 0.0367 and 0.065 mg/kg. The power plant is equipped with a cold-side electrostatic precipitator and wet type flue gas desulfurization system. During full load operation of the boilers, samples of the input and output streams such as coal, coal ash, ESP ash and post-ESP particulates and flue gas were collected. The Hg concentrations in solid were measured by cold-vapor atomic absorption spectrometry (AAS) after appropriate preparation and acid digestion. Gaseous Hg was collected using a mixed solution of potassium permanganate and sulfuric acid and the Hg concentrations in the samples were measured using cold-vapor AAS. The results were used to examine: (1) overall mass balances; (2) relative distribution in the power plant; (3) equilibrium of Hg species using MALT-2 calculation program; and (4) Hg concentrations in stack emissions. The mass balances estimated in this study were 100, 138 and 89%, respectively, for the coals. Total Hg concentrations in stack gas were 1.113, 0.422 and 0.712 microg(m3N), respectively, for the coals. More than 99.5% of the Hg in the stack emissions were in gaseous form and the proportion in particulate form was extremely low. The relative distribution of Hg in ESP, FGD and Stack ranged from 8.3 to 55.2%, 13.3 to 69.2% and 12.2% to 44.4%, respectively. The results indicated that factors other than the Hg concentration of coals and efficiency of pollution control devices might affect Hg emissions from coal-fired plant. The calculated equilibrium of the distribution of Hg species using the MALT2 program suggest that it is necessary to consider condensation mechanism to interpret the affect of Hg species on the variations of the removal efficiencies of Hg in the ESP.

  17. Isotopic Variations of Mercury Emitted by Coal Fired Power Plant Gases

    NASA Astrophysics Data System (ADS)

    Khawaja, S. N.; Odom, L.; Landing, W.

    2010-12-01

    Emission of mercury from the burning of coal is considered one of the important anthropogenic sources of atmospheric mercury. Along with current measurements of the isotopic composition of atmospheric mercury being conducted in our laboratory, we have analyzed mercury emitted from a coal fired power plant. Previously Biswas and others (2008) had reported variations in the isotopic composition of mercury in a number of samples of coal deposits. Since the combustion of coal is expected to release virtually all of its mercury, we anticipated comparable isotopc patterns in coal and total emmited mercury. The emitted mercury exists in various physical and chemical forms, each possessing distinct properties that affect atmospheric transport, and sampling methods. Flue gas has been sampled in the stack of a coal fired electric power plant. The Ontario Hydro method was used to trap mercury in flue gases. The method uses oxidant solutions (KCl, H2O2-HNO3 and KMnO4-H2SO4) in its sampling train. This method is the modification of EPA method 29 with the use of KCl in the sampling train. Hg (II) is captured in the KCl impingers, while Hg (0) is captured in H2O2-HNO3 and KMnO4-H2SO4 impingers that oxidize elemental to Hg (ll) (EPA Draft, 1999). In addition gaseous reactive mercury was sampled downwind in large volume rain samples. Mercury (Hg+2) in sample solutions was reduced with SnCl2, and the generated Hg(0) vapor carried by Ar gas into the source of a NEPTUNE ICPMS-MC. Isotope ratios were measured by standard-sample bracketing and reported as permil deviations from the SRM NIST-3133 values. The measurement shows a small range of values of odd isotopes for mass independent fractionation which is negligible, However it displays the wide range of mass dependent fractionation (δ198 Hg -1.239 to 2.294). We found that samples in KCl impingers are light isotope enriched and depleted in heavy isotopes, while in KMnO4 impingers these are reverse.

  18. Combining support vector regression and ant colony optimization to reduce NOx emissions in coal-fired utility boilers

    SciTech Connect

    Ligang Zheng; Hao Zhou; Chunlin Wang; Kefa Cen

    2008-03-15

    Combustion optimization has recently demonstrated its potential to reduce NOx emissions in high capacity coal-fired utility boilers. In the present study, support vector regression (SVR), as well as artificial neural networks (ANN), was proposed to model the relationship between NOx emissions and operating parameters of a 300 MW coal-fired utility boiler. The predicted NOx emissions from the SVR model, by comparing with that of the ANN-based model, showed better agreement with the values obtained in the experimental tests on this boiler operated at different loads and various other operating parameters. The mean modeling error and the correlation factor were 1.58% and 0.94, respectively. Then, the combination of the SVR model with ant colony optimization (ACO) to reduce NOx emissions was presented in detail. The experimental results showed that the proposed approach can effectively reduce NOx emissions from the coal-fired utility boiler by about 18.69% (65 ppm). A time period of less than 6 min was required for NOx emissions modeling, and 2 min was required for a run of optimization under a PC system. The computing times are suitable for the online application of the proposed method to actual power plants. 37 refs., 8 figs., 3 tabs.

  19. Coal-fired MHD combustor development project: Phase IIIB. First quarterly technical progress report, 13 January-30 April 1982

    SciTech Connect

    1982-05-20

    The first quarterly technical progress report of the Coal-Fired MHD Combustor Development Project (Phase IIIB) presents the accomplishments during the period 13 January to 30 April, 1982. The scope of work covered by this quarterly report relates to those tasks associated with preparing the TRW 20 MW/sub t/ MHD coal combustor for delivery to AERL for integrated power tests and the work associated with the preliminary design of a 50 MW/sub t/ coal-fired combustor. Progress during this reporting period is described. All new 20 MW/sub t/ hardware was designed and fabricated. Interface coordination meetings were conducted with AERL and DOE. Interface control drawings were completed and a 20 MW/sub t/ coal combustion User's manual was delivered to AERL. The User's manual contained a shipping plan, a crew training plan, an assembly manual, interface documentation and recommended operating procedures. Facility/combustor set-up was completed and the pre-delivery 20 MW/sub t/ coal combustor qualification test series was completed. The 50 MW/sub t/ coal-fired MHD combustor preliminary designs were finalized and the DOE preliminary design review (PDR) was successfully completed.

  20. A new method to assess mercury emissions: a study of three coal-fired electric-generating power station configurations.

    PubMed

    Boylan, Helen M; Cain, Randy D; Kingston, H M

    2003-11-01

    U.S. Environmental Protection Agency (EPA) Method 7473 for the analysis of mercury (Hg) by thermal decomposition, amalgamation, and atomic absorption spectroscopy has proved successful for use in Hg assessment at coal-fired power stations. In an analysis time of approximately 5 min per sample, this instrumental methodology can directly analyze total Hg--with no discrete sample preparation--in the solid matrices associated with a coal-fired power plant, including coal, fly ash, bottom ash, and flue gas desulfurization (FGD) material. This analysis technique was used to investigate Hg capture by coal combustion byproducts (CCBs) in three different coal-fired power plant configurations. Hg capture and associated emissions were estimated by partial mass balance. The station equipped with an FGD system demonstrated 68% capture on FGD material and an emissions estimate of 18% (11 kg/yr) of total Hg input. The power plant equipped with low oxides of nitrogen burners and an electrostatic precipitator (ESP) retained 43% on the fly ash and emitted 57% (51 kg/yr). The station equipped with conventional burners and an ESP retained less than 1% on the fly ash, emitting an estimated 99% (88 kg/yr) of Hg. Estimated Hg emissions demonstrate good agreement with EPA data for the power stations investigated.

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

    SciTech Connect

    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.

  2. Opportunities for Decarbonizing Existing U.S. Coal-Fired Power Plants via CO2 Capture, Utilization and Storage.

    PubMed

    Zhai, Haibo; Ou, Yang; Rubin, Edward S

    2015-07-07

    This study employs a power plant modeling tool to explore the feasibility of reducing unit-level emission rates of CO2 by 30% by retrofitting carbon capture, utilization, and storage (CCUS) to existing U.S. coal-fired electric generating units (EGUs). Our goal is to identify feasible EGUs and their key attributes. The results indicate that for about 60 gigawatts of the existing coal-fired capacity, the implementation of partial CO2 capture appears feasible, though its cost is highly dependent on the unit characteristics and fuel prices. Auxiliary gas-fired boilers can be employed to power a carbon capture process without significant increases in the cost of electricity generation. A complementary CO2 emission trading program can provide additional economic incentives for the deployment of CCS with 90% CO2 capture. Selling and utilizing the captured CO2 product for enhanced oil recovery can further accelerate CCUS deployment and also help reinforce a CO2 emission trading market. These efforts would allow existing coal-fired EGUs to continue to provide a significant share of the U.S. electricity demand.

  3. Low Leakage Turbine Shaft Seals for Advanced Combined Cycle Systems.

    DTIC Science & Technology

    1984-11-01

    S-. xdJ , , -Inpa .. L,, A. LA0b. J00O"il C.Sc’a~,,,r,1, TABLE OF CONTENTS Section Page *SYNOPSIS xi. ACKNOWLEDGEMENT xiii SUMMARY 1 1...54 4.8 Seal Bibliography 68 5 DISCUSSION OF RESULTS 69 6 DESIGN GUIDELINES 71 7 CONCLUSIONS 73 8 RECOMMENDATIONS 75 *’ TABLE OF CONTENTS (Continued...for Rotor Dynamic Balancing) 67 viii L LIST OF TABLES Table Page 1 Sample Computer Program Output for NASA-Solar Spiral-.;roove Face Seal 27 2 Sample

  4. Model Predictive Control of Integrated Gasification Combined Cycle Power Plants

    SciTech Connect

    B. Wayne Bequette; Priyadarshi Mahapatra

    2010-08-31

    The primary project objectives were to understand how the process design of an integrated gasification combined cycle (IGCC) power plant affects the dynamic operability and controllability of the process. Steady-state and dynamic simulation models were developed to predict the process behavior during typical transients that occur in plant operation. Advanced control strategies were developed to improve the ability of the process to follow changes in the power load demand, and to improve performance during transitions between power levels. Another objective of the proposed work was to educate graduate and undergraduate students in the application of process systems and control to coal technology. Educational materials were developed for use in engineering courses to further broaden this exposure to many students. ASPENTECH software was used to perform steady-state and dynamic simulations of an IGCC power plant. Linear systems analysis techniques were used to assess the steady-state and dynamic operability of the power plant under various plant operating conditions. Model predictive control (MPC) strategies were developed to improve the dynamic operation of the power plants. MATLAB and SIMULINK software were used for systems analysis and control system design, and the SIMULINK functionality in ASPEN DYNAMICS was used to test the control strategies on the simulated process. Project funds were used to support a Ph.D. student to receive education and training in coal technology and the application of modeling and simulation techniques.

  5. ASSESSMENT OF LOW COST NOVEL SORBENTS FOR COAL-FIRED POWER PLANT MERCURY CONTROL

    SciTech Connect

    Trevor Ley

    2004-01-01

    This is a Technical Report under a program funded by the Department of Energy's National Energy Technology Laboratory (NETL) to obtain the necessary information to assess the viability of lower cost alternatives to commercially available activated carbon for mercury control in coal-fired utilities. Novel sorbent evaluations at We Energies' Pleasant Prairie Power Plant (P4) Unit 1 (no SCR in place) have been completed. Nineteen sorbents were evaluated for mercury control. A batch injection rate of 1 lb/Mmacf for 1 hour was conducted for screening purposes at a temperature of 300 F. Four sorbents were further evaluated at three injection rates and two temperatures. The multi-pollutant control test system (PoCT) was installed on P4's Unit 2 (with an SCR) and sorbent evaluations are continuing. Evaluations will continue through the end of January 2004. Tests and analysis on samples from Powerton and Valley to yield waste characterization results for the COHPAC long-term tests are continuing. A no-cost time extension for work to be completed by March 31, 2004 was granted by DOE/NETL.

  6. Peak Oil and Coal Fires: How Scientific Fact Becomes Debatable Political Questions

    NASA Astrophysics Data System (ADS)

    McCurdy, K. M.

    2008-12-01

    Political consensus in the United States cannot be more different from a scientific consensus. The latter situation allows for resolution of problems large and small based on recognized facts and procedures. Once a compelling problem is recognized the scientific community is able to marshal resources to examine that phenomenon. Political consensus however allows for the unending reconsideration of problems in the political arena depending on the outcome of elections and the intensity and sustained length of citizen interest. Serious problems can be trivialized by election campaign rhetoric, or can fail to rise to the level of aggregation necessary to be considered. Coal fires are an example of the latter while OCS exploration and production is an example of the former. Peak oil is a problem that will be avoided until there is a crisis. With current scientific evidence mounting that an important tipping point is approaching, and that societal collapse is a probable outcome of maintaining the status quo, it is vitally important to understand the structural limitations of government decisions. Long standing consensus in the legislature is transferred to the bureaucracy, which can maintain a policy position long after its electoral support has vanished. A legislature and executive experiencing thin electoral margins (51-54% of the vote or seats) produces a different sort of political environment than what is possible with safe margins (>60%). Supermajorities with veto proof margins (>65%) are rare, but not unknown (e.g. 1935-37; 1965-67) and allow for revolutionary policy innovation.

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

    SciTech Connect

    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.

  8. Mercury capture by native fly ash carbons in coal-fired power plants.

    PubMed

    Hower, James C; Senior, Constance L; Suuberg, Eric M; Hurt, Robert H; Wilcox, Jennifer L; Olson, Edwin S

    2010-08-01

    The control of mercury in the air emissions from coal-fired power plants is an on-going challenge. The native unburned carbons in fly ash can capture varying amounts of Hg depending upon the temperature and composition of the flue gas at the air pollution control device, with Hg capture increasing with a decrease in temperature; the amount of carbon in the fly ash, with Hg capture increasing with an increase in carbon; and the form of the carbon and the consequent surface area of the carbon, with Hg capture increasing with an increase in surface area. The latter is influenced by the rank of the feed coal, with carbons derived from the combustion of low-rank coals having a greater surface area than carbons from bituminous- and anthracite-rank coals. The chemistry of the feed coal and the resulting composition of the flue gas enhances Hg capture by fly ash carbons. This is particularly evident in the correlation of feed coal Cl content to Hg oxidation to HgCl2, enhancing Hg capture. Acid gases, including HCl and H2SO4 and the combination of HCl and NO2, in the flue gas can enhance the oxidation of Hg. In this presentation, we discuss the transport of Hg through the boiler and pollution control systems, the mechanisms of Hg oxidation, and the parameters controlling Hg capture by coal-derived fly ash carbons.

  9. Multiplex CARS temperature measurements in a coal-fired MHD environment

    NASA Astrophysics Data System (ADS)

    Beiting, E. J.

    1986-01-01

    Multiplex CARS spectra of nitrogen were recorded in an environment that simulates the post-magnet gas stream of a coal-fired MHD generator. The presence of coal fly ash and potassium seed created a weakly ionized, highly luminous medium with a high number density of relatively large (1-50 microns) diameter particles. Maximum temperatures of 2500 K were measured with a spatial resolution of 5 mm. The precision optical alignment necessary for folded BOXCARS phasematching was maintained for the long distances (greater than 10 m) necessary to route the laser beams from the CARS instrument to the combustion facility. The increased luminosity caused by the injection of potassium seed did not impede the recovery of good quality spectra. The coal fly ash particles precipitated laser induced breakdown which, in turn, led to the generation of a coherent interference with N2 spectra. Techniques to overcome this problem are discussed. The accuracy of the temperature measurements are estimated to be + or - 3 percent.

  10. Infrared optical properties of a coal-fired power plant plume

    SciTech Connect

    Stearns, L.P.; Pueschel, R.F.

    1983-06-15

    Infrared measurements in the 8--14-..mu..m spectral region were made of two coal-fired power plant plumes and area haze in the Four Corners region of New Mexico from 1 to 7 Nov. 1980. The layer tranmittance, optical depth, and volume extinction coefficient derived from measurements on four nonconsecutive days show the effects of the plumes on the IR optical properties of the atmosphere. The average contribution of the plume alone to the IR extinction coefficient was 74% at the Four Corners plant; the background haze contributed 7--11%. More efficient particulate emission control at the San Juan power plant reduced the average contribution of its plume to 57% of the extinction coefficient. The haze contributed an average of 16%. The results show an increase with time of the haze bulk extinction coefficient during a persistent anticyclonic synoptic situation. Extinction coefficients of the haze showed a linearity with particulate loading, which led to estimates of IR volume extinctions of the free troposphre from aerosol measurements.

  11. Epidemiological monitoring in the vicinity of a coal-fired power plant.

    PubMed

    Toeplitz, R; Goren, A; Goldsmith, J R; Donagi, A

    1984-01-27

    An epidemiological monitoring program has been designed and put into operation in response to a health monitoring requirement of a permit to build a coal-fired power plant. It will consist of four 350 megawatt units and is being built on the Mediterranean coast about halfway between Tel-Aviv and Haifa; the first unit became operational in 1981. The resident population within a 10 km. radius consists of about 69,000 persons. The permit to build this power plant required the installation of a comprehensive monitoring network including environmental, health and agricultural monitoring. Four types of studies are included in the epidemiological monitoring program: mortality analyses, monitoring of requests for health services, studies of pulmonary symptoms and lung function in school children, and panel studies of children and adults with chronic pulmonary conditions. Areas of maximal expected exposure risk and two other comparable areas of lesser risk were chosen, based on expected emissions, meterological and topographical considerations; baseline data were gathered for a year prior to the operation of the first unit of the power plant. Subsequent data are planned to be collected for another 10 years. The program permits detection of short-term effects based on increases in health service requests, medium-term effects by repeat examination of panelists, and long-term effects based on pulmonary conditions among school children. The initial survey, before plant operations showed, among other things, lower flow rates for children in the area expected to have medium levels of exposure.

  12. Development and testing of a commercial-scale coal-fired combustion system, Phase 3

    SciTech Connect

    Litka, A.F.; Breault, R.W.

    1991-10-01

    Within the commercial sector, oil and natural gas are the predominant fuels used to meet the space-heating needs of schools, office buildings, apartment complexes, and other similar structures. In general, these buildings require firing rates of 1 to 10 million Btu/hr. The objective of this program is to demonstrate the technical and economic viability of a coal-fired combustion system for this sector. The commercial-scale coal-water slurry (CWS)-fired space heating system will be a scale-up of a CWS-fired residential warm-air heating system developed by Tecogen under contract to the Department of Energy, Pittsburgh Energy Technology Center. This system included a patented nonslagging combustor known as IRIS, for Inertial Reactor with Internal Separation. This combustion technology, which has demonstrated high combustion efficiency using CWS fuels at input rates of 100,000 Btu/hr, will be scaled to operate at 2 to 5 millon Btu/hr. Along with the necessary fuel storage and delivery, heat recovery, and control equipment, the system will include pollution control devices to meet targeted values of NO{sub x}, S0{sub 2}, and particulate emissions. In general, the system will be designed to match the reliability, safety, turndown, and ignition performance of gas or oil-fired systems.

  13. [Experimental study on emission characteristics of PM10 in coal-fired boilers].

    PubMed

    Guo, Xin; Chen, Dan; Zheng, Chu-Guang; Sui, Jian-Cai; Xu, Ming-Hou

    2008-03-01

    Fly ash was sampled at the inlet and outlet of ash collectors in four different coal-fired utility boilers using 13-stage low pressure impactor (LPI). The mass distribution, emission characteristics and the composition at different size particle of PM10 were studied. The results show that PM10 of the four boilers have a similar himodal distribution, with two peaks formed around 0.1 microm and 2.36 - 3.95 microm, respectively. The lowest efficiency of ash collectors was between 50% - 65% when the particle sizes were around 0.1 - 1 microm, no matter Venturi water membrane dust collector or ESP was used. Ash collectors show different removal efficiencies to various particle sizes PM. The removal efficiency of ash collectors was about 96% around 10 microm, while under 1 microm it was between 62% - 83%. The chemical composition of the size-segregated ash showed that the element S and Na were obvious enrichment in finer ash, which is possibly formed via vaporization and subsequent condensation of inorganic matter. While the refractory oxides were the major composition in bigger size ash, which may be formed via char fragmentation, excluded mineral fragmentation and included mineral coalescence.

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

    DOE PAGES

    Liu, Manzhi; Shen, Bo; Han, Yafeng; ...

    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

  15. Mercury Emission Ratios from Coal-Fired Power Plants in the Southeastern United States during NOMADSS.

    PubMed

    Ambrose, Jesse L; Gratz, Lynne E; Jaffe, Daniel A; Campos, Teresa; Flocke, Frank M; Knapp, David J; Stechman, Daniel M; Stell, Meghan; Weinheimer, Andrew J; Cantrell, Christopher A; Mauldin, Roy L

    2015-09-01

    We use measurements made onboard the National Science Foundation's C-130 research aircraft during the 2013 Nitrogen, Oxidants, Mercury, and Aerosol Distributions, Sources, and Sinks (NOMADSS) experiment to examine total Hg (THg) emission ratios (EmRs) for six coal-fired power plants (CFPPs) in the southeastern U.S. We compare observed enhancement ratios (ERs) with EmRs calculated using Hg emissions data from two inventories: the National Emissions Inventory (NEI) and the Toxics Release Inventory (TRI). For four CFPPs, our measured ERs are strongly correlated with EmRs based on the 2011 NEI (r(2) = 0.97), although the inventory data exhibit a -39% low bias. Our measurements agree best (to within ±32%) with the NEI Hg data when the latter were derived from on-site emissions measurements. Conversely, the NEI underestimates by approximately 1 order of magnitude the ERs we measured for one previously untested CFPP. Measured ERs are uncorrelated with values based on the 2013 TRI, which also tends to be biased low. Our results suggest that the Hg inventories can be improved by targeting CFPPs for which the NEI- and TRI-based EmRs have significant disagreements. We recommend that future versions of the Hg inventories should provide greater traceability and uncertainty estimates.

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

    SciTech Connect

    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.

  17. Characterizing mercury emissions from a coal-fired power plant utilizing a venturi wet FGD system

    SciTech Connect

    Vann Bush, P.; Dismukes, E.B.; Fowler, W.K.

    1995-11-01

    Southern Research Institute (SRI) conducted a test program at a coal-fired utility plant from October 24 to October 29, 1994. The test schedule was chosen to permit us to collect samples during a period of consecutive days with a constant coal source. SRI collected the samples required to measured concentrations of anions and trace elements around two scrubber modules and in the stack. Anions of interest were CI{sup -}, F{sup -}, and SO{sub 4}{sup =}. We analyzed samples for five major elements (Al, Ca, Fe, Mg, and Ti) and 16 trace elements (As, B, Ba, Be, Cd, Co, Cr, Cu, Hg, Mn, Mo, Ni, Pb, Sb, Se, and V). SRI made measurements across two scrubber modules, each treating nominally 20% of the total effluent from the boiler. Across one module we examined the effects of changes in the liquid-to-gas ratio (L/G) on the efficiency with which the scrubber removes trace elements and anions from the flue gas. Across another module we examined the effects of slurry pH on the removal of trace elements and anions from the flue gas. Measurements in the stack quantified emissions rates of anions and trace elements.

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

    SciTech Connect

    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.

  19. [Comprehensive fuzzy evaluation of nitrogen oxide control technologies for coal-fired power plants].

    PubMed

    Yu, Chao; Wang, Shu-xiao; Hao, Ji-ming

    2010-07-01

    A multi-level assessment index system was established to quantitatively and comprehensively evaluate the performance of typical nitrogen oxide control technologies for coal-fired power plants. Comprehensive fuzzy evaluation was conducted to assess six NO, control technologies, including low NO, burner (LNB), over the fire (OFA), flue gas reburning (Reburning), selective catalyst reduction (SCR), selective non-catalyst reduction (SNCR) and hybrid SCR/SNCR. Case studies indicated that combination of SCR and LNB are the optimal choice for wall-fired boilers combusting anthracite coal which requires NO, removal efficiency to be over 70%, however, for W-flame or tangential boilers combusting bituminous and sub-bituminous coal which requires 30% NO, removal, LNB and reburning are better choices. Therefore, we recommend that in the developed and ecological frangible regions, large units burning anthracite or meager coal should install LNB and SCR and other units should install LNB and SNCR. In the regions with environmental capacity, units burning anthracite or meager coal shall install LNB and SNCR, and other units shall apply LNB to reduce NO, emissions.

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

    SciTech Connect

    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.

  1. Development and testing of a commercial-scale coal-fired combustion system, Phase 3

    SciTech Connect

    Litka, A.F.; Breault, R.W.

    1991-07-01

    Within the commercial sector, oil and natural gas are the predominant fuels used to meet the space-heating needs of schools, office buildings, apartment complexes, and other similar structures. In general, these buildings require firing rates of 1 to 10 million Btu/hr. The objective of this program is to demonstrate the technical and economic viability of a coal-fired combustion system for this sector. The commercial-scale coal-water slurry (CWS)-fired space heating system will be a scale-up of a CWS-fired residential warm-air heating system developed by Tecogen under contract to the Department of Energy, Pittsburgh Energy Technology Center. This system included a patented nonslagging combustor known as IRIS, for Inertial Reactor with Internal Separation. This combustion technology, which has demonstrated high combustion efficiency using CWS fuels at input rates of 100,000 Btu/hr, will be scaled to operate at 2 to 5 millon Btu/hr. Along with the necessary fuel storage and delivery, heat recovery, and control equipment, the system will include pollution control devices to meet targeted values of NO{sub x}, S0{sub 2}, and particulate emissions. In general, the system will be designed to match the reliability, safety, turndown, and ignition performance of gas or oil-fired systems.

  2. Characterization of Fly Ash from Coal-Fired Power Plant and Their Properties of Mercury Retention

    NASA Astrophysics Data System (ADS)

    He, Ping; Jiang, Xiumin; Wu, Jiang; Pan, Weiguo; Ren, Jianxing

    2015-12-01

    Recent research has shown that fly ash may catalyze the oxidation of elemental mercury and facilitate its removal. However, the nature of mercury-fly ash interaction is still unknown, and the mechanism of mercury retention in fly ash needs to be investigated more thoroughly. In this work, a fly ash from a coal-fired power plant is used to characterize the inorganic and organic constituents and then evaluate its mercury retention capacities. The as-received fly ash sample is mechanically sieved to obtain five size fractions. Their characteristics are examined by loss on ignition (LOI), scanning electron microscope (SEM), energy dispersive X-ray detector (EDX), X-ray diffraction (XRD), and Raman spectra. The results show that the unburned carbon (UBC) content and UBC structural ordering decrease with a decreasing particle size for the five ashes. The morphologies of different size fractions of as-received fly ash change from the glass microspheres to irregular shapes as the particle size increases, but there is no correlation between particle size and mineralogical compositions in each size fraction. The adsorption experimental studies show that the mercury-retention capacity of fly ash depends on the particle size, UBC, and the type of inorganic constituents. Mercury retention of the types of sp2 carbon is similar to that of sp3 carbon.

  3. Removal characteristics of sulfuric acid aerosols from coal-fired power plants.

    PubMed

    Pan, Danping; Yang, Linjun; Wu, Hao; Huang, Rongting

    2017-03-01

    With increasing attention on sulfuric acid emission, investigations on the removal characteristics of sulfuric acid aerosols by the limestone gypsum wet flue gas desulfurization (WFGD) system and the wet electrostatic precipitator (WESP) were carried out in two coal-fired power plants, and the effects of the WFGD scrubber type and the flue gas characteristics were discussed. The results showed that it was necessary to install the WESP device after desulfurization, as the WFGD system was inefficient to remove sulfuric acid aerosols from the flue gas. The removal efficiency of sulfuric acid aerosols in the WFGD system with double scrubbers ranged from 50% to 65%, which was higher than that with a single scrubber, ranging from 30% to 40%. Furthermore, the removal efficiency of WESP on the sulfuric acid aerosols was from 47.9% to 52.4%. With increased concentrations of SO3 and particles in the flue gas, the removal efficiencies of the WFGD and the WESP on the sulfuric acid aerosols were increased.

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

    SciTech Connect

    Rubin, E.S.

    1989-04-01

    This is the sixth quarterly report of DOE Contract No. DE-AC22- 87PC79863, entitled Modeling of Integrated Environmental Control Systems for Coal-Fired Power Plants.'' This report summarizes accomplishments during the period January 1, 1989 to March 31, 1989. Efforts this past quarter focused primarily on the preparation of a computer User's Guide for the Integrated Environmental Control Model (IECM). Drafts of the first two chapters are now complete. These chapters constitute the bulk of this quarterly report. Drafts of the remaining chapters are in preparation, and will appear in a future report this year. We also have been working closely with DOE/PETC to define the computer configuration to be transferred to PETC as a contract deliverable. That process is now complete and the equipment is on order. Delivery of the IECM to PETC is expected during the next calendar quarter. Finally, we are continuing our efforts to develop and refine a number of clean coal technology process models. These efforts will be summarized and reported at a future date.

  5. Mercury capture by native fly ash carbons in coal-fired power plants

    PubMed Central

    Hower, James C.; Senior, Constance L.; Suuberg, Eric M.; Hurt, Robert H.; Wilcox, Jennifer L.; Olson, Edwin S.

    2013-01-01

    The control of mercury in the air emissions from coal-fired power plants is an on-going challenge. The native unburned carbons in fly ash can capture varying amounts of Hg depending upon the temperature and composition of the flue gas at the air pollution control device, with Hg capture increasing with a decrease in temperature; the amount of carbon in the fly ash, with Hg capture increasing with an increase in carbon; and the form of the carbon and the consequent surface area of the carbon, with Hg capture increasing with an increase in surface area. The latter is influenced by the rank of the feed coal, with carbons derived from the combustion of low-rank coals having a greater surface area than carbons from bituminous- and anthracite-rank coals. The chemistry of the feed coal and the resulting composition of the flue gas enhances Hg capture by fly ash carbons. This is particularly evident in the correlation of feed coal Cl content to Hg oxidation to HgCl2, enhancing Hg capture. Acid gases, including HCl and H2SO4 and the combination of HCl and NO2, in the flue gas can enhance the oxidation of Hg. In this presentation, we discuss the transport of Hg through the boiler and pollution control systems, the mechanisms of Hg oxidation, and the parameters controlling Hg capture by coal-derived fly ash carbons. PMID:24223466

  6. Fayalite from Fe-rich paralavas of ancient coal fires in the Kuzbass, Russia

    NASA Astrophysics Data System (ADS)

    Novikova, S. A.

    2009-12-01

    Fayalite is a common mineral of Fe-rich paralavas related to spontaneous combustion of coal seams. Fayalite has also been found in parabasalts from burned coal waste piles of the Chelyabinsk coal basin. Among paralavas from different combustion metamorphic (CM) complexes of the world, fayalite is the most widespread in the fused rocks of the Kuznetsk coal basin (Kuzbass) and the Ravat area in Tajikistan. The optimal conditions for fayalite formation as products of coal fires in the Kuzbass and Ravat resulted from a favorable combination of the composition of fused protolith (parental rocks) composed of pelitic and Fe-rich sediments and the redox conditions of the deep subsurface ( f_{O_2 } is lower than the QFM buffer). In the Kuzbass, fayalite is commonly hosted in high-silica aluminous Fe-rich paralavas composed of Fe-cordierite (sekaninaite), tridymite, hercynite-magnetite, cristobalite, aluminous clinoferrosilite, and Al-K silicic glass. The composition of all Kuzbass fayalites is close to the Fe2SiO4 end member. Kuzbass fayalites are characterized by a negligibly low CaO content and higher MnO and P2O5 contents like fayalites from burned rocks of other CM complexes. In Kuzbass paralavas, Fe-olivine is the late phase that crystallized after sekaninaite and tridymite, immediately before melt quenching.

  7. A pilot study of mercury liberation and capture from coal-fired power plant fly ash.

    PubMed

    Li, Jin; Gao, Xiaobing; Goeckner, Bryna; Kollakowsky, Dave; Ramme, Bruce

    2005-03-01

    The coal-fired electric utility generation industry has been identified as the largest anthropogenic source of mercury (Hg) emissions in the United States. One of the promising techniques for Hg removal from flue gas is activated carbon injection (ACI). The aim of this project was to liberate Hg bound to fly ash and activated carbon after ACI and provide high-quality coal combustion products for use in construction materials. Both bench- and pilot-scale tests were conducted to liberate Hg using a thermal desorption process. The results indicated that up to 90% of the Hg could be liberated from the fly ash or fly-ash-and-activated-carbon mixture using a pilot-scale apparatus (air slide) at 538 degrees C with a very short retention time (less than 1 min). Scanning electron microscope (SEM) evaluation indicated no significant change in fly ash carbon particle morphology following the thermal treatment. Fly ash particles collected in the baghouse of the pilot-scale apparatus were smaller in size than those collected at the exit of the air slide. A similar trend was observed in carbon particles separated from the fly ash using froth flotation. The results of this study suggest a means for power plants to reduce the level of Hg in coal-combustion products and potentially recycle activated carbon while maintaining the resale value of fly ash. This technology is in the process of being patented.

  8. Engineering development of coal-fired high performance power systems phase 2 and 3

    SciTech Connect

    Unknown

    1999-08-01

    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; and 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 2.2 HITAF Air Heaters; and Task 2.4 Duct Heater and Gas Turbine Integration.

  9. Novel regenerable sorbent for mercury capture from flue gases of coal-fired power plant.

    PubMed

    Liu, Yan; Kelly, David J A; Yang, Hongqun; Lin, Christopher C H; Kuznicki, Steve M; Xu, Zhenghe

    2008-08-15

    A natural chabazite-based silver nanocomposite (AgMC) was synthesized to capture mercury from flue gases of coal-fired power plants. Silver nanoparticles were engineered on zeolite through ion-exchange of sodium ions with silver ions, followed by thermal annealing. Mercury sorption test using AgMC was performed at various temperatures by exposing it to either pulse injection of mercury or continuous mercury flow. A complete capture of mercury by AgMC was achieved up to a capture temperature of 250 degrees C. Nano silver particles were shown to be the main active component for mercury capture by amalgamation mechanism. Compared with activated carbon-based sorbents, the sorbent prepared in this study showed a much higher mercury capture capacity and upper temperature limit for mercury capture. More importantly, the mercury captured by the spent AgMC could be easily released for safe disposal and the sorbent regenerated by simple heating at 400 degrees C. Mercury capture tests performed in real flue gas environment showed a much higher level of mercury capture by AgMC than by other potential mercury sorbents tested. In our mercury capture tests, the AgMC exposed to real flue gases showed an increased mercury capture efficiency than the fresh AgMC.

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

    SciTech Connect

    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.

  11. Effect of the shutdown of a large coal-fired power plant on ambient mercury species.

    PubMed

    Wang, Yungang; Huang, Jiaoyan; Hopke, Philip K; Rattigan, Oliver V; Chalupa, David C; Utell, Mark J; Holsen, Thomas M

    2013-07-01

    In the spring of 2008, a 260MWe coal-fired power plant (CFPP) located in Rochester, New York was closed over a 4month period. Using a 2-years data record, the impacts of the shutdown of the CFPP on nearby ambient concentrations of three Hg species were quantified. The arithmetic average ambient concentrations of gaseous elemental mercury (GEM), gaseous oxidized mercury (GOM), and particulate mercury (PBM) during December 2007-November 2009 were 1.6ngm(-3), 5.1pgm(-3), and 8.9pgm(-3), respectively. The median concentrations of GEM, GOM, and PBM significantly decreased by 12%, 73%, and 50% after the CFPP closed (Mann-Whitney test, p<0.001). Positive Matrix Factorization (EPA PMF v4.1) identified six factors including O3-rich, traffic, gas phase oxidation, wood combustion, nucleation, and CFPP. When the CFPP was closed, median concentrations of GEM, GOM, and PBM apportioned to the CFPP factor significantly decreased by 25%, 74%, and 67%, respectively, compared to those measured when the CFPP was still in operation (Mann-Whitney test, p<0.001). Conditional probability function (CPF) analysis showed the greatest reduction in all three Hg species was associated with northwesterly winds pointing toward the CFPP. These changes were clearly attributable to the closure of the CFPP.

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

    SciTech Connect

    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.

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

    SciTech Connect

    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.

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

    PubMed

    Patiño-Echeverri, Dalia; Morel, Benoit; Apt, Jay; Chen, Chao

    2007-12-01

    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 SO2, NOx, Hg, and CO2 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 SO2 and NOx, controls on the existing unit. An expectation that the CO2 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.

  15. Burden of Disease from Rising Coal-Fired Power Plant Emissions in Southeast Asia.

    PubMed

    Koplitz, Shannon N; Jacob, Daniel J; Sulprizio, Melissa P; Myllyvirta, Lauri; Reid, Colleen

    2017-02-07

    Southeast Asia has a very high population density and is on a fast track to economic development, with most of the growth in electricity demand currently projected to be met by coal. From a detailed analysis of coal-fired power plants presently planned or under construction in Southeast Asia, we project in a business-as-usual scenario that emissions from coal in the region will triple to 2.6 Tg a(-1) SO2 and 2.6 Tg a(-1) NOx by 2030, with the largest increases occurring in Indonesia and Vietnam. Simulations with the GEOS-Chem chemical transport model show large resulting increases in surface air pollution, up to 11 μg m(-3) for annual mean fine particulate matter (PM2.5) in northern Vietnam and up to 15 ppb for seasonal maximum 1 h ozone in Indonesia. We estimate 19 880 (11 400-28 400) excess deaths per year from Southeast Asian coal emissions at present, increasing to 69 660 (40 080-126 710) by 2030. 9000 of these excess deaths in 2030 are in China. As Chinese emissions from coal decline in coming decades, transboundary pollution influence from rising coal emissions in Southeast Asia may become an increasing issue.

  16. Laser Induced Breakdown Spectroscopy application for ash characterisation for a coal fired power plant

    NASA Astrophysics Data System (ADS)

    Ctvrtnickova, T.; Mateo, M. P.; Yañez, A.; Nicolas, G.

    2010-08-01

    The aim of this work was to apply the LIBS technique for the analysis of fly ash and bottom ash resulting from the coal combustion in a coal fired power plant. The steps of presented LIBS analysis were pelletizing of powdered samples, firing with laser and spectroscopic detection. The analysis "on tape" was presented as an alternative fast sampling approach. This procedure was compared with the usual steps of normalized chemical analysis methods for coal which are coal calcination, fluxing in high temperature plasma, dilution in strong acids and analyzing by means of ICP-OES and/or AAS. First, the single pulse LIBS approach was used for determination and quantification of elemental content in fly ash and bottom ash on the exit of the boiler. For pellet preparation, ash has to be mixed with proper binder to assure the sample resistance. Preparation of the samples (binder selection and pressing/pelletizing conditions) was determined and LIBS experimental conditions optimized. No preparation is necessary in "on tape" sampling. Moreover, double-pulse approach in orthogonal reheating configuration was applied to enhance the repeatability and precision of the LIBS results and to surpass the matrix effect influencing the calibration curves in case of some elements. Obtained results showed that LIBS responses are comparable to the normalized analytical methods. Once optimized the experimental conditions and features, application of LIBS may be a promising technique for combustion process control even in on-line mode.

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

    SciTech Connect

    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.

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

    SciTech Connect

    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.

  19. Coal-fired propulsion system dynamics. Volume III. Dynamic analysis of the cv-3600. Final report

    SciTech Connect

    Greenlee, T.L.; Pearsons, J.L.

    1982-12-01

    This volume summarizes the results of a thorough analysis of the CV-3600 dynamic model that was discussed in Volume II. The purpose of this effort was to determine general engineering details and specifications for coal-fired propulsion systems based on a detailed analysis of a specific propulsion system design. The basis for these specifications included the sensitivity of ship propulsion system response to component parameter and control variations such as grate travel speed and controls, spreader and distributor feed and controls, fan speed and damper controls, steam dump (sizing, control valve characteristics and controls), feedwater pump controls (drum level controls), throttle control, and desuperheater steam attemperation controls. To develop greater insight into the effects of these variations, both open-loop (without control) and closed-loop (with control) versions of the propulsion system were studied. The open and closed-loop responses were further analyzed through the use of linear models and eigenvalue analyses. Specific conclusions regarding desirable trends in component specification are provided as part of the conclusions in this volume.

  20. Natural radionuclides in waste water discharged from coal-fired power plants in Serbia.

    PubMed

    Janković, Marija M; Todorović, Dragana J; Sarap, Nataša B; Krneta Nikolić, Jelena D; Rajačić, Milica M; Pantelić, Gordana K

    2016-12-01

    Investigation of the natural radioactivity levels in water around power plants, as well as in plants, coal, ash, slag and soil, and to assess the associated radiation hazard is becoming an emerging and interesting topic. This paper is focused on the results of the radioactivity analysis in waste water samples from five coal-fired power plants in Serbia (Nikola Tesla A, Nikola Tesla B, Kolubara, Morava and Kostolac), which were analyzed in the period 2003-2015. River water samples taken upstream and downstream from the power plants, drain water and overflow water were analyzed. In the water samples gamma spectrometry analysis was performed as well as determination of gross alpha and beta activity. Natural radionuclide (40)K was detected by gamma spectrometry, while the concentrations of other radionuclides, (226)Ra, (235)U and (238)U, usually were below the minimum detection activity (MDA). (232)Th and artificial radionuclide (137)Cs were not detected in these samples. Gross alpha and beta activities were determined by the α/β low level proportional counter Thermo Eberline FHT 770 T. In the analyzed samples, gross alpha activity ranged from MDA to 0.47 Bq L(-)(1), while the gross beta activity ranged from MDA to 1.55 Bq L(-)(1).

  1. Pulverized coal firing of aluminum melting furnaces. Quarterly technical progress report, July 1-September 30, 1979

    SciTech Connect

    West, C E

    1980-09-01

    The ultimate objective of this program is the commercial demonstration of an efficient, environmentally acceptable coal firing process suitable for implementation on melting furnaces throughout the aluminum industry. To achieve this goal, the program has been divided into two phases. Phase I has begun with the design and construction of a 350 pound (coal) per hour staged slagging cyclone combustor (SSCC) attached to a 7-ft diameter aluminum melting ladle furnace. Process development will culminate with a 1000 pph prototype SSCC firing a 40,000 pound capacity open hearth melting furnace at the Alcoa Laboratories. Phase II implementation is currently planned for Alcoa's Lafayette, IN, Works, where two of the ingot plant's five open hearth melting furnaces will be converted to utilize coal. In addition to confirmation of data gathered in Phase I, the effect of extended production schedule operation on equipment and efficiencies will be determined. This work would begin in 1982 pursuant to technical and economic evaluation of the process development at that time.

  2. Coal-fired power generaion, new air quality regulations, and future U.S. coal production

    USGS Publications Warehouse

    Attanasi, E.D.; Root, D.H.

    1999-01-01

    Tighter new regulation of stack gas emissions and competition in power generation are driving electrical utilities to demand cleaner, lower sulfur coal. Historical data on sulfur content of produced coals shows little variability in coal quality for individual mines and individual coal-producing counties over relatively long periods of time. If coal-using power generators follow the compliance patterns established in Phase I of the 1990 Clean Air Act Amendments, then the industry's response to the tighter Phase II emissions standards will result in large amounts of coal production shifting from higher sulfur areas to areas with lower cost low sulfur coal. One reason this shift will likely occur is that currently only 30% of U.S. coal-fired electrical generating capacity is equipped with flue-gas scrubbers. In 1995, coal mines in the higher sulfur areas of the Illinois Basin and Northern and Central Appalachia employed 78% of all coal miners (>70,000 miners). A substantial geographical redistribution of the nation's coal supplies will likely lead to economic dislocations that will reach beyond local coal-producing areas.

  3. MHD Coal Fired Flow Facility. Quarterly technical progress report, July-September 1980

    SciTech Connect

    Altstatt, M. C.; Attig, R. C.; Brosnan, D. A.

    1980-11-01

    Significant activity, task status, planned research, testing, development, and conclusions for the Magnetohydrodynamics (MHD) Coal-Fired Flow Facility (CFFF) and the Energy Conversion Facility (ECF) are described. On Task 1, the first phase of the downstream quench system was completed. On Task 2, all three combustor sections were completed, hydrotested, ASME code stamped, and delivered to UTSI. The nozzle was also delivered. Fabrication of support stands and cooling water manifolds for the combustor and vitiation heater were completed, heat transfer and thermal stress analysis, along with design development, were conducted on the generator and radiant furnace and secondary combustor installation progressed as planned. Under Task 3 an Elemental Analyzer and Atomic Absorption Spectrophotometer/Graphite Furnace were received and installed, sites were prepared for two air monitoring stations, phytoplankton analysis began, and foliage and soil sampling was conducted using all study plots. Some 288 soil samples were combined to make 72 samples which were analyzed. Also, approval was granted to dispose of MHD flyash and slag at the Franklin County landfill. Task 4 effort consisted of completing all component test plans, and establishing the capability of displaying experimental data in graphical format. Under Task 7, a preliminary testing program for critical monitoring of the local current and voltage non-uniformities in the generator electrodes was outlined, electrode metal wear characteristics were documented, boron nitride/refrasil composite interelectrode sealing was improved, and several refractories for downstream MHD applications were evaluated with promising results.

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

    SciTech Connect

    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.

  5. Thermal Imaging of Subsurface Coal Fires by means of an Unmanned Aerial Vehicle (UAV) in the Autonomous Province Xinjiang, PRC

    NASA Astrophysics Data System (ADS)

    Vasterling, Margarete; Schloemer, Stefan; Fischer, Christian; Ehrler, Christoph

    2010-05-01

    Spontaneous combustion of coal and resulting coal fires lead to very high temperatures in the subsurface. To a large amount the heat is transferred to the surface by convective and conductive transport inducing a more or less pronounced thermal anomaly. During the past decade satellite-based infrared-imaging (ASTER, MODIS) was the method of choice for coal fire detection on a local and regional scale. However, the resolution is by far too low for a detailed analysis of single coal fires which is essential prerequisite for corrective measures (i.e. fire fighting) and calculation of carbon dioxide emission based on a complex correlation between energy release and CO2 generation. Consequently, within the framework of the Sino-German research project "Innovative Technologies for Exploration, Extinction and Monitoring of Coal Fires in Northern China", a new concept was developed and successfully tested. An unmanned aerial vehicle (UAV) was equipped with a lightweight camera for thermografic (resolution 160 by 120 pixel, dynamic range -20 to 250°C) and for visual imaging. The UAV designed as an octocopter is able to hover at GPS controlled waypoints during predefined flight missions. The application of a UAV has several advantages. Compared to point measurements on the ground the thermal imagery quickly provides the spatial distribution of the temperature anomaly with a much better resolution. Areas otherwise not accessible (due to topography, fire induced cracks, etc.) can easily be investigated. The results of areal surveys on two coal fires in Xinjiang are presented. Georeferenced thermal and visual images were mosaicked together and analyzed. UAV-born data do well compared to temperatures measured directly on the ground and cover large areas in detail. However, measuring surface temperature alone is not sufficient. Simultaneous measurements made at the surface and in roughly 15cm depth proved substantial temperature gradients in the upper soil. Thus the temperature

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

    SciTech Connect

    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 useful tool to help reduce the number of iterations necessary to perform laboratory experiments or alloy development. However, we clearly are not able to rely solely on computational techniques in the development of high temperature materials for IGT applications. A significant amount of experimentation will continue to be required.

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

    SciTech Connect

    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.

  8. World market: A survey of opportunities for advanced coal-fired systems

    SciTech Connect

    Holt, N.A.H.

    1995-06-01

    Although there is a wide range of forecasts for the future of World energy demand and consumption over the next 25 years, all forecasts show marked increases being required for all forms of fossil fuels even when optimistic projections are made for the future adoption of Nuclear and Renewable energy. It is also generally expected that coal usage will in this period experience its greatest growth (a doubling) in the Asia-Pacific region dominated demographically by China and India. In this paper, energy projections and the extent and nature of the coal reserves available worldwide are examined. While most coal technologies can handle a variety of feedstocks, there are often economic factors that will determine the preferred selection. The matching of technology to coal type and other factors is examined with particular reference to the Asia Pacific region. Oil usage is similarly forecast to experience a comparable growth in this region. Over 70% of the World`s oil reserves are heavy oils and refinery crudes are increasing in gravity and sulfur content. The clean coal technologies of gasification and fluid bed combustion can also use low value petroleum residuals as feedstocks. There is therefore a nearer term market opportunity to incorporate such technologies into cogeneration and coproduction schemes adjacent to refineries resulting in extremely efficient use of these resources.

  9. Rocket Based Combined Cycle (RBCC) Propulsion Workshop, volume 2

    NASA Technical Reports Server (NTRS)

    Chojnacki, Kent T.

    1992-01-01

    The goal of the Rocket Based Combined Cycle (RBCC) Propulsion Technology Workshop, was to impart technology information to the propulsion community with respect to hypersonic combined cycle propulsion capabilities. The major recommendation resulting from this technology workshop was as follows: conduct a systems-level applications study to define the desired propulsion system and vehicle technology requirements for LEO launch vehicles. All SSTO and TSTO options using the various propulsion systems (airbreathing combined cycle, rocket-based combined cycle, and all rocket) must be considered. Such a study should be accomplished as soon as possible. It must be conducted with a consistent set of ground rules and assumptions. Additionally, the study should be conducted before any major expenditures on a RBCC technology development program occur.

  10. Transient studies of an Integrated Gasification Combined Cycle (IGCC) plant with CO2 capture

    SciTech Connect

    Bhattacharyya, D.; Turton, R.; Zitney, S.

    2010-01-01

    Next-generation coal-fired power plants need to consider the option for CO2 capture as stringent governmental mandates are expected to be issued in near future. Integrated gasification combined cycle (IGCC) plants are more efficient than the conventional coal combustion processes when the option for CO2 capture is considered. However, no IGCC plant with CO2 capture currently exists in the world. Therefore, it is important to consider the operability and controllability issues of such a plant before it is commercially built. To facilitate this objective, a detailed plant-wide dynamic simulation of an IGCC plant with 90% CO2 capture has been developed in Aspen Plus Dynamics{reg_sign}. The plant considers a General Electric Energy (GEE)-type downflow radiant-only gasifier followed by a quench section. A two-stage water gas shift (WGS) reaction is considered for conversion of CO to CO2. A two-stage acid gas removal (AGR) process based on a physical solvent is simulated for selective capture of H2S and CO2. Compression of the captured CO2 for sequestration, an oxy-Claus process for removal of H2S and NH3, black water treatment, and the sour water treatment are also modeled. The tail gas from the Claus unit is recycled to the SELEXOL unit. The clean syngas from the AGR process is sent to a gas turbine followed by a heat recovery steam generator. This turbine is modeled as per published data in the literature. Diluent N2 is used from the elevated-pressure ASU for reducing the NOx formation. The heat recovery steam generator (HRSG) is modeled by considering generation of high-pressure, intermediate-pressure, and low-pressure steam. All of the vessels, reactors, heat exchangers, and the columns have been sized. The basic IGCC process control structure has been synthesized by standard guidelines and existing practices. The steady state results are validated with data from a commercial gasifier. In the future grid-connected system, the plant should satisfy the environmental

  11. Tampa Electric Company Integrated Gasification Combined Cycle Project

    SciTech Connect

    Pless, D.E.; Black, C.R.

    1992-01-01

    The proposed project will utilize commercially available gasification technology as provided by Texaco in their licensed oxygen-blown entrained-flow gasifier. In this arrangement, coal is ground to specification and slurried in water to the desired concentration (60--70% solids) in rod mills. This coal slurry and an oxidant (95 % pure oxygen) are then mixed in the gasifier burner where the coal partially combusts, in an oxygen deficient environment, to produce syngas with a heat content of about 250 BTU/SCF (LHV) at a temperature in excess of 2500[degrees]F. The oxygen will be produced from an Air Separation Unit (ASU). The gasifier is expected to achieve greater than 95% carbon conversion in a single pass. It is currently planned for the gasifier to be a single vessel feeding into one radiant syngas cooler where the temperature will be reduced from about 2500[degrees]F to about 1300[degrees]F. After the radiant cooler, the gas will then be split into two (2) parallel convective coolers, where the temperature will be cooled further to about 900[degrees]F. One stream will go to the 50% HGCU system and the other stream to the traditional CGCU system with 100% capacity. This flow arrangement was selected to provide assurance to Tampa Electric that the IGCC capability would not be restricted due to the demonstration of the HGCU system. A traditional amine scrubber type system with conventional sulfur recovery will be used. Sulfur from the HGCU and CGCU systems will be recovered in the form of H[sub 2]SO[sub 4] and elemental sulfur respectively.The key components of the combined cycle are the advanced combustion.turbine (CT), heat recovery steam generator (HRSG), and steam turbine (ST), and generators. The advanced CT will be a GE 7F operating with a firing temperature of about 2300[degrees]F.

  12. Tampa Electric Company Integrated Gasification Combined Cycle Project

    SciTech Connect

    Pless, D.E.; Black, C.R.

    1992-11-01

    The proposed project will utilize commercially available gasification technology as provided by Texaco in their licensed oxygen-blown entrained-flow gasifier. In this arrangement, coal is ground to specification and slurried in water to the desired concentration (60--70% solids) in rod mills. This coal slurry and an oxidant (95 % pure oxygen) are then mixed in the gasifier burner where the coal partially combusts, in an oxygen deficient environment, to produce syngas with a heat content of about 250 BTU/SCF (LHV) at a temperature in excess of 2500{degrees}F. The oxygen will be produced from an Air Separation Unit (ASU). The gasifier is expected to achieve greater than 95% carbon conversion in a single pass. It is currently planned for the gasifier to be a single vessel feeding into one radiant syngas cooler where the temperature will be reduced from about 2500{degrees}F to about 1300{degrees}F. After the radiant cooler, the gas will then be split into two (2) parallel convective coolers, where the temperature will be cooled further to about 900{degrees}F. One stream will go to the 50% HGCU system and the other stream to the traditional CGCU system with 100% capacity. This flow arrangement was selected to provide assurance to Tampa Electric that the IGCC capability would not be restricted due to the demonstration of the HGCU system. A traditional amine scrubber type system with conventional sulfur recovery will be used. Sulfur from the HGCU and CGCU systems will be recovered in the form of H{sub 2}SO{sub 4} and elemental sulfur respectively.The key components of the combined cycle are the advanced combustion.turbine (CT), heat recovery steam generator (HRSG), and steam turbine (ST), and generators. The advanced CT will be a GE 7F operating with a firing temperature of about 2300{degrees}F.

  13. Summary of workshop on materials issues in low emission boilers and high efficiency coal-fired cycles

    SciTech Connect

    1997-12-01

    The purpose of the workshop was to review with experts in the field the materials issues associated with two of the primary coal power systems being developed by the DOE Office of Fossil Energy. The DOE-FE Advanced Power Systems Program includes natural gas-based and coal-based power systems. Major activities in the natural gas-based power systems area include the Advanced Turbine Systems (ATS) Program, the Fuel Cells Program, and Hybrid Cycles. The coal-based power systems projects include the Low Emissions Boiler Systems (LEBS) Program, the High-Performance Power Systems Program (HIPPS), the Integrated (Coal) Gasification Combined-Cycle Program, and the Fluidized-Bed Combustion Program. This workshop focused on the materials issues associated with the LEBS and HIPPS technologies.

  14. Applications study of advanced power generation systems utilizing coal-derived fuels. Volume 1: Executive summary

    NASA Technical Reports Server (NTRS)

    Robson, F. L.

    1981-01-01

    The technology status of phosphoric acid and molten carbon fuel cells, combined gas and steam turbine cycles, and magnetohydrodynamic energy conversion systems was assessed and the power performance of these systems when operating with medium-Btu fuel gas whether delivered by pipeline to the power plant or in an integrated mode in which the coal gasification process and power system are closely coupled as an overall power plant was evaluated. Commercially available combined-cycle gas turbine systems can reach projected required performance levels for advanced systems using currently available technology. The phosphoric acid fuel cell appears to be the next most likely candidate for commercialization. On pipeline delivery, the systems efficiency ranges from 40.9% for the phosphoric acid fuel cell to 63% for the molten carbonate fuel cell system. The efficiencies of the integrated power plants vary from approximately 39-40% for the combined cycle to 46-47% for the molden carbonate fuel cell systems. Conventional coal-fired steam stations with flue-gas desulfurization have only 33-35% efficiency.

  15. 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

    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.

  16. Modeling and optimization of a hybrid solar combined cycle (HYCS)

    NASA Astrophysics Data System (ADS)

    Eter, Ahmad Adel

    2011-12-01

    The main objective of this thesis is to investigate the feasibility of integrating concentrated solar power (CSP) technology with the conventional combined cycle technology for electric generation in Saudi Arabia. The generated electricity can be used locally to meet the annual increasing demand. Specifically, it can be utilized to meet the demand during the hours 10 am-3 pm and prevent blackout hours, of some industrial sectors. The proposed CSP design gives flexibility in the operation system. Since, it works as a conventional combined cycle during night time and it switches to work as a hybrid solar combined cycle during day time. The first objective of the thesis is to develop a thermo-economical mathematical model that can simulate the performance of a hybrid solar-fossil fuel combined cycle. The second objective is to develop a computer simulation code that can solve the thermo-economical mathematical model using available software such as E.E.S. The developed simulation code is used to analyze the thermo-economic performance of different configurations of integrating the CSP with the conventional fossil fuel combined cycle to achieve the optimal integration configuration. This optimal integration configuration has been investigated further to achieve the optimal design of the solar field that gives the optimal solar share. Thermo-economical performance metrics which are available in the literature have been used in the present work to assess the thermo-economic performance of the investigated configurations. The economical and environmental impact of integration CSP with the conventional fossil fuel combined cycle are estimated and discussed. Finally, the optimal integration configuration is found to be solarization steam side in conventional combined cycle with solar multiple 0.38 which needs 29 hectare and LEC of HYCS is 63.17 $/MWh under Dhahran weather conditions.

  17. The level of air pollution in the impact zone of coal-fired power plant (Karaganda City) using the data of geochemical snow survey (Republic of Kazakhstan)

    NASA Astrophysics Data System (ADS)

    Adil'bayeva, T. E.; Talovskaya, A. V.; Yazikov, Ye G.; Matveenko, I. A.

    2016-09-01

    Coal-fired power plants emissions impact the air quality and human health. Of great significance is assessment of solid airborne particles emissions from those plants and distance of their transportation. The article presents the results of air pollution assessment in the zone of coal-fired power plant (Karaganda City) using snow survey. Based on the mass of solid airborne particles deposited in snow, time of their deposition on snow at the distance from 0.5 to 4.5 km a value of dust load has been determined. It is stated that very high level of pollution is observed at the distance from 0.5 to 1 km. there is a trend in decrease of dust burden value with the distance from the stacks of coal-fired power plant that may be conditioned by the particle size and washing out smaller ash particles by ice pellets forming at freezing water vapour in stacks of the coal-fired power plant. Study in composition of solid airborne particles deposited in snow has shown that they mainly contain particulates of underburnt coal, Al-Si- rich spheres, Fe-rich spheres, and coal dust. The content of the particles in samples decreases with the distance from the stacks of the coal-fired power plant.

  18. Assessment method for the prevention effectiveness of PM2.5 based on the optimization development of coal-fired power generation

    NASA Astrophysics Data System (ADS)

    Zheng, Kuan; Liu, Jun; Zhang, Jin-fang; Hao, Weihua

    2017-01-01

    A large number of combustion of coal is easy to lead to the haze weather which has brought a lot of inconveniences and threat to people’s living and health in E&C China, as the dominant power source of China, the coal-fired power generation is one of the main sources to the haze. In this paper, the contribution of the combustion of coal and development of coal-fired power generation to the PM2.5 emissions is summarized based on the analysis of the present situation, the mechanism and the emission source of PM2.5. Considering the peak of carbon emissions and the constraints of atmospheric environment, the quantitative assessment method of PM2.5 by optimizing the development of coal-fired power generation is present. By the computation analysis for different scenarios, it indicates that the optimization scenario, which means the main new-installed coal-fired power generation is distributed in western and northern China, can prevent the PM2.5 effectively for both the load center and coal base regions of China. The results of this paper not only have reference value for the optimized layout of coal-fired power generation in the “13rd fifth-year” power planning, also is of great significance to deal with problems that the atmospheric pollution and climate warming in the future.

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

    SciTech Connect

    Adams, Bradley; Davis, Kevin; Senior, Constance; Shim, Hong Shim; Otten, Brydger Van; 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

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

    SciTech Connect

    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

  1. Low level measurements of natural radionuclides in soil samples around a coal-fired power plant

    NASA Astrophysics Data System (ADS)

    Rosner, G.; Bunzl, K.; Hötzl, H.; Winkler, R.

    1984-06-01

    To detect a possible contribution of airborne radioactivity from stack effluents to the soil radioactivity, several radionuclides in the soil around a coal-fired power plant have been determined. A plant situated in a rural region of Bavaria was selected to minimize contributions from other civilisatory sources. The soil sampling network consisted of 5 concentric circles with diameters between 0.4 and 5.2 km around the plant, 16 sampling points being distributed regularly on each circle. Radiochemical analysis techniques for 210Pb and 210Po in soil samples of several grams had to be developed. They include a wet dissolution procedure, simultaneous precipitation of lead and polonium as the sulfides, purification via lead sulfate, counting of the lead as the chromate in a low-level beta counter and alpha spectrometric determination of the 210Po in a gridded ionization chamber. The 238U, 226Ra, 232Th and 40K were counted by low level gamma spectrometry. Specific activities found were in the range of 0.7 to 2.0 pCi g -1 for 210Pb and 0.3 to 1.6 pCi g -1 for 226Ra. The distribution patterns of 210Po and 210Pb around the plant were found to be similar. They were different, however, from that of 226Ra. The highest 210Pb/ 226Ra activity ratio was 3.9 at a distance of 0.76 km SSE from the plant. Nevertheless, the evidence is not considered to be sufficient to attribute these observations unambiguously to plant releases.

  2. Optimization of Trona/Limestone Injection for SO2 Control in Coal-Fired Boilers

    SciTech Connect

    2005-09-01

    Mobotec USA develops and markets air pollution control systems for utility boilers and other combustion systems. They have a particular interest in technologies that can reduce NOx, SOx, and mercury emissions from coal-fired boilers, and have been investigating the injection of sorbents such as limestone and trona into a boiler to reduce SOx and Hg emissions. WRI proposed to use the Combustion Test Facility (CTF) to enable Mobotec to conduct a thorough evaluation of limestone and trona injection for SO{sub 2} control. The overall goal of the project was to characterize the SO{sub 2} reductions resulting from the injection of limestone and trona into the CTF when fired with a high-sulfur eastern bituminous coal used in one of Mobotec's Midwest installations. Results revealed that when limestone was injected at Ca:S molar ratios of 1.5 to 3.0, the resulting SO{sub 2} reductions were 35-55%. It is believed that further reductions can be attained with improved mixing of the sorbent with the combustion gases. When limestone was added to the coal, at Ca:S molar ratios of 0.5 to 1.5, the SO{sub 2} reductions were 13-21%. The lower reductions were attributed to dead-burning of the sorbent in the high temperature flame zone. In cases where limestone was both injected into the furnace and added to the coal, the total SO{sub 2} reductions for a given Ca:S molar ratio were similar to the reductions for furnace injection only. The injection of trona into the mid-furnace zone, for Na:S molar ratios of 1.4 to 2.4, resulted in SO{sub 2} reductions of 29-43%. Limestone injection did not produce any slag deposits on an ash deposition probe while trona injection resulted in noticeable slag deposition.

  3. Modeling of ash deposition in the convective pass of a coal-fired boiler

    SciTech Connect

    Allan, S.E.; Erickson, T.A.; McCollor, D.P.

    1996-12-31

    The Energy and Environmental Research Center (EERC) has developed a personal computer (PC)-based model, FOULER, to predict convective pass fouling deposit formation in coal-fired boilers. This program is used to evaluate the effects of coal quality and operational changes on both high- and low-temperature fouling. In addition, the effects of coal cleaning, blending, and switching options can be evaluated. FOULER will be incorporated in the Coal Quality Expert (CQE) software project. CQE is a comprehensive, PC-based program that can be used to evaluate various potential coal cleaning, blending, and switching options to reduce power plant emissions while minimizing generation costs. The model is based on theory and a combination of laboratory-, pilot-, and field-scale test data. The code encompasses the hanging pendant, superheater, reheater, and economizer regions of the convective pass. The code predicts growth and removal of ash deposition through the interaction of several submodels: (1) Deposit Growth, (2) Deposit Strength Development, (3) Thermal Properties, (4) Deposit Removal, and (5) Sootblower Effectiveness. The deposit removal mechanisms included are thermal shock, gravity shedding, and sootblowing. The required inputs for the code include ash size and composition, boiler parameters, and operation conditions. Input parameters can be entered into the code directly or they can be predicted by other codes such as MMT (mineral matter transformation code) and CQE heat-transfer module. The submodels interact to produce outputs, based on a time basis, of the deposit mass, strength, resistivity, and removal rates. This report describes the fouling submodels, the rationale used in these submodels, and a description of how the experimental data were utilized to validate the algorithms.

  4. Biological processes for the treatment of waste water from coal-fired power plants

    SciTech Connect

    Vredenbregt, L.H.J.; Potma, A.A.; Enoch, G.D.

    1998-07-01

    In The Netherlands, all coal-fired power stations are equipped with a wet lime(stone)-gypsum flue gas desulfurization (FGD) installation, in order to meet the SO{sub 2} emission requirements. During wet desulfurization a waste water stream is produced containing among others suspended solids, heavy metals, nitrate and in some cases ammonia. Besides, the chemical oxygen demand (COD) of the waste water is increased if the FGD process is optimized by application of organic buffers. The traditional waste water treatment plant (WWTP) does not remove nitrate, ammonia and COD, and only poorly removes the anions of oxygenated metals such as selenium. In a previous research it was demonstrated that nitrate and ammonia can be removed biologically, even at the relatively extreme conditions of FGD waste water, which is characterized by a high chloride concentration (5 and 40 g/l) and relatively high temperatures (typically 35--50 C). However, the removal is no longer solely focused on nitrogen components, but also on COD removal and for the anions of some oxygenated metals target values are expected in the near future. In this paper attention is focused on two biological processes. One process is the combined removal of nitrate and COD in a fluid-bed reactor which can be applied upstream of the traditional WWTP. The application of this process was successfully demonstrated at a bench-scale fluid bed reactor. The optimal process conditions were determined in activated-sludge reactors on a laboratory scale. The second biological process is the combined removal of COD and metals from FGD waste water. An upflow sludge blanket reactor was successfully tested on laboratory scale at a wide range of process conditions with actual waste water. The possible advantages and disadvantages of the biological removal processes are discussed and compared with the well known chemical precipitation process.

  5. Impacts of the Minamata Convention for Mercury Emissions from Coal-fired Power Generation in Asia

    NASA Astrophysics Data System (ADS)

    Giang, A.; Stokes, L. C.; Streets, D. G.; Corbitt, E. S.; Selin, N. E.

    2014-12-01

    We explore the potential implications of the recently signed United Nations Minamata Convention on Mercury for emissions from coal-fired power generation in Asia, and the impacts of these emissions changes on deposition of mercury worldwide by 2050. We use qualitative interviews, document analysis, and engineering analysis to create plausible technology scenarios consistent with the Convention, taking into account both technological and political factors. We translate these scenarios into possible emissions inventories for 2050, based on IPCC development scenarios, and then use the GEOS-Chem global transport model to evaluate the effect of these different technology choices on mercury deposition over geographic regions and oceans. We find that China is most likely to address mercury control through co-benefits from technologies for SO2, NOx, and particulate matter (PM) capture that will be required to attain its existing air quality goals. In contrast, India is likely to focus on improvements to plant efficiency such as upgrading boilers, and coal washing. Compared to current technologies, we project that these changes will result in emissions decreases of approximately 140 and 190 Mg/yr for China and India respectively in 2050, under an A1B development scenario. With these emissions reductions, simulated average gross deposition over India and China are reduced by approximately 10 and 3 μg/m2/yr respectively, and the global average concentration of total gaseous mercury (TGM) is reduced by approximately 10% in the Northern hemisphere. Stricter, but technologically feasible, requirements for mercury control in both countries could lead to an additional 200 Mg/yr of emissions reductions. Modeled differences in concentration and deposition patterns between technology suites are due to differences in both the mercury removal efficiency of technologies and their resulting stack speciation.

  6. Atmospheric emissions and pollution from the coal-fired thermal power plants in India

    NASA Astrophysics Data System (ADS)

    Guttikunda, Sarath K.; Jawahar, Puja

    2014-08-01

    In India, of the 210 GW electricity generation capacity, 66% is derived from coal, with planned additions of 76 GW and 93 GW during the 12th and the 13th five year plans, respectively. Atmospheric emissions from the coal-fired power plants are responsible for a large burden on human health. In 2010-11, 111 plants with an installed capacity of 121 GW, consumed 503 million tons of coal, and generated an estimated 580 ktons of particulates with diameter less than 2.5 μm (PM2.5), 2100 ktons of sulfur dioxides, 2000 ktons of nitrogen oxides, 1100 ktons of carbon monoxide, 100 ktons of volatile organic compounds, and 665 million tons of carbon dioxide. These emissions resulted in an estimated 80,000 to 115,000 premature deaths and 20.0 million asthma cases from exposure to PM2.5 pollution, which cost the public and the government an estimated INR 16,000 to 23,000 crores (USD 3.2 to 4.6 billion). The emissions were estimated for the individual plants and the atmospheric modeling was conducted using CAMx chemical transport model, coupled with plume rise functions and hourly meteorology. The analysis shows that aggressive pollution control regulations such as mandating flue gas desulfurization, introduction and tightening of emission standards for all criteria pollutants, and updating procedures for environment impact assessments, are imperative for regional clean air and to reduce health impacts. For example, a mandate for installation of flue gas desulfurization systems for the operational 111 plants could reduce the PM2.5 concentrations by 30-40% by eliminating the formation of the secondary sulfates and nitrates.

  7. Pollution control and environmental monitoring efforts at DOE's Coal-Fired Flow Facility

    SciTech Connect

    Attig, R.C.; Crawford, L.W.; Lynch, T.P.; Sheth, A.C.

    1991-01-01

    Proof-of-Concept (POC) scale demonstration of such technology is currently being carried out at the US Department of Energy's (DOE's) Coal-Fired Flow Facility (CFFF), located at The University of Tennessee Space Institute (UTSI) in Tullahoma, Tennessee and at the Component Development and Integration Facility in Butte, Montana. The CFFF is dedicated to the evaluation of downstream (steam cycle) components and technology that may be considered for a full-scale MHD system. The objectives of the CFFF testing include the demonstration of various pollution control devices and techniques at a scale sufficient for future scale-up. The CFFF offers a unique test environment in which emissions control techniques can be developed and evaluated through emissions and environmental monitoring. Results thus far have demonstrated the ability of sulfur oxide (SO{sub x}), nitrogen oxide (NO{sub x}) and particulate emissions well below the New Source Performance Standards (NSPS). Regeneration of the potassium sulfate to produce sulfur-free compounds also has been demonstrated. The experimental program at the CFFF is now aimed at determining the optimum conditions for future commercial scale designs. Because of increased interests in Air Toxics, measurements of nitrous oxide (N{sub 2}O), a potential greenhouse gas, priority pollutants (inorganic as well as organics), and chlorine-containing species (Cl{sub 2} and HCl) are also included in our ongoing efforts. Environmental monitoring activities are being pursued to develop an environmental impact assessment data base. These include the use of three ambient air sites to determine the impacts of gaseous and particulate emissions, five lake water sites to determine impacts due to process water discharges and seven sites to collect terrestrial data on possible soil contamination and tree growth. In this paper, we will summarize the status of our ongoing environmental program. 16 refs., 15 figs., 3 tabs.

  8. A NOVEL SENSOR AND MEASUREMENT SYSTEM FOR FIRESIDE CORROSION MONITORING IN COAL-FIRED BOILERS

    SciTech Connect

    Heng Ban; Zuoping Li

    2003-03-01

    Fireside corrosion in coal-fired power plants is a major obstacle to increase the overall efficiency for power producers. The increased use of opportunity fuels and low emission combustion modes have aggravated the corrosion on boiler tube walls in power plants. Corrosion-induced equipment failure could lead to catastrophic damage and inflict significant loss of production and cost for repair. Monitoring fireside corrosion in a reliable and timely manner can provide significant benefits to the plant operation. Current corrosion inspection and measurement are typically performed during scheduled maintenance outages, which is often after the damage is done. In the past, there have been many attempts to develop real time continuous corrosion monitoring technologies. However, there is still no short-term, online corrosion monitoring system commercially available for fireside corrosion to date due to the extremely harsh combustion environment. This report describes the results of a laboratory feasibility study on the development effort of a novel sensor for on-line fireside corrosion monitoring. A novel sensor principle and thin-film technologies were employed in the corrosion sensor design and fabrication. The sensor and the measurement system were experimentally studied using laboratory muffle furnaces. The results indicated that an accurate measure of corrosion rate could be made with high sensitivity using the new sensor. The investigation proved the feasibility of the concept and demonstrated the sensor design, sensor fabrication, and measurement instrumentation at the laboratory scale. An uncertainty analysis of the measurement system was also performed to provide a basis for further improvement of the system for future pilot or full scale testing.

  9. Vibratory machines can provide handling flexibility in coal fired power plants

    SciTech Connect

    Dumbaugh, G.D.

    1993-12-31

    In an electric utility type coal fired power plant, there are many different types of bulk solids that must be handled other than the needed fuel. In addition to the coal, which can be of high or low sulfur content, the firing of the combustor of the boilers may be supplemented with one or more of the various {open_quotes}waste type fuels{close_quotes}. The latter could include coal culm, gob, or silt; wood wastes such as bark, chips, shavings, or sawdust, and other plant type organics like sugar can stalks, rice hulls, or something similar. Whole and shredded rubber tires or shredded municipal solid waste (MSW), which is better known as {open_quotes}refuse derived fuel{close_quotes} (RDF), can also be burned. These {open_quotes}waste type fuels{close_quotes} are attractive because their cost is very nominal as compared to {open_quotes}highly specified{close_quotes} top grade fossil fuels. Quite often, the utility will actually be paid an added revenue to receive them. To accomplish the current {open_quotes}clean air{close_quotes} standards, lime, limestone, and so-called FGD gypsum must be successfully moved. Regardless of the type of fuel, the aftermath of its burning will always take the form of either the dust collected {open_quotes}fly ash{close_quotes} or the residue {open_quotes}bottom ash{close_quotes} that drops down to discharge from the combustor. This presentation will show the {open_quotes}Induced Vertical Flow and Conveying{close_quotes} principles can be selectively applied to achieve more flexibility in the handling of these needed materials. The primary advantage is their ability to successfully contend with continually changing physical properties and, when needed, the quantity of heat content of the bulk solid being handled.

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

    SciTech Connect

    Constance Senior; Temi Linjewile

    2003-07-25

    This is the first 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 Ceramics 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, analysis of the coal, ash and mercury speciation data from the first test series was completed. Good agreement was shown between different methods of measuring mercury in the flue gas: Ontario Hydro, semi-continuous emission monitor (SCEM) and coal composition. There was a loss of total mercury across the commercial catalysts, but not across the blank monolith. The blank monolith showed no oxidation. The data from the first test series show the same trend in mercury oxidation as a function of space velocity that has been seen elsewhere. At space velocities in the range of 6,000-7,000 hr{sup -1} the blank monolith did not show any mercury oxidation, with or without ammonia present. Two of the commercial catalysts clearly showed an effect of ammonia. Two other commercial catalysts showed an effect of ammonia, although the error bars for the no-ammonia case are large. A test plan was written for the second test series and is being reviewed.

  11. Soil as an archive of coal-fired power plant mercury deposition.

    PubMed

    Rodríguez Martín, José Antonio; Nanos, Nikos

    2016-05-05

    Mercury pollution is a global environmental problem that has serious implications for human health. One of the most important sources of anthropogenic mercury emissions are coal-burning power plants. Hg accumulations in soil are associated with their atmospheric deposition. Our study provides the first assessment of soil Hg on the entire Spanish surface obtained from one sampling protocol. Hg spatial distribution was analysed with topsoil samples taken from 4000 locations in a regular sampling grid. The other aim was to use geostatistical techniques to verify the extent of soil contamination by Hg and to evaluate presumed Hg enrichment near the seven Spanish power plants with installed capacity above 1000 MW. The Hg concentration in Spanish soil fell within the range of 1-7564 μg kg(-1) (mean 67.2) and 50% of the samples had a concentration below 37 μg kg(-1). Evidence for human activity was found near all the coal-fired power plants, which reflects that metals have accumulated in the basin over many years. Values over 1000 μg kg(-1) have been found in soils in the vicinity of the Aboño, Soto de Ribera and Castellon power plants. However, soil Hg enrichment was detectable only close to the emission source, within an approximate range of only 15 km from the power plants. We associated this effect with airborne emissions and subsequent depositions as the potential distance through fly ash deposition. Hg associated with particles of ash tends to be deposited near coal combustion sources.

  12. Mercury emission and speciation of coal-fired power plants in China

    NASA Astrophysics Data System (ADS)

    Wang, S. X.; Zhang, L.; Li, G. H.; Wu, Y.; Hao, J. M.; Pirrone, N.; Sprovieri, F.; Ancora, M. P.

    2010-02-01

    Comprehensive field measurements are needed to understand the mercury emissions from Chinese power plants and to improve the accuracy of emission inventories. Characterization of mercury emissions and their behavior were measured in six typical coal-fired power plants in China. During the tests, the flue gas was sampled simultaneously at inlet and outlet of Selective Catalytic Reduction (SCR), electrostatic precipitators (ESP), and flue gas desulfurization (FGD) using the Ontario Hydro Method (OHM). The pulverized coal, bottom ash, fly ash and gypsum were also sampled in the field. Mercury concentrations in coal burned in the measured power plants ranged from 17 to 385 μg/kg. The mercury mass balances for the six power plants varied from 87 to 116% of the input coal mercury for the whole system. The total mercury concentrations in the flue gas from boilers were at the range of 1.92-27.15 μg/m3, which were significantly related to the mercury contents in burned coal. The mercury speciation in flue gas right after the boiler is influenced by the contents of halogen, mercury, and ash in the burned coal. The average mercury removal efficiencies of ESP, ESP plus wet FGD, and ESP plus dry FGD-FF systems were 24%, 73% and 66%, respectively, which were similar to the average removal efficiencies of pollution control device systems in other countries such as US, Japan and South Korea. The SCR system oxidized 16% elemental mercury and reduced about 32% of total mercury. Elemental mercury, accounting for 66-94% of total mercury, was the dominant species emitted to the atmosphere. The mercury emission factor was also calculated for each power plant.

  13. Aged particles derived from emissions of coal-fired power plants: The TERESA field results

    PubMed Central

    Kang, Choong-Min; Gupta, Tarun; Ruiz, Pablo A.; Wolfson, Jack M.; Ferguson, Stephen T.; Lawrence, Joy E.; Rohr, Annette C.; Godleski, John; Koutrakis, Petros

    2013-01-01

    The Toxicological Evaluation of Realistic Emissions Source Aerosols (TERESA) study was carried out at three US coal-fired power plants to investigate the potential toxicological effects of primary and photochemically aged (secondary) particles using in situ stack emissions. The exposure system designed successfully simulated chemical reactions that power plant emissions undergo in a plume during transport from the stack to receptor areas (e.g., urban areas). Test atmospheres developed for toxicological experiments included scenarios to simulate a sequence of atmospheric reactions that can occur in a plume: (1) primary emissions only; (2) H2SO4 aerosol from oxidation of SO2; (3) H2SO4 aerosol neutralized by gas-phase NH3; (4) neutralized H2SO4 with secondary organic aerosol (SOA) formed by the reaction of α-pinene with O3; and (5) three control scenarios excluding primary particles. The aged particle mass concentrations varied significantly from 43.8 to 257.1 μg/m3 with respect to scenario and power plant. The highest was found when oxidized aerosols were neutralized by gas-phase NH3 with added SOA. The mass concentration depended primarily on the ratio of SO2 to NOx (particularly NO) emissions, which was determined mainly by coal composition and emissions controls. Particulate sulfate (H2SO4 + neutralized sulfate) and organic carbon (OC) were major components of the aged particles with added SOA, whereas trace elements were present at very low concentrations. Physical and chemical properties of aged particles appear to be influenced by coal type, emissions controls and the particular atmospheric scenarios employed. PMID:20462390

  14. Mercury removals by existing pollutants control devices of four coal-fired power plants in China.

    PubMed

    Wang, Juan; Wang, Wenhua; Xu, Wei; Wang, Xiaohao; Zhao, Song

    2011-01-01

    The mercury removals by existing pollution control devices and the mass balances of mercury in four coal-fired power plants of China were carried out based on a measurement method with the aluminum matrix sorbent. All the plants are equipped with a cold-side electrostatic precipitator (ESP) and a wet flue gas desulfurization (FGD) in series. During the course of coal stream, the samples, such as coal, bottom ash, fly ash, gypsum and flue gas, were collected. The Hg concentrations in coals were measured by CVAAS after appropriate preparation and acid digestion. Other solid samples were measured by the RA-915+ Zeeman Mercury Spectrometer. The vapor phase Hg was collected by a sorbent trap from flue gas and then measured using CVAAS followed by acid leaching. The mercury mass balances were estimated in this study were 91.6%, 77.1%, 118% and 85.8% for the four power plants, respectively. The total Hg concentrations in the stack gas were ranged from 1.56-5.95 microg/m3. The relative distribution of Hg in bottom ash, ESP, WFGD and stack discharged were ranged between 0.110%-2.50%, 2.17%-23.4%, 2.21%-87.1%, and 21.8%-72.7%, respectively. The distribution profiles were varied with the coal type and the operation conditions. The Hg in flue gas could be removed by ESP and FGD systems with an average removal efficiency of 51.8%. The calculated average emission factor was 0.066 g/ton and much lower than the results obtained ten years ago.

  15. Mercury emission and speciation of coal-fired power plants in China

    NASA Astrophysics Data System (ADS)

    Wang, S.; Zhang, L.; Li, G.; Wu, Y.; Hao, J.; Pirrone, N.; Sprovieri, F.; Ancora, M. P.

    2009-11-01

    Comprehensive field measurements are needed to understand the mercury emissions from Chinese power plants and to improve the accuracy of emission inventories. Characterization of mercury emissions and their behavior were measured in six typical coal-fired power plants in China. During the tests, the flue gas was sampled simultaneously at inlet and outlet of selective catalyst reduction (SCR), electrostatic precipitators (ESP), and flue gas desulfurization (FGD) using the Ontario Hydro Method (OHM). The pulverized coal, bottom ash, fly ash and gypsum were also sampled in the field. Mercury concentrations in coal burned in the measured power plants ranged from 17 to 385 μg/kg. The mercury mass balances for the six power plants varied from 87 to 116% of the input coal mercury for the whole system. The total mercury concentrations in the flue gas from boilers were at the range of 1.92-27.15 μg/m3, which were significantly related to the mercury contents in burned coal. The mercury speciation in flue gas right after the boiler is influenced by the contents of halogen, mercury, and ash in the burned coal. The average mercury removal efficiencies of ESP, ESP plus wet FGD, and ESP plus dry FGD-FF systems were 24%, 73% and 66%, respectively, which were similar to the average removal efficiencies of pollution control device systems in other countries such as US, Japan and South Korea. The SCR system oxidized 16% elemental mercury and reduced about 32% of total mercury. Elemental mercury, accounting for 66-94% of total mercury, was the dominant species emitted to the atmosphere. The mercury emission factor was also calculated for each power plant.

  16. Aged particles derived from emissions of coal-fired power plants: the TERESA field results.

    PubMed

    Kang, Choong-Min; Gupta, Tarun; Ruiz, Pablo A; Wolfson, Jack M; Ferguson, Stephen T; Lawrence, Joy E; Rohr, Annette C; Godleski, John; Koutrakis, Petros

    2011-08-01

    The Toxicological Evaluation of Realistic Emissions Source Aerosols (TERESA) study was carried out at three US coal-fired power plants to investigate the potential toxicological effects of primary and photochemically aged (secondary) particles using in situ stack emissions. The exposure system designed successfully simulated chemical reactions that power plant emissions undergo in a plume during transport from the stack to receptor areas (e.g., urban areas). Test atmospheres developed for toxicological experiments included scenarios to simulate a sequence of atmospheric reactions that can occur in a plume: (1) primary emissions only; (2) H(2)SO(4) aerosol from oxidation of SO(2); (3) H(2)SO(4) aerosol neutralized by gas-phase NH(3); (4) neutralized H(2)SO(4) with secondary organic aerosol (SOA) formed by the reaction of α-pinene with O(3); and (5) three control scenarios excluding primary particles. The aged particle mass concentrations varied significantly from 43.8 to 257.1 µg/m(3) with respect to scenario and power plant. The highest was found when oxidized aerosols were neutralized by gas-phase NH(3) with added SOA. The mass concentration depended primarily on the ratio of SO(2) to NO(x) (particularly NO) emissions, which was determined mainly by coal composition and emissions controls. Particulate sulfate (H(2)SO(4) + neutralized sulfate) and organic carbon (OC) were major components of the aged particles with added SOA, whereas trace elements were present at very low concentrations. Physical and chemical properties of aged particles appear to be influenced by coal type, emissions controls and the particular atmospheric scenarios employed.

  17. Ground Penetrating Radar, a Method for Exploration and Monitoring of Coal Fires in China

    NASA Astrophysics Data System (ADS)

    Gundelach, Volker

    2010-05-01

    Due to the climate change it is a global task to fight against gas emission of coal fires. In China exists many burning coal seams which should be extinguished. A Chinese-German initiative tries to find new technologies and solutions to control these fires. Most of the fires are close to the surface in arid areas. In that case GPR is a possible geophysical method to get detailed information about the structure of the soil. Mining activities and the burning coal are leaving voids which collapse or still exist as dangerous areas. With GPR it is possible to detect voids and clefts. Crevices are potential paths for oxygen transport from the surface to the fire. The knowledge of these structures would help to extinguish the fire. The heat of the burning coal changes the permittivity and the conductivity of the rock. This affects the radar signal and makes it possible to separate burning zones from intact zones. Monitoring of the burning zones helps to find optimal solutions for fire extinguishing strategies. Several field campaigns were made in China. One campaign was in the province Xinjiang with a 50 MHz system from Mala on a steep dipping coal seam. Other campaigns were in the Inner Mongolia with 40 MHz to 200 MHz antennae from GSSI on shallow dipping coal seams. The experiences from these measurements will be shown. The surveys were collected in rough terrain. The data from the unshielded antennae contained a lot of effects coming through the air. The limits of detecting crevices with GPR will be demonstrated. Some parts of the measurements over burning coal were influenced by strong anomalies of the magnetization. Modeling of the radar signal helps at the interpretation. Parts of the interpretation from the surveys can be validated by the outcrop of the investigated structures. A spatial visualization of the results is the basis for discussions.

  18. Rocket-Based Combined-Cycle (RBCC) Propulsion Technology Workshop. Tutorial session

    NASA Technical Reports Server (NTRS)

    1992-01-01

    The goal of this workshop was to illuminate the nation's space transportation and propulsion engineering community on the potential of hypersonic combined cycle (airbreathing/rocket) propulsion systems for future space transportation applications. Four general topics were examined: (1) selections from the expansive advanced propulsion archival resource; (2) related propulsion systems technical backgrounds; (3) RBCC engine multimode operations related subsystem background; and (4) focused review of propulsion aspects of current related programs.

  19. Combined cycle phosphoric acid fuel cell electric power system

    SciTech Connect

    Mollot, D.J.; Micheli, P.L.

    1995-12-31

    By arranging two or more electric power generation cycles in series, combined cycle systems are able to produce electric power more efficiently than conventional single cycle plants. The high fuel to electricity conversion efficiency results in lower plant operating costs, better environmental performance, and in some cases even lower capital costs. Despite these advantages, combined cycle systems for the 1 - 10 megawatt (MW) industrial market are rare. This paper presents a low noise, low (oxides of nitrogen) NOx, combined cycle alternative for the small industrial user. By combining a commercially available phosphoric acid fuel cell (PAFC) with a low-temperature Rankine cycle (similar to those used in geothermal applications), electric conversion efficiencies between 45 and 47 percent are predicted. While the simple cycle PAFC is competitive on a cost of energy basis with gas turbines and diesel generators in the 1 to 2 MW market, the combined cycle PAFC is competitive, on a cost of energy basis, with simple cycle diesel generators in the 4 to 25 MW market. In addition, the efficiency and low-temperature operation of the combined cycle PAFC results in a significant reduction in carbon dioxide emissions with NO{sub x} concentration on the order of 1 parts per million (per weight) (ppmw).

  20. Analysis and discussion on formation and control of primary particulate matter generated from coal-fired power plants.

    PubMed

    Lu, Jianyi; Ren, Xudan

    2014-12-01

    Particulate matter (PM) has been becoming the principal urban pollutant in many major cities in China, and even all over the world. It is reported that the coal combustion process is one of the main sources of PM in the atmosphere. Therefore, an investigation of formation and emission of fine primary PM in coal combustion was conducted. First, the sources and classification of coal-fired primary PM were discussed; then their formation pathways during the coal combustion process were analyzed in detail. Accordingly, the emission control methods for fine particles generated from coal-fired power plants were put forward, and were classified as precombustion control, in-combustion control, and postcombustion control. Precombustion control refers to the processes for improving the coal quality before combustion, such as coal type selection and coal preparation. In-combustion control means to take measures for adjusting the combustion conditions and injection of additives during the combustion process to abate the formation of PM. Postcombustion control is the way that the fine PM are aggregated into larger ones by some agglomeration approaches and subsequently are removed by dust removal devices, or some high-performance modifications of conventional particle emission control devices (PECDs) can be taken for capturing fine particles. Finally, some general management suggestions are given for reducing fine PM emission in coal-fired power plants. Implications: The analysis and discussions of coal properties and its combustion process are critical to recognizing the formation and emission of the fine primary PM in combustion. The measures of precombustion, in-combustion, and postcombustion control based on the analysis and discussions are favorable for abating the PM emission. Practically, some measures of implementation do need the support of national policies, even needing to sacrifice economy to gain environmental profit, but this is the very time to execute these, and

  1. As, Hg, and Se flue gas sampling in a coal-fired power plant and their fate during coal combustion.

    PubMed

    Otero-Rey, José R; López-Vilariño, José M; Moreda-Piñeiro, Jorge; Alonso-Rodríguez, Elia; Muniategui-Lorenzo, Soledad; López-Mahía, Purificación; Prada-Rodríguez, Darío

    2003-11-15

    As, Hg, and Se are the most volatile elements in the flue gas from a coal-fired power plant. Significant amounts of these elements cause an undesired direct gaseous emission, which leads to a serious environmental health risk. The main focus of this study is to evaluate the possibility of simultaneous sampling of these volatile elements using an accurate official method for Hg (the most volatile element). A study of As, Hg, and Se emissions from a 1400 MW coal-fired power plant equipped with electrostatic precipitators (ESPs) was carried out for the combustion of a mixture of two types of coal. Simultaneous sampling of coal, bottom ash, fly ash, flue gas, and particles associated with the gas phase has been performed. Flue gas has been sampled by the Ontario Hydro Method Sampling Train, an ASTM method for Hg speciation. This sampling method was tested for As and Se sampling. As and Se determinations have been performed by HG-AAS, and Hg has been determined by CV-AAS. The results were used to examine the following: overall mass balances, relative distribution of these elements in the coal-fired power plant; As, Hg, and Se concentrations in coal and combustion residues; and predominant oxidation state for Hg in flue gas. The mass balances obtained for As, Hg, and Se were satisfactory in all cases; nevertheless, relative enrichment values in fly ash for As and Se were low; therefore, we concluded that As sampling in flue gas can be conducted by application of the Ontario Hydro Method; nevertheless Se released in the gas phase is not completely collected by this sampling train. Application of this sampling method allowed for performance of Hg speciation. The results indicated that Hg(II) was the predominant species in flue gas. It has also been proved that 24%, more than 99.8%, and 90% for As, Hg, and Se in the stack emissions, respectively, were in the gaseous phase.

  2. Behavior of fluorine and chlorine in Spanish coal fired power plants with pulverized coal boilers and fluidized bed boiler.

    PubMed

    López-Vilariño, J M; Fernández-Martínez, G; Turnes-Carou, I; Muinategui-Lorenzo, S; López-Mahía, P; Prada-Rodríguez, D

    2003-06-01

    Behavior and contents of fluorine and chlorine in coal feedstock, combustion wastes (slag and fly ash) and emissions were studied in five conventional coal fired power plants and in a fluidized bed coal power plant. The halide levels found in the used coal were quite low. Mass balances and emission factors were calculated. The volatility of these elements makes the gaseous emission the main target between the residues. The influence of combustion parameters is not clearly established. Several analytical techniques (ion selective electrodes, capillary electrophoresis and ion chromatography) are employed to determinate the halide concentration in the different samples taken in the power plants studied (coal, slag, fly ash and flue gases).

  3. Nuclear techniques for the on-line bulk analysis of carbon in coal-fired power stations.

    PubMed

    Sowerby, B D

    2009-09-01

    Carbon trading schemes usually require large emitters of CO(2), such as coal-fired power stations, to monitor, report and be audited on their CO(2) emissions. The emission price provides a significant additional incentive for power stations to improve efficiency. In the present paper, previous work on the bulk determination of carbon in coal is reviewed and assessed. The most favourable method is that based on neutron inelastic scattering. The potential role of on-line carbon analysers in improving boiler efficiency and in carbon accounting is discussed.

  4. Economic comparison of fabric filters and electrostatic precipitators for particulate control on coal-fired utility boilers

    NASA Technical Reports Server (NTRS)

    Cukor, P. M.; Chapman, R. A.

    1978-01-01

    The uncertainties and associated costs involved in selecting and designing a particulate control device to meet California's air emission regulations are considered. The basic operating principles of electrostatic precipitators and fabric filters are discussed, and design parameters are identified. The size and resulting cost of the control device as a function of design parameters is illustrated by a case study for an 800 MW coal-fired fired utility boiler burning a typical southwestern subbituminous coal. The cost of selecting an undersized particulate control device is compared with the cost of selecting an oversized device.

  5. 300 MW combined-cycle plant with integrated coal gasification

    SciTech Connect

    Kehlhofer, R.H.

    1984-09-01

    The main obstacle to further expansion of the combined cycle principle is its lack of fuel flexibility. To this day, gas turbines are still limited to gaseous or liquid fuels. This paper shows a viable way to add a cheap solid fuel, coal, to the list. The plant system in question is a 2 X 150 MW combined-cycle plant of BBC Brown Boveri with integrated coal gasification plant of British Gas/Lurgi. The main point of interest is that All the individual components of the power plant described in this paper have proven their worth commercially. It is therefore not a pilot plant but a viable commercial proposition.

  6. Ramjet-Mode Operation in a Combined Cycle Engine Combustor

    NASA Astrophysics Data System (ADS)

    Kato, Kanenori; Kudo, Kenji; Murakami, Atsuo; Tani, Kouichiro; Kanda, Takeshi

    A rocket-ramjet combined-cycle engine was tested in ramjet-mode. The combustor model had two rockets in the combustor section. They were used as an igniter in this operation mode. In the preliminary tests, the downstream combustion ramjet-mode was demonstrated with a 1.4-degree of divergent duct condition. In this study, the upstream and downstream combustion ramjet-mode operations were applied to the combined cycle engine model with large angle of divergent duct condition. In the case of upstream combustion ramjet-mode, the combustion condition at the exit of the combustor showed high combustion efficiency.

  7. 78 FR 43870 - Hydrogen Energy California's Integrated Gasification Combined Cycle Project; Preliminary Staff...

    Federal Register 2010, 2011, 2012, 2013, 2014

    2013-07-22

    ... of Availability Hydrogen Energy California's Integrated Gasification Combined Cycle Project... availability of the Hydrogen Energy California's Integrated Gasification Combined Cycle Project Preliminary... the Hydrogen Energy California's (HECA) Integrated Gasification Combined Cycle Project, which would...

  8. COSTEAM expansion and improvements: design of a coal-fired atmospheric fluidized bed submodel, an oil-fired submodel and input/output improvements

    SciTech Connect

    Reierson, James D.; Rosenberg, Joseph I.; Murphy, Mary B.; Lethi, Minh- Triet

    1980-10-01

    COSTEAM is an interactive computer model designed to estimate the cost of industrial steam produced by various steam plant technologies. At the end of Phase I development, the COSTEAM model included only one submodel to calculate the capital and operating costs of a conventional coal-fired boiler plant with environmental control systems. This report describes the results of Phase II development. Two new submodels are added which calculate costs for steam produced by coal-fired atmospheric fluidized bed boilers and by oil-fired boilers. COSTEAM input/output capabilities are also improved.

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

    SciTech Connect

    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.

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

    SciTech Connect

    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.

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

    SciTech Connect

    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.

  12. Effects of coal-fired thermal power plant discharges on agricultural soil and crop plants.

    PubMed

    Ajmal, M; Khan, M A

    1986-04-01

    The physicochemical properties of the upstream and downstream waters from the Upper Ganga canal, discharged cooling tower water, machine washings, and scrubber and bottom ash effluents of a 530 MW Kasimpur coal-fired thermal power plant have been determined, and their effects directly on fertile soil and indirectly on pea (Pisum sativam) and wheat (Triticum aestivum) crops have also been studied. The effluents were found to be alkaline in nature. The scrubber and bottom ash effluent was found to contain large amounts of solids and had high biochemical and chemical oxygen demands. All the effluents were found to be responsible for altering the chemical composition of the soil. The soils irrigated with the different effluents exhibited an increase in pH, organic matter, calcium carbonate, water-soluble salts, cation exchange capacity, electrical conductivity, and nitrogen and phosphorus contents while potassium content decreased, probably due to being leached to the lower layers of the soil. The effects of 100, 50, and 0% (tap water control) dilutions of cooling tower, machine washings, and scrubber and bottom ash effluents on the germination and growth of pea and wheat crops were also monitored. Using the undiluted effluents, there was 100% germination for both the crops when the irrigation was done with cooling tower effluent. The germination was restricted to 90% for the two crops when irrigated with machine washings effluent, and to 80 and 70% for pea and wheat, respectively, when irrigated with scrubber and bottom ash effluent. The samples of upstream and downstream canal water were also used for irrigating soils with and without crop plants in order to ascertain the impact of the effluents on the canal water and its subsequent effect on the crops. The soils irrigated with downstream canal water were found to contain slightly more calcium carbonate, phosphorus, and ammonia-nitrogen than those receiving upstream canal water. Though 100% germination was obtained

  13. The ADESORB Process for Economical Production of Sorbents for Mercury Removal from Coal Fired Power Plants

    SciTech Connect

    Robin Stewart

    2008-03-12

    The DOE's National Energy Technology Laboratory (NETL) currently manages the largest research program in the country for controlling coal-based mercury emissions. NETL has shown through various field test programs that the determination of cost-effective mercury control strategies is complex and highly coal- and plant-specific. However, one particular technology has the potential for widespread application: the injection of activated carbon upstream of either an electrostatic precipitator (ESP) or a fabric filter baghouse. This technology has potential application to the control of mercury emissions on all coal-fired power plants, even those with wet and dry scrubbers. This is a low capital cost technology in which the largest cost element is the cost of sorbents. Therefore, the obvious solutions for reducing the costs of mercury control must focus on either reducing the amount of sorbent needed or decreasing the cost of sorbent production. NETL has researched the economics and performance of novel sorbents and determined that there are alternatives to the commercial standard (NORIT DARCO{reg_sign} Hg) and that this is an area where significant technical improvements can still be made. In addition, a key barrier to the application of sorbent injection technology to the power industry is the availability of activated carbon production. Currently, about 450 million pounds ($250 million per year) of activated carbon is produced and used in the U.S. each year - primarily for purification of drinking water, food, and beverages. If activated carbon technology were to be applied to all 1,100 power plants, EPA and DOE estimate that it would require an additional $1-$2 billion per year, which would require increasing current capacity by a factor of two to eight. A new facility to produce activated carbon would cost approximately $250 million, would increase current U.S. production by nearly 25%, and could take four to five years to build. This means that there could be

  14. Health risk assessment of toxic VOCs species for the coal fire well drillers.

    PubMed

    Yan, Yulong; Peng, Lin; Cheng, Na; Bai, Huiling; Mu, Ling

    2015-10-01

    In this study, the health risk of toxic volatile organic compounds (VOCs) species for well drillers, working at an exposure site around a well of underground coal fire site, was presented in a case of Shanxi province. The samples were collected by Teflon sampling bags and measured by gas chromatography-mass spectrometry (GC-MS). The results showed that isopropyl alcohol was the most abundant compound of VOCs, with the geometric mean concentrations of 1700.38 μg/m(3). The geometric mean concentrations of individual BTEX compounds obtained in all of the sampling campaign were 131.64, 10.15, 15.53, and 25.38 μg/m(3) for benzene, toluene, ethyl-benzene, and xylenes, respectively. Relative proportion of BTEX averaged as 8.5:0.7:1:1.6. High B/T ratio (13.0) and low T/E ratio (0.7) was observed in this study. For non-cancer risk in this study, the hazardous quotient (HQ) of 1,2-dibromoethane, 1,3-butadiene, and benzene was 17.91, 1.71, and 43.88, respectively, mean their non-cancer risk was at the level of definite concern. The HQ sum of 20 VOCs was 64.94, much higher than 1. The cancer risk values of benzene (7.01E-04), 1,2-dibromoethane (1.91E-04), carbon tetrachloride (1.55E-04), and 1,3-butadiene (1.09E-04) were greater than 10(-4), indicating that they were all definite risk. The total cancer risk of all VOCs species was 1.39E-03, almost 14 times more than the level of definite risk. The stochastic exposure assessment of all VOCs species total cancer risk using the Monte Carlo simulation analysis shows that 5 and 95 % cancer risks were predicted to be 7.60E-04 and 2.75E-03, respectively. The cancer risk for all VOCs species is unacceptable. The results of sensitivity analysis show that benzene, carbon tetrachloride, and 1,3-butadiene exposure account for more than 98 % contributions to the estimated risk for drillers, indicating that those VOCs species exposure has greater impact than other species on risk assessment. Both combined effects and independent effects

  15. Review of the coal-fired, over-supercritical and ultra-supercritical steam power plants

    NASA Astrophysics Data System (ADS)

    Tumanovskii, A. G.; Shvarts, A. L.; Somova, E. V.; Verbovetskii, E. Kh.; Avrutskii, G. D.; Ermakova, S. V.; Kalugin, R. N.; Lazarev, M. V.

    2017-02-01

    The article presents a review of developments of modern high-capacity coal-fired over-supercritical (OSC) and ultra-supercritical (USC) steam power plants and their implementation. The basic engineering solutions are reported that ensure the reliability, economic performance, and low atmospheric pollution levels. The net efficiency of the power plants is increased by optimizing the heat balance, improving the primary and auxiliary equipment, and, which is the main thing, by increasing the throttle conditions. As a result of the enhanced efficiency, emissions of hazardous substances into the atmosphere, including carbon dioxide, the "greenhouse" gas, are reduced. To date, the exhaust steam conditions in the world power industry are p 0 ≈ 30 MPa and t 0 = 610/620°C. The efficiency of such power plants reaches 47%. The OSC plants are being operated in Germany, Denmark, Japan, China, and Korea; pilot plants are being developed in Russia. Currently, a project of a power plant for the ultra-supercritical steam conditions p 0 ≈ 35 MPa and t 0 = 700/720°C with efficiency of approximately 50% is being studied in the EU within the framework of the Thermie AD700 program, project AD 700PF. Investigations in this field have also been launched in the United States, Japan, and China. Engineering solutions are also being sought in Russia by the All-Russia Thermal Engineering Research Institute (VTI) and the Moscow Power Engineering Institute. The stated steam parameter level necessitates application of new materials, namely, nickel-base alloys. Taking into consideration high costs of nickel-base alloys and the absence in Russia of technologies for their production and manufacture of products from these materials for steam-turbine power plants, the development of power plants for steam parameters of 32 MPa and 650/650°C should be considered to be the first stage in creating the USC plants as, to achieve the above parameters, no expensive alloys are require. To develop and

  16. Power Gas and Combined Cycles: Clean Power From Fossil Fuels

    ERIC Educational Resources Information Center

    Metz, William D.

    1973-01-01

    The combined-cycle system is currently regarded as a useful procedure for producing electricity. This system can burn natural gas and oil distillates in addition to coal. In the future when natural gas stocks will be low, coal may become an important fuel for such systems. Considerable effort must be made for research on coal gasification and…

  17. TECHNOECONOMIC APPRAISAL OF INTEGRATED GASIFICATION COMBINED-CYCLE POWER GENERATION

    EPA Science Inventory

    The report is a technoeconomic appraisal of the integrated (coal) gasification combined-cycle (IGCC) system. lthough not yet a proven commercial technology, IGCC is a future competitive technology to current pulverized-coal boilers equipped with SO2 and NOx controls, because of i...

  18. Atmospheric emissions estimation of Hg, As, and Se from coal-fired power plants in China, 2007.

    PubMed

    Tian, Hezhong; Wang, Yan; Xue, Zhigang; Qu, Yiping; Chai, Fahe; Hao, Jiming

    2011-07-15

    Over half of coal in China is burned directly by power plants, becoming an important source of hazardous trace element emissions, such as mercury (Hg), arsenic (As), and selenium (Se), etc. Based on coal consumption by each power plant, emission factors classified by different boiler patterns and air pollution control devices configuration, atmospheric emissions of Hg, As, and Se from coal-fired power plants in China are evaluated. The national total emissions of Hg, As, and Se from coal-fired power plants in 2007 are calculated at 132 t, 550 t, and 787 t, respectively. Furthermore, according to the percentage of coal consumed by units equipped with different types of PM devices and FGD systems, speciation of mercury is estimated as follows: 80.48 t of Hg, 49.98 t of Hg(2+), and 1.89 t of Hg(P), representing 60.81%, 37.76%, and 1.43% of the totals, respectively. The emissions of Hg, As, and Se in China's eastern and central provinces are much higher than those in the west, except for provinces involved in the program of electricity transmission from west to east China, such as Sichuan, Guizhou, Yunnan, Shaanxi, etc.

  19. Near-term implications of a ban on new coal-fired power plants in the United States.

    PubMed

    Newcomer, Adam; Apt, Jay

    2009-06-01

    Large numbers of proposed new coal power generators in the United States have been canceled, and some states have prohibited new coal power generators. We examine the effects on the U.S. electric power system of banning the construction of coal-fired electricity generators, which has been proposed as a means to reduce U.S. CO2 emissions. The model simulates load growth, resource planning, and economic dispatch of the Midwest Independent Transmission System Operator (ISO), Inc., Electric Reliability Council of Texas (ERCOT), and PJM under a ban on new coal generation and uses an economic dispatch model to calculate the resulting changes in dispatch order, CO2 emissions, and fuel use under three near-term (until 2030) future electric power sector scenarios. A national ban on new coal-fired power plants does not lead to CO2 reductions of the scale required under proposed federal legislation such as Lieberman-Warner but would greatly increase the fraction of time when natural gas sets the price of electricity, even with aggressive wind and demand response policies.

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

    SciTech Connect

    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.

  1. Estimating the effect of air pollution from a coal-fired power station on the development of children's pulmonary function.

    PubMed

    Dubnov, Jonathan; Barchana, Micha; Rishpon, Shmuel; Leventhal, Alex; Segal, Isaac; Carel, Rafael; Portnov, Boris A

    2007-01-01

    Using geographical information systems (GIS) tools, the present study analyzed the association between children's lung function development and their long-term exposure to air pollution. The study covered the cohort of 1492 schoolchildren living in the vicinity of a major coal-fired power station in the Hadera sub-district of Israel. In 1996 and 1999, the children underwent subsequent pulmonary function tests (PFT) (forced vital capacity (FVC) and forced expiratory volume during the first second (FEV(1))), and the children's parents completed a detailed questionnaire on their health status and household characteristics. A negative association was found between changes in the results of PFT and the estimated individual levels of air pollution. A sensitivity test revealed a FEV(1) decline from -4.3% for the average pollution level to -10.2% for the high air pollution level. The results of a sensitivity test for FVC were found to be similar. Association with the reported health status was found to be insignificant. As we conclude, air pollution from a coal-fired power station, although not exceeding local pollution standards, had a negative effect on children's lung function development. As argued, previous studies carried out in the region failed to show the above association because they were based on zone approaches that assign average concentration levels of air pollutants to all individuals in each zone, leading to a misclassification bias of individual exposure.

  2. Nitrogen isotopic composition of coal-fired power plant NOx: influence of emission controls and implications for global emission inventories.

    PubMed

    Felix, J David; Elliott, Emily M; Shaw, Stephanie L

    2012-03-20

    Despite the potential use of δ(15)N as a tracer of NO(x) source contributions, prior documentation of δ(15)N of various NO(x) emission sources is exceedingly limited. This manuscript presents the first measurements of the nitrogen isotopic composition of NO(x) (δ(15)N-NO(x)) emitted from coal-fired power plants in the U.S. at typical operating conditions with and without the presence of selective catalytic reduction (SCR) and selective noncatalytic reduction (SNCR) technology. To accomplish this, a novel method for collection and isotopic analysis of coal-fired stack NO(x) emission samples was developed based on modifications of a historic U.S. EPA stack sampling method. At the power plants included in this study, large differences exist in the isotopic composition of NO(x) emitted with and without SCRs and SNCRs; further the isotopic composition of power plant NO(x) is higher than that of other measured NO(x) emission sources confirming its use as an environmental tracer. These findings indicate that gradual implementation of SCRs at power plants will result in an industry-wide increase in δ(15)N values of NO(x) and NO(y) oxidation products from this emission source.

  3. Design and implementation of a pulverised coal flow monitoring system for coal-fired power plant applications

    NASA Astrophysics Data System (ADS)

    Qian, Xiangchen; Hu, Yonghui; Huang, Xiaobin; Yan, Yong

    2014-04-01

    On-line continuous monitoring of pulverised coal in fuel injection pipelines will allow power plant operators to understand fuel conveying conditions and ultimately to achieve higher combustion efficiency and lower pollutant emissions. This paper presents the design, implementation and trials of an instrumentation system for on-line non-intrusive measurement of pulverised coal in a power plant environment. An array of three identical electrostatic electrodes is housed in a sensing head to determine multiple measurement results from different electrode pairs. Flow parameters such as flow velocity, relative mass flow rate and fuel distribution between injection pipes can be obtained by fusing the multiple results. On-plant trials on 488 mm bore pneumatic conveying pipelines at a 600 MW coal-fired power plant were undertaken following preliminary system evaluation tests on a 50 mm bore laboratory test rig. Experimental results demonstrate that monitoring of pulverised coal flow is achieved using the developed instrumentation system under real industrial conditions. The developed technology is likely to find immediate applications, leading to improved performance of coal-fired power plants, efficient use of fuel, and subsequent reductions in emissions.

  4. Assessment of pulverized-coal-fired combustion performance: Final report for the period September 1980--September 1983

    SciTech Connect

    Richter, W.F.; Clark, W.; Pohl, J.H.; Payne, R.

    1987-06-01

    The purpose of this program was to evaluate an engineering analysis procedure which could be used to assess the impact on thermal performance of converting gas and oil fired equipment to coal. The program consisted of four major tasks: (1) Engineering Analysis. The objective was to evaluate currently available models which could be used to predict combustor performance and to define a procedure which could be used to assess the impact of a coal firing in a boiler or furnace; (2) Reactor Studies. The purpose was to evaluate, under controlled conditions, the radiative properties of fly ash clouds; (3) Pilot Scale Experiments. This involved a combustion trial with gas and coals which were burned at 0.7 /times/ 10/sup 6/ Btu/hr in a pilot-scale combustor. The purpose was to verify and supplement the results of the small-scale reactor studies on the radiant properties of coal flames at larger scale; (4) Reporting. Engineering analysis procedures were used to identify those fuels related properties which had a major impact on the thermal performance of furnaces. The major result of the study is that thermal performance of coal-fired furnaces is dominated by the formation of fly ash deposits on the heat transfer surfaces. The key parameters which influence thermal performance are: thickness, thermal conductivity, and surface emissivity or absorptivity. 105 refs., 170 figs., 29 tabs.

  5. Economic analysis of selective catalytic reduction applied to coal-fired boilers for NO{sub x} reduction

    SciTech Connect

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

    1997-12-31

    Selective Catalytic Reduction (SCR) technology is one of many compliance options electric utilities have at their disposal when considering reduction of nitrogen oxide (NO{sub x}) emissions at coal-fired power plants. This paper describes the results of an economic analysis that was completed as part of an Innovative Clean Coal Technology project, which demonstrated SCR technology for reduction of NO{sub x} emission from utility boilers burning high-sulfur coal. The project, conducted at Gulf Power Company`s Plant Crist Unit 5, was sponsored by the US Department of Energy, managed and cofunded by Southern Company Services, Inc., on behalf of Southern Company, and also cofunded by The Electric Power Research Institute and Ontario Hydro. The test program was conducted for approximately 2 years to evaluate catalyst deactivation and to quantify operational impacts of SCR technology employed in a high-sulfur environment. Measured data and operational lessons learned at the test facility form the basis of the technical premises and economic analysis. Capital and O and M costs were prepared for commercial-scale new and retrofit applications of SCR technology. Additionally, the results of the economic analysis presented in this paper are enhanced by incorporating current market trends based on US coal-fired SCR installations.

  6. Acidity of vapor plume from cooling tower mixed with flue gases emitted from coal-fired power plant.

    PubMed

    Hlawiczka, Stanislaw; Korszun, Katarzyna; Fudala, Janina

    2016-06-01

    Acidity of products resulting from the reaction of flue gas components emitted from a coal-fired power plant with water contained in a vapor plume from a wet cooling tower was analyzed in a close vicinity of a power plant (710 m from the stack and 315 m from the cooling tower). Samples of this mixture were collected using a precipitation funnel where components of the mixed plumes were discharged from the atmosphere with the rainfall. To identify situations when the precipitation occurred at the same time as the wind directed the mixed vapor and flue gas plumes above the precipitation funnel, an ultrasound anemometer designed for 3D measurements of the wind field located near the funnel was used. Precipitation samples of extremely high acidity were identified - about 5% of samples collected during 12 months showed the acidity below pH=3 and the lowest recorded pH was 1.4. During the measurement period the value of pH characterizing the background acidity of the precipitation was about 6. The main outcome of this study was to demonstrate a very high, and so far completely underestimated, potential of occurrence of episodes of extremely acid depositions in the immediate vicinity of a coal-fired power plant.

  7. Viability of Carbon Capture and Sequestration Retrofits for Existing Coal-Fired Power Plants under an Emission Trading Scheme.

    PubMed

    Talati, Shuchi; Zhai, Haibo; Morgan, M Granger

    2016-12-06

    Using data on the coal-fired electric generating units (EGUs) in Texas we assess the economic feasibility of retrofitting existing units with carbon capture and sequestration (CCS) in order to comply with the Clean Power Plan's rate-based emission standards under an emission trading scheme. CCS with 90% capture is shown to be more economically attractive for a range of existing units than purchasing emission rate credits (ERCs) from a trading market at an average credit price above $28 per MWh under the final state standard and $35 per MWh under the final national standard. The breakeven ERC trading prices would decrease significantly if the captured CO2 were sold for use in enhanced oil recovery, making CCS retrofits viable at lower trading prices. The combination of ERC trading and CO2 use can greatly reinforce economic incentives and market demands for CCS and hence accelerate large-scale deployment, even under scenarios with high retrofit costs. Comparing the levelized costs of electricity generation between CCS retrofits and new renewable plants under the ERC trading scheme, retrofitting coal-fired EGUs with CCS may be significantly cheaper than new solar plants under some market conditions.

  8. Near-term implications of a ban on new coal-fired power plants in the United States

    SciTech Connect

    Adam Newcomer; Jay Apt

    2009-06-15

    Large numbers of proposed new coal power generators in the United States have been cancelled, and some states have prohibited new coal power generators. We examine the effects on the U.S. electric power system of banning the construction of coal-fired electricity generators, which has been proposed as a means to reduce U.S. CO{sub 2} emissions. The model simulates load growth, resource planning, and economic dispatch of the Midwest Independent Transmission System Operator (ISO), Inc., Electric Reliability Council of Texas (ERCOT), and PJM under a ban on new coal generation and uses an economic dispatch model to calculate the resulting changes in dispatch order, CO{sub 2} emissions, and fuel use under three near-term (until 2030) future electric power sector scenarios. A national ban on new coal-fired power plants does not lead to CO{sub 2} reductions of the scale required under proposed federal legislation such as Lieberman-Warner but would greatly increase the fraction of time when natural gas sets the price of electricity, even with aggressive wind and demand response policies. 50 refs., 5 figs., 4 tabs.

  9. The relationship between chemical elements in soil and whole blood, and fluorosis induced by coal-fired pollution.

    PubMed

    Wang, Hao; Mu, Lihong; Jiang, Miao; Wang, Yingxiong; Yan, Wei; Jiao, Yongzhuo

    2014-04-01

    To study the relationship between chemical elements in soil and whole blood, and fluorosis induced by coal-fired pollution, ecological and case-control studies were carried out. We determined the concentrations of 11 chemical elements and pH values in soil in two fluorosis-affected counties in Chongqing, China, and analyzed the correlation between these values and prevalence of dental fluorosis. Ni, I, F, Hg, and pH values positively correlated with fluorosis prevalence (P < 0.05); these soil parameters may be related to coal-fired pollution fluorosis. Cu, Zn, Ca, Mg, and Fe concentrations in whole blood, and fluoride levels in urine of residents in epidemic and non-epidemic areas were determined. Cu, Zn, Mg, and Fe levels of the children in the case group were lower than those of the children in the external control group; urine fluoride level in the children in the case group was higher than that of the children in the internal and external control groups (P < 0.05). The levels of Mg, Fe, and urine fluoride were higher in the case adult group than in the internal adult control group (P < 0.05). Anti-fluoride elements were deficient in endemic areas.

  10. Development and testing of industrial scale, coal fired combustion system, Phase 3. Fourth quarterly technical progress report, October 1, 1992--December 31, 1992

    SciTech Connect

    Zauderer, B.

    1993-02-15

    A major part of the work in this quarter was on the combustor tests in task 2. Three of the six planned tests in this task were completed. The first two were parametric tests of nominal one shift, (8 hour) duration on coal. Due to failure of the UV detector in the first test only several hours of coal fired operation were completed. In the second test, coal fired operation continued for the planned one shift until the 4 ton coal bin was empty. After reviewing this work with DOE, it was decided to focus the remaining test on longer duration operation with each test at one optimum condition. The third test was planned for two shift coal fired operation. Due to a problem with the pilot gas ignitor, combustion was delayed by 5 hours from 7 AM to Noon. As a result coal fired operation was limited to one shift between 3 PM and 11 PM. Throughout this period the combustor remained at one fixed condition with the use of computer control. Results for these three tests are presented in this report. Most of the work on the task 4 design and cost of a 20 MW combined gas-steam turbine power plant using the air cooled combustor was completed in the previous quarter. The results obtained by the A/E subcontractor on the installation desip and cost were evaluated in the present quarter and they are summarized in this report.

  11. Engineering development of coal-fired high performance power systems, Phase II and Phase III. Quarter progress report, April 1, 1996--June 30, 1996

    SciTech Connect

    1996-11-01

    Work is presented on the development of a coal-fired high performance power generation system by the year 2000. This report describes the design of the air heater, duct heater, system controls, slag viscosity, and design of a quench zone.

  12. RETROFIT COSTS FOR SO2 AND NOX CONTROL OPTIONS AT 200 COAL-FIRED PLANTS, VOLUME II - SITE SPECIFIC STUDIES FOR AL, DE. FL, GA, IL

    EPA Science Inventory

    The report gives results of a study, the objective of which was to significantly improve engineering cost estimates currently being used to evaluate the economic effects of applying SO2 and NOx controls at 200 large SO2-emitting coal-fired utility plants. To accomplish the object...

  13. Ozone monitoring instrument observations of interannual increases in SO2 emissions from Indian coal-fired power plants during 2005-2012.

    PubMed

    Lu, Zifeng; Streets, David G; de Foy, Benjamin; Krotkov, Nickolay A

    2013-12-17

    Due to the rapid growth of electricity demand and the absence of regulations, sulfur dioxide (SO2) emissions from coal-fired power plants in India have increased notably in the past decade. In this study, we present the first interannual comparison of SO2 emissions and the satellite SO2 observations from the Ozone Monitoring Instrument (OMI) for Indian coal-fired power plants during the OMI era of 2005-2012. A detailed unit-based inventory is developed for the Indian coal-fired power sector, and results show that its SO2 emissions increased dramatically by 71% during 2005-2012. Using the oversampling technique, yearly high-resolution OMI maps for the whole domain of India are created, and they reveal a continuous increase in SO2 columns over India. Power plant regions with annual SO2 emissions greater than 50 Gg year(-1) produce statistically significant OMI signals, and a high correlation (R = 0.93) is found between SO2 emissions and OMI-observed SO2 burdens. Contrary to the decreasing trend of national mean SO2 concentrations reported by the Indian Government, both the total OMI-observed SO2 and annual average SO2 concentrations in coal-fired power plant regions increased by >60% during 2005-2012, implying the air quality monitoring network needs to be optimized to reflect the true SO2 situation in India.

  14. RETROFIT COSTS FOR SO2 AND NOX CONTROL OPTIONS AT 200 COAL-FIRED PLANTS, VOLUME III - SITE SPECIFIC STUDIES FOR IN, KY, MA, MD, MI, MN

    EPA Science Inventory

    The report gives results of a study, the objective of which was to significantly improve engineering cost estimates currently being used to evaluate the economic effects of applying SO2 and NOx controls at 200 large SO2-emitting coal-fired utility plants. To accomplish the object...

  15. RETROFIT COSTS FOR SO2 AND NOX CONTROL OPTIONS AT 200 COAL-FIRED PLANTS, VOLUME V - SITE SPECIFIC STUDIES FOR PA, SC, TN, VA, WI, WV

    EPA Science Inventory

    The report gives results of a study, the objective of which was to significantly improve engineering cost estimates currently being used to evaluate the economic effects of applying SO2 and NOx controls at 200 large SO2-emitting coal-fired utility plants. To accomplish the object...

  16. RETROFIT COSTS FOR SO2 AND NOX CONTROL OPTIONS AT 200 COAL-FIRED PLANTS, VOLUME IV - SITE SPECIFIC STUDIES FOR MO, MS, NC, NH, NJ, NY, OH

    EPA Science Inventory

    The report gives results of a study, the objective of which was to significantly improve engineering cost estimates currently being used to evaluate the economic effects of applying SO2 and NOx controls at 200 large SO2-emitting coal-fired utility plants. To accomplish the object...

  17. Behavior of Mercury Emissions from a Commercial Coal-Fired Utility Boiler: TheRelationship Between Stack Speciation and Near-Field Plume Measurements

    EPA Science Inventory

    The reduction of divalent gaseous mercury (HgII) to elemental gaseous mercury (Hg0) in a commercial coal-fired power plant (CFPP)exhaust plume was investigated by simultaneous measurement in-stack and in-plume as part of a collaborative study among the U.S....

  18. Ozone Monitoring Instrument Observations of Interannual Increases in SO2 Emissions from Indian Coal-fired Power Plants During 2005-2012

    NASA Technical Reports Server (NTRS)

    Lu, Zifeng; Streets, David D.; de Foy, Benjamin; Krotkov, Nickolay A.

    2014-01-01

    Due to the rapid growth of electricity demand and the absence of regulations, sulfur dioxide (SO2) emissions from coal-fired power plants in India have increased notably in the past decade. In this study, we present the first interannual comparison of SO2 emissions and the satellite SO2 observations from the Ozone Monitoring Instrument (OMI) for Indian coal-fired power plants during the OMI era of 2005-2012. A detailed unit-based inventory is developed for the Indian coal-fired power sector, and results show that its SO2 emissions increased dramatically by 71 percent during 2005-2012. Using the oversampling technique, yearly high-resolution OMI maps for the whole domain of India are created, and they reveal a continuous increase in SO2 columns over India. Power plant regions with annual SO2 emissions greater than 50 Gg year-1 produce statistically significant OMI signals, and a high correlation (R equals 0.93) is found between SO2 emissions and OMI-observed SO2 burdens. Contrary to the decreasing trend of national mean SO2 concentrations reported by the Indian Government, both the total OMI-observed SO2 and average SO2 concentrations in coal-fired power plant regions increased by greater than 60 percent during 2005-2012, implying the air quality monitoring network needs to be optimized to reflect the true SO2 situation in India.

  19. A study of toxic emissions from a coal-fired power plant utilizing an ESP/wet FGD system. Final report, Volume 2 of 2 - appendices

    SciTech Connect

    Not Available

    1994-07-01

    This volume contains the appendices for a coal-fired power plant toxic emissions study. Included are Process data log sheets from Coal Creek, Auditing information, Sampling protocol, Field sampling data sheets, Quality assurance/quality control, Analytical protocol, and Uncertainty analyses.

  20. Health and air quality benefits of policies to reduce coal-fired power plant emissions: a case study in North Carolina.

    PubMed

    Li, Ya-Ru; Gibson, Jacqueline MacDonald

    2014-09-02

    We analyzed sulfur dioxide (SO2) emissions and fine particulate sulfate (PM2.5 sulfate) concentrations in the southeastern United States during 2002-2012, in order to evaluate the health impacts in North Carolina (NC) of the NC Clean Smokestacks Act of 2002. This state law required progressive reductions (beyond those mandated by federal rules) in pollutant emissions from NC's coal-fired power plants. Although coal-fired power plants remain NC's leading SO2 source, a trend analysis shows significant declines in SO2 emissions (-20.3%/year) and PM2.5 sulfate concentrations (-8.7%/year) since passage of the act. Emissions reductions were significantly greater in NC than in neighboring states, and emissions and PM2.5 sulfate concentration reductions were highest in NC's piedmont region, where 9 of the state's 14 major coal-fired power plants are located. Our risk model estimates that these air quality improvements decreased the risk of premature death attributable to PM2.5 sulfate in NC by about 63%, resulting in an estimated 1700 (95% CI: 1500, 1800) deaths prevented in 2012. These findings lend support to recent studies predicting that implementing the proposed federal Cross-State Air Pollution Rule (recently upheld by the U.S. Supreme Court) could substantially decrease U.S. premature deaths attributable to coal-fired power plant emissions.