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1

CoalFleet RD&D augmentation plan for integrated gasification combined cycle (IGCC) power plants  

SciTech Connect (OSTI)

To help accelerate the development, demonstration, and market introduction of integrated gasification combined cycle (IGCC) and other clean coal technologies, EPRI formed the CoalFleet for Tomorrow initiative, which facilitates collaborative research by more than 50 organizations from around the world representing power generators, equipment suppliers and engineering design and construction firms, the U.S. Department of Energy, and others. This group advised EPRI as it evaluated more than 120 coal-gasification-related research projects worldwide to identify gaps or critical-path activities where additional resources and expertise could hasten the market introduction of IGCC advances. The resulting 'IGCC RD&D Augmentation Plan' describes such opportunities and how they could be addressed, for both IGCC plants to be built in the near term (by 2012-15) and over the longer term (2015-25), when demand for new electric generating capacity is expected to soar. For the near term, EPRI recommends 19 projects that could reduce the levelized cost-of-electricity for IGCC to the level of today's conventional pulverized-coal power plants with supercritical steam conditions and state-of-the-art environmental controls. For the long term, EPRI's recommended projects could reduce the levelized cost of an IGCC plant capturing 90% of the CO{sub 2} produced from the carbon in coal (for safe storage away from the atmosphere) to the level of today's IGCC plants without CO{sub 2} capture. EPRI's CoalFleet for Tomorrow program is also preparing a companion RD&D augmentation plan for advanced-combustion-based (i.e., non-gasification) clean coal technologies (Report 1013221). 7 refs., 30 figs., 29 tabs., 4 apps.

NONE

2007-01-15T23:59:59.000Z

2

Impact of coal quality and gasifier technology on IGCC performance  

E-Print Network [OSTI]

02139, USA Abstract Integrated coal gasification combined cycle (IGCC) plants withpre Plus and combined with GTPRO, mass and energy balances were computed. Two gasification technologies quality, efficiency Introduction Integrated coal gasification combined cycle (IGCC) has emerged

3

Mesaba next-generation IGCC plant  

SciTech Connect (OSTI)

Through a US Department of Energy (DOE) cooperative agreement awarded in June 2006, MEP-I LLC plans to demonstrate a next generation integrated gasification-combined cycle (IGCC) electric power generating plant, the Mesaba Energy Project. The 606-MWe plant (the first of two similarly sized plants envisioned by project sponsors) will feature next-generation ConocoPhillips E-Gas{trademark} technology first tested on the DOE-funded Wabash River Coal Gasification Repowering project. Mesaba will benefit from recommendations of an industry panel applying the Value Improving Practices process to Wabash cost and performance results. The project will be twice the size of Wabash, while demonstrating better efficient, reliability and pollutant control. The $2.16 billion project ($36 million federal cost share) will be located in the Iron Range region north of Duluth, Minnesota. Mesaba is one of four projects selected under Round II of the Clean Coal Power Initiative. 1 fig.

NONE

2006-01-01T23:59:59.000Z

4

Systems Study for Improving Gas Turbine Performance for Coal/IGCC Application  

SciTech Connect (OSTI)

This study identifies vital gas turbine (GT) parameters and quantifies their influence in meeting the DOE Turbine Program overall Integrated Gasification Combined Cycle (IGCC) plant goals of 50% net HHV efficiency, $1000/kW capital cost, and low emissions. The project analytically evaluates GE advanced F class air cooled technology level gas turbine conceptual cycle designs and determines their influence on IGCC plant level performance including impact of Carbon capture. This report summarizes the work accomplished in each of the following six Tasks. Task 1.0--Overall IGCC Plant Level Requirements Identification: Plant level requirements were identified, and compared with DOE's IGCC Goal of achieving 50% Net HHV Efficiency and $1000/KW by the Year 2008, through use of a Six Sigma Quality Functional Deployment (QFD) Tool. This analysis resulted in 7 GT System Level Parameters as the most significant. Task 2.0--Requirements Prioritization/Flow-Down to GT Subsystem Level: GT requirements were identified, analyzed and prioritized relative to achieving plant level goals, and compared with the flow down of power island goals through use of a Six Sigma QFD Tool. This analysis resulted in 11 GT Cycle Design Parameters being selected as the most significant. Task 3.0--IGCC Conceptual System Analysis: A Baseline IGCC Plant configuration was chosen, and an IGCC simulation analysis model was constructed, validated against published performance data and then optimized by including air extraction heat recovery and GE steam turbine model. Baseline IGCC based on GE 207FA+e gas turbine combined cycle has net HHV efficiency of 40.5% and net output nominally of 526 Megawatts at NOx emission level of 15 ppmvd{at}15% corrected O2. 18 advanced F technology GT cycle design options were developed to provide performance targets with increased output and/or efficiency with low NOx emissions. Task 4.0--Gas Turbine Cycle Options vs. Requirements Evaluation: Influence coefficients on 4 key IGCC plant level parameters (IGCC Net Efficiency, IGCC Net Output, GT Output, NOx Emissions) of 11 GT identified cycle parameters were determined. Results indicate that IGCC net efficiency HHV gains up to 2.8 pts (40.5% to 43.3%) and IGCC net output gains up to 35% are possible due to improvements in GT technology alone with single digit NOx emission levels. Task 5.0--Recommendations for GT Technical Improvements: A trade off analysis was conducted utilizing the performance results of 18 gas turbine (GT) conceptual designs, and three most promising GT candidates are recommended. A roadmap for turbine technology development is proposed for future coal based IGCC power plants. Task 6.0--Determine Carbon Capture Impact on IGCC Plant Level Performance: A gas turbine performance model for high Hydrogen fuel gas turbine was created and integrated to an IGCC system performance model, which also included newly created models for moisturized syngas, gas shift and CO2 removal subsystems. This performance model was analyzed for two gas turbine technology based subsystems each with two Carbon removal design options of 85% and 88% respectively. The results show larger IGCC performance penalty for gas turbine designs with higher firing temperature and higher Carbon removal.

Ashok K. Anand

2005-12-16T23:59:59.000Z

5

Hydrogen Production from Hydrogen Sulfide in IGCC Power Plants  

SciTech Connect (OSTI)

IGCC power plants are the cleanest coal-based power generation facilities in the world. Technical improvements are needed to help make them cost competitive. Sulfur recovery is one procedure in which improvement is possible. This project has developed and demonstrated an electrochemical process that could provide such an improvement. IGCC power plants now in operation extract the sulfur from the synthesis gas as hydrogen sulfide. In this project H{sub 2}S has been electrolyzed to yield sulfur and hydrogen (instead of sulfur and water as is the present practice). The value of the byproduct hydrogen makes this process more cost effective. The electrolysis has exploited some recent developments in solid state electrolytes. The proof of principal for the project concept has been accomplished.

Elias Stefanakos; Burton Krakow; Jonathan Mbah

2007-07-31T23:59:59.000Z

6

Clean coal technology using process integration : a focus on the IGCC.  

E-Print Network [OSTI]

?? The integrated gasification combined cycle (IGCC) is the most environmentally friendly coal-fired power generation technology that offers near zero green house gas emissions. This… (more)

Madzivhandila, Vhutshilo

2011-01-01T23:59:59.000Z

7

Advanced CO{sub 2} Capture Technology for Low Rank Coal IGCC System  

SciTech Connect (OSTI)

The overall objective of the project is to demonstrate the technical and economic viability of a new Integrated Gasification Combined Cycle (IGCC) power plant designed to efficiently process low rank coals. The plant uses an integrated CO{sub 2} scrubber/Water Gas Shift (WGS) catalyst to capture over90 percent capture of the CO{sub 2} emissions, while providing a significantly lower cost of electricity (COE) than a similar plant with conventional cold gas cleanup system based on SelexolTM technology and 90 percent carbon capture. TDA’s system uses a high temperature physical adsorbent capable of removing CO{sub 2} above the dew point of the synthesis gas and a commercial WGS catalyst that can effectively convert CO in The overall objective of the project is to demonstrate the technical and economic viability of a new Integrated Gasification Combined Cycle (IGCC) power plant designed to efficiently process low rank coals. The plant uses an integrated CO{sub 2} scrubber/Water Gas Shift (WGS) catalyst to capture over90 percent capture of the CO{sub 2} emissions, while providing a significantly lower cost of electricity (COE) than a similar plant with conventional cold gas cleanup system based on SelexolTM technology and 90 percent carbon capture. TDA’s system uses a high temperature physical adsorbent capable of removing CO{sub 2} above the dew point of the synthesis gas and a commercial WGS catalyst that can effectively convert CO in bituminous coal the net plant efficiency is about 2.4 percentage points higher than an Integrated Gasification Combined Cycle (IGCC) plant equipped with SelexolTM to capture CO{sub 2}. We also previously completed two successful field demonstrations: one at the National Carbon Capture Center (Southern- Wilsonville, AL) in 2011, and a second demonstration in fall of 2012 at the Wabash River IGCC plant (Terra Haute, IN). In this project, we first optimized the sorbent to catalyst ratio used in the combined WGS and CO{sub 2} capture process and confirmed the technical feasibility in bench-scale experiments. In these tests, we did not observe any CO breakthrough both during adsorption and desorption steps indicating that there is complete conversion of CO to CO{sub 2} and H{sub 2}. The overall CO conversions above 90 percent were observed. The sorbent achieved a total CO{sub 2} loading of 7.82 percent wt. of which 5.68 percent is from conversion of CO into CO{sub 2}. The results of the system analysis suggest that the TDA combined shift and high temperature PSA-based Warm Gas Clean-up technology can make a substantial improvement in the IGCC plant thermal performance for a plant designed to achieve near zero emissions (including greater than 90 percent carbon capture). The capital expenses are also expected to be lower than those of Selexol. The higher net plant efficiency and lower capital and operating costs result in substantial reduction in the COE for the IGCC plant equipped with the TDA combined shift and high temperature PSA-based carbon capture system.

Alptekin, Gokhan

2013-09-30T23:59:59.000Z

8

A Review of Hazardous Chemical Species Associated with CO2 Capture from Coal-Fired Power Plants and Their Potential Fate in CO2 Geologic Storage  

E-Print Network [OSTI]

favors IGCC technology over existing power plant designs (technologies either retrofitted to existing power plants, ortechnologies that could either be retrofitted to existing coal-fired power plants,

Apps, J.A.

2006-01-01T23:59:59.000Z

9

Plant-wide dynamic simulation of an IGCC plant with CO2 capture  

SciTech Connect (OSTI)

To eliminate the harmful effects of greenhouse gases, especially that of CO2, future coalfired power plants need to consider the option for CO2 capture. The loss in efficiency for CO2 capture is less in an Integrated Gasification Combined Cycle (IGCC) plant compared to other conventional coal combustion processes. 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. With this objective in mind, a detailed plant-wide dynamic simulation of an IGCC plant with CO2 capture has been developed. 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 about 96 mol% 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. The clean syngas is sent to a gas turbine (GT) followed by a heat recovery steam generator (HRSG). The steady state results are validated with data from a commercial gasifier. A 5 % ramp increase in the flowrate of coal is introduced to study the system dynamics. To control the conversion of CO at a desired level in the WGS reactors, the steam/CO ratio is manipulated. This strategy is found to be efficient for this operating condition. In the absence of an efficient control strategy in the AGR process, the environmental emissions exceeded the limits by a great extent.

Bhattacharyya, D.; Turton, R.; Zitney, S.

2009-01-01T23:59:59.000Z

10

Analysis of Biomass/Coal Co-Gasification for Integrated Gasification Combined Cycle (IGCC) Systems with Carbon Capture.  

E-Print Network [OSTI]

?? In recent years, Integrated Gasification Combined Cycle Technology (IGCC) has become more common in clean coal power operations with carbon capture and sequestration (CCS).… (more)

Long, Henry A, III

2011-01-01T23:59:59.000Z

11

Advanced Coal Wind Hybrid: Economic Analysis  

E-Print Network [OSTI]

farms with advanced coal generation facilities and operatingfarms with advanced coal generation facilities and operatingin the stand-alone coal generation option (IGCC+CCS plant)

Phadke, Amol

2008-01-01T23:59:59.000Z

12

Enabling Technology for Monitoring & Predicting Gas Turbine Health & Performance in COAL IGCC Powerplants  

SciTech Connect (OSTI)

The ''Enabling & Information Technology To Increase RAM for Advanced Powerplants'' program, by DOE request, has been re-directed, de-scoped to two tasks, shortened to a 2-year period of performance, and refocused to develop, validate and accelerate the commercial use of enabling materials technologies and sensors for Coal IGCC powerplants. The new program has been re-titled as ''Enabling Technology for Monitoring & Predicting Gas Turbine Health & Performance in IGCC Powerplants'' to better match the new scope. This technical progress report summarizes the work accomplished in the reporting period April 1, 2004 to August 31, 2004 on the revised Re-Directed and De-Scoped program activity. The program Tasks are: Task 1--IGCC Environmental Impact on high Temperature Materials: This first materials task has been refocused to address Coal IGCC environmental impacts on high temperature materials use in gas turbines and remains in the program. This task will screen material performance and quantify the effects of high temperature erosion and corrosion of hot gas path materials in Coal IGCC applications. The materials of interest will include those in current service as well as advanced, high-performance alloys and coatings. Task 2--Material In-Service Health Monitoring: This second task develops and demonstrates new sensor technologies to determine the in-service health of advanced technology Coal IGCC powerplants, and remains in the program with a reduced scope. Its focus is now on only two critical sensor need areas for advanced Coal IGCC gas turbines: (1) Fuel Quality Sensor for detection of fuel impurities that could lead to rapid component degradation, and a Fuel Heating Value Sensor to rapidly determine the fuel heating value for more precise control of the gas turbine, and (2) Infra-Red Pyrometer to continuously measure the temperature of gas turbine buckets, nozzles, and combustor hardware.

Kenneth A. Yackly

2004-09-30T23:59:59.000Z

13

CE IGCC Repowering Project: Use of the Lockheed Kinetic Extruder for coal feeding; Topical report, June 1993  

SciTech Connect (OSTI)

ABB CE is evaluating alternate methods of coal feed across a pressure barrier for its pressurized coal gasification process. The Lockheed Kinetic Extruder has shown to be one of the most promising such developments. In essence, the Kinetic Extruder consists of a rotor in a pressure vessel. Coal enters the rotor and is forced outward to the surrounding pressure vessel by centrifugal force. The force on the coal passing across the rotor serves as a pressure barrier. Should this technology be successfully developed and tested, it could reduce the cost of IGCC technology by replacing the large lockhoppers conventionally used with a much smaller system. This will significantly decrease the size of the gasifier island. Kinetic Extruder technology needs testing over an extended period of time to develop and prove the long term reliability and performance needed in a commercial application. Major issues to be investigated in this program are component design for high temperatures, turn-down, scale-up factors, and cost. Such a test would only be economically feasible if it could be conducted on an existing plant. This would defray the cost of power and feedstock. Such an installation was planned for the CE IGCC Repowering Project in Springfield, Illinois. Due to budgetary constraints, however, this provision was dropped from the present plant design. It is believed that, with minor design changes, a small scale test version of the Kinetic Extruder could be installed parallel to an existing lockhopper system without prior space allocation. Kinetic Extruder technology represents significant potential cost savings to the IGCC process. For this reason, a test program similar to that specified for the Springfield project would be a worthwhile endeavor.

NONE

1994-02-01T23:59:59.000Z

14

Thermoeconomic design optimization of a KRW-based IGCC power plant  

SciTech Connect (OSTI)

This report discussed the cost and efficiency optimization of an integrated gasification-combined-cycle (IGCC) power plant design and the effects of important design options and parameters. Advanced thermoeconomic techniques were used to evaluate and optimize a given IGCC concept which uses Illinois No. 6 bituminous coal, air-blown KRW coal gasifiers, a hot gas cleanup system, and GE MS7001F gas turbines. Three optimal design concepts are presented and discussed in the report. Two of the concepts are characterized by minimum cost of electricity at two different values of the steam high pressure. The third concept represents the thermodynamic optimum. This study identified several differences between the original design and the design of the optimized cases. Compared with the original concept, significant annual savings are achieved in the cost optimal cases. Comparisons were made between results obtained using both the old and the new performance data for the MS7001F gas turbine. This report discusses the effects of gasification temperature, steam high pressure, coal moisture, and various design options on the overall plant efficiency and cost of electricity. Cost sensitivity studies were conducted and recommendations for future studies were made.

Tsatsaronis, G.; Lin, L.; Pisa, J.; Tawfik, T. (Tennessee Technological Univ., Cookeville, TN (United States). Center for Electric Power)

1991-11-01T23:59:59.000Z

15

Thermoeconomic design optimization of a KRW-based IGCC power plant. Final report  

SciTech Connect (OSTI)

This report discussed the cost and efficiency optimization of an integrated gasification-combined-cycle (IGCC) power plant design and the effects of important design options and parameters. Advanced thermoeconomic techniques were used to evaluate and optimize a given IGCC concept which uses Illinois No. 6 bituminous coal, air-blown KRW coal gasifiers, a hot gas cleanup system, and GE MS7001F gas turbines. Three optimal design concepts are presented and discussed in the report. Two of the concepts are characterized by minimum cost of electricity at two different values of the steam high pressure. The third concept represents the thermodynamic optimum. This study identified several differences between the original design and the design of the optimized cases. Compared with the original concept, significant annual savings are achieved in the cost optimal cases. Comparisons were made between results obtained using both the old and the new performance data for the MS7001F gas turbine. This report discusses the effects of gasification temperature, steam high pressure, coal moisture, and various design options on the overall plant efficiency and cost of electricity. Cost sensitivity studies were conducted and recommendations for future studies were made.

Tsatsaronis, G.; Lin, L.; Pisa, J.; Tawfik, T. [Tennessee Technological Univ., Cookeville, TN (United States). Center for Electric Power

1991-11-01T23:59:59.000Z

16

Advanced virtual energy simulation training and research: IGCC with CO2 capture power plant  

SciTech Connect (OSTI)

In this presentation, we highlight the deployment of a real-time dynamic simulator of an integrated gasification combined cycle (IGCC) power plant with CO{sub 2} capture at the Department of Energy's (DOE) National Energy Technology Laboratory's (NETL) Advanced Virtual Energy Simulation Training and Research (AVESTARTM) Center. The Center was established as part of the DOE's accelerating initiative to advance new clean coal technology for power generation. IGCC systems are an attractive technology option, generating low-cost electricity by converting coal and/or other fuels into a clean synthesis gas mixture in a process that is efficient and environmentally superior to conventional power plants. The IGCC dynamic simulator builds on, and reaches beyond, conventional power plant simulators to merge, for the first time, a 'gasification with CO{sub 2} capture' process simulator with a 'combined-cycle' power simulator. Fueled with coal, petroleum coke, and/or biomass, the gasification island of the simulated IGCC plant consists of two oxygen-blown, downward-fired, entrained-flow, slagging gasifiers with radiant syngas coolers and two-stage sour shift reactors, followed by a dual-stage acid gas removal process for CO{sub 2} capture. The combined cycle island consists of two F-class gas turbines, steam turbine, and a heat recovery steam generator with three-pressure levels. The dynamic simulator can be used for normal base-load operation, as well as plant start-up and shut down. The real-time dynamic simulator also responds satisfactorily to process disturbances, feedstock blending and switchovers, fluctuations in ambient conditions, and power demand load shedding. In addition, the full-scope simulator handles a wide range of abnormal situations, including equipment malfunctions and failures, together with changes initiated through actions from plant field operators. By providing a comprehensive IGCC operator training system, the AVESTAR Center is poised to develop a workforce well-prepared to operate and control commercial-scale gasification-based power plants capable of 90% pre-combustion CO{sub 2} capture and compression, as well as low sulfur, mercury, and NOx emissions. With additional support from the NETL-Regional University Alliance (NETL-RUA), the Center will educate and train engineering students and researchers by providing hands-on 'learning by operating' experience The AVESTAR Center also offers unique collaborative R&D opportunities in high-fidelity dynamic modeling, advanced process control, real-time optimization, and virtual plant simulation. Objectives and goals are aimed at safe and effective management of power generation systems for optimal efficiency, while protecting the environment. To add another dimension of realism to the AVESTAR experience, NETL will introduce an immersive training system with innovative three-dimensional virtual reality technology. Wearing a stereoscopic headset or eyewear, trainees will enter an interactive virtual environment that will allow them to move freely throughout the simulated 3-D facility to study and learn various aspects of IGCC plant operation, control, and safety. Such combined operator and immersive training systems go beyond traditional simulation and include more realistic scenarios, improved communication, and collaboration among co-workers.

Zitney, S.; Liese, E.; Mahapatra, P.; Bhattacharyya, D.; Provost, G.

2011-01-01T23:59:59.000Z

17

IGCC repowering project clean coal II project public design report. Annual report, October 1992--September 1993  

SciTech Connect (OSTI)

Combustion Engineering, Inc. (CE) is participating in a $270 million coal gasification combined cycle repowering project that was designed to provide a nominal 60 MW of electricity to City, Water, Light and Power (CWL&P) in Springfield, Illinois. The Integrated Gasification Combined Cycle (IGCC) system consists of CE`s air-blown entrained flow two-stage gasifier; an advanced hot gas cleanup system; a combustion turbine adapted to use low-BTU gas; and all necessary coal handling equipment, The project is currently completing the second budget period of five. The major activities to date are: (1) Establishment of a design, cost, and schedule for the project; (2) Establishment of financial commitments; (3) Acquire design and modeling data; (4) Establishment of an approved for design (AFD) engineering package; (5) Development of a detailed cost estimate; (6) Resolution of project business issues; (7) CWL&P renewal and replacement activities; and (8) Application for environmental air permits. A Project Management Plan was generated, The conceptual design of the plant was completed and a cost and schedule baseline for the project was established in Budget Period One. This information was used to establish AFD Process Flow Diagrams, Piping and Instrument Diagrams, Equipment Data Sheets, material take offs, site modification plans and other information necessary to develop a plus or minus 20% cost estimate. Environmental permitting activities were accomplished, including the Air Permit Application, completion of the National Environmental Policy Act process, and the draft Environmental Monitoring Plan. At the end of 1992 the DOE requested that Duke Engineering and Services Inc., (DESI) be used to complete the balance of plant cost estimate. DESI was retained to do this work, DESI completed the material take off estimate and included operations, maintenance, and startup in the estimate.

NONE

1993-10-01T23:59:59.000Z

18

Future Impacts of Coal Distribution Constraints on Coal Cost  

E-Print Network [OSTI]

coal (PC) or integrated gasification combined cycle ( IGCC)coal (PC) or integrated gasification combined cycle (IGCC)will be integrated gasification combined cycle (IGCC) (Same

McCollum, David L

2007-01-01T23:59:59.000Z

19

CE IGCC repowering project: Clean Coal II Project. Annual report, 1 January, 1992--31 December, 1992  

SciTech Connect (OSTI)

CE is participating in a $270 million coal gasification combined cycle repowering project that will provide a nominal 60 MW of electricity to City, Water, light and Power (CWL and P) in Springfield, Illinois. The IGCC system will consist of CE`s air-blown entrained flow two-stage gasifier; an advanced hot gas cleanup system; a combustion turbine adapted to use low-Btu gas: and all necessary coal handling equipment. The project is currently in the second budget period of five. The major activities during this budgeted period are: Establishment of an approved for design (AFD) engineering package; development of a detailed cost estimate; resolution of project business issues; CWL and P renewal and replacement activities; and application for environmental air permits. The Project Management Plan was updated. The conceptual design of the plant was completed and a cost and schedule baseline for the project was established previously in Budget Period One. This information was used to establish AFD Process Flow Diagrams, Piping and Instrument Diagrams, Equipment Data Sheets, material take offs, site modification plans and other information necessary to develop a plus or minus 20% cost estimate. Environmental permitting activities are continuing. At the end of 1992 the major activities remaining for Budget Period two is to finish the cost estimate and complete the Continuation Request Documents.

Not Available

1993-12-01T23:59:59.000Z

20

Enhanced IGCC regulatory control and coordinated plant-wide control strategies for improving power ramp rates  

SciTech Connect (OSTI)

As part of ongoing R&D activities at the National Energy Technology Laboratory’s (NETL) Advanced Virtual Energy Simulation Training & Research (AVESTAR™) Center, this paper highlights strategies for enhancing low-level regulatory control and system-wide coordinated control strategies implemented in a high-fidelity dynamic simulator for an Integrated Gasification Combined Cycle (IGCC) power plant with carbon capture. The underlying IGCC plant dynamic model contains 20 major process areas, each of which is tightly integrated with the rest of the power plant, making individual functionally-independent processes prone to routine disturbances. Single-loop feedback control although adequate to meet the primary control objective for most processes, does not take into account in advance the effect of these disturbances, making the entire power plant undergo large offshoots and/or oscillations before the feedback action has an opportunity to impact control performance. In this paper, controller enhancements ranging from retuning feedback control loops, multiplicative feed-forward control and other control techniques such as split-range control, feedback trim and dynamic compensation, applicable on various subsections of the integrated IGCC plant, have been highlighted and improvements in control responses have been given. Compared to using classical feedback-based control structure, the enhanced IGCC regulatory control architecture reduces plant settling time and peak offshoots, achieves faster disturbance rejection, and promotes higher power ramp-rates. In addition, improvements in IGCC coordinated plant-wide control strategies for “Gasifier-Lead”, “GT-Lead” and “Plantwide” operation modes have been proposed and their responses compared. The paper is concluded with a brief discussion on the potential IGCC controller improvements resulting from using advanced process control, including model predictive control (MPC), as a supervisory control layer.

Mahapatra, P.; Zitney, S.

2012-01-01T23:59:59.000Z

Note: This page contains sample records for the topic "igcc coal plants" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


21

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

SciTech Connect (OSTI)

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.

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

1994-06-01T23:59:59.000Z

22

Investigation of adsorbent-based warm carbon dioxide capture technology for IGCC system  

E-Print Network [OSTI]

Integrated gasification combined cycle with CO? capture and sequestration (IGCC-CCS) emerges as one of the most promising technologies for reducing CO? emission from coal power plant without reducing thermal efficiency ...

Liu, Zan, Ph. D. Massachusetts Institute of Technology

2014-01-01T23:59:59.000Z

23

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

SciTech Connect (OSTI)

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.

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

1994-06-01T23:59:59.000Z

24

Control system design for maintaining CO{sub 2} capture in IGCC power plants while loading-following  

SciTech Connect (OSTI)

Load-following requirements for future integrated gasification combined cycle (IGCC) power plants with precombustion CO{sub 2} capture are expected to be far more challenging as electricity produced by renewable energy is connected to the grid and strict environmental limits become mandatory requirements. In this work, loadfollowing studies are performed using a comprehensive dynamic model of an IGCC plant with pre-combustion CO{sub 2} capture developed in Aspen Engineering Suite (AES). Considering multiple single-loop controllers for power demand load following, the preferred IGCC control strategy from the perspective of a power producer is gas turbine (GT) lead with gasifier follow. In this strategy, the GT controls the load by manipulating its firing rate while the slurry feed flow to the gasifier is manipulated to control the syngas pressure at the GT inlet. The syngas pressure control is an integrating process with significant time delay mainly because of the large piping and equipment volumes between the gasifier and the GT inlet. A modified proportional–integral–derivative (PID) control is considered for IGCC syngas pressure control. The desired CO{sub 2} capture rate must be maintained while the IGCC plant follows the load. For maintaining the desired CO{sub 2} capture rate, the control performance of PID control is compared with linear model predictive control (LMPC). The results show that the LMPC outperforms PID control for maintaining CO{sub 2} capture rates in an IGCC power plant while load following.

Bhattacharyya, D.; Turton, R.; Zitney, S.

2012-01-01T23:59:59.000Z

25

An evaluation of integrated-gasification-combined-cycle and pulverized-coal-fired steam plants: Volume 1, Base case studies: Final report  

SciTech Connect (OSTI)

An evaluation of the performance and costs for a Texaco-based integrated gasification combined cycle (IGCC) power plant as compared to a conventional pulverized coal-fired steam (PCFS) power plant with flue gas desulfurization (FGD) is provided. A general set of groundrules was used within which each plant design was optimized. The study incorporated numerous sensitivity cases along with up-to-date operating and cost data obtained through participation of equipment vendors and process developers. Consequently, the IGCC designs presented in this study use the most recent data available from Texaco's ongoing international coal gasification development program and General Electric's continuing gas turbine development efforts. The Texaco-based IGCC has advantages over the conventional PCFS technology with regard to environmental emissions and natural resource requirements. SO/sub 2/, NOx, and particulate emissions are lower. Land area and water requirements are less for IGCC concepts. Coal consumption is less due to the higher plant thermal efficiency attainable in the IGCC plant. The IGCC plant also has the capability to be designed in several different configurations, with and without the use of natural gas or oil as a backup fuel. This capability may prove to be particularly advantageous in certain utility planning and operation scenarios. 107 figs., 114 tabs.

Pietruszkiewicz, J.; Milkavich, R.J.; Booras, G.S.; Thomas, G.O.; Doss, H.

1988-09-01T23:59:59.000Z

26

Method and system to estimate variables in an integrated gasification combined cycle (IGCC) plant  

DOE Patents [OSTI]

System and method to estimate variables in an integrated gasification combined cycle (IGCC) plant are provided. The system includes a sensor suite to measure respective plant input and output variables. An extended Kalman filter (EKF) receives sensed plant input variables and includes a dynamic model to generate a plurality of plant state estimates and a covariance matrix for the state estimates. A preemptive-constraining processor is configured to preemptively constrain the state estimates and covariance matrix to be free of constraint violations. A measurement-correction processor may be configured to correct constrained state estimates and a constrained covariance matrix based on processing of sensed plant output variables. The measurement-correction processor is coupled to update the dynamic model with corrected state estimates and a corrected covariance matrix. The updated dynamic model may be configured to estimate values for at least one plant variable not originally sensed by the sensor suite.

Kumar, Aditya; Shi, Ruijie; Dokucu, Mustafa

2013-09-17T23:59:59.000Z

27

Advanced regulatory control and coordinated plant-wide control strategies for IGCC targeted towards improving power ramp-rates  

SciTech Connect (OSTI)

As part of ongoing R&D activities at the National Energy Technology Laboratory's (NETL) Advanced Virtual Energy Simulation Training & Research (AVESTAR™) Center, this paper highlights strategies for enhancing low-level regulatory control and system-wide coordinated control strategies implemented in a high-fidelity dynamic simulator for an Integrated Gasification Combined Cycle (IGCC) power plant with carbon capture. The underlying IGCC plant dynamic model contains 20 major process areas, each of which is tightly integrated with the rest of the power plant, making individual functionally-independent processes prone to routine disturbances. Single-loop feedback control although adequate to meet the primary control objective for most processes, does not take into account in advance the effect of these disturbances, making the entire power plant undergo large offshoots and/or oscillations before the feedback action has an opportunity to impact control performance. In this paper, controller enhancements ranging from retuning feedback control loops, multiplicative feed-forward control and other control techniques such as split-range control, feedback trim and dynamic compensation, applicable on various subsections of the integrated IGCC plant, have been highlighted and improvements in control responses have been given. Compared to using classical feedback-based control structure, the enhanced IGCC regulatory control architecture reduces plant settling time and peak offshoots, achieves faster disturbance rejection, and promotes higher power ramp-rates. In addition, improvements in IGCC coordinated plant-wide control strategies for “Gasifier-Lead”, “GT-Lead” and “Plantwide” operation modes have been proposed and their responses compared. The paper is concluded with a brief discussion on the potential IGCC controller improvements resulting from using advanced process control, including model predictive control (MPC), as a supervisory control layer.

Mahapatra, P.; Zitney, S.

2012-01-01T23:59:59.000Z

28

AVESTAR Center for operational excellence of IGCC power plants with CO2 capture  

SciTech Connect (OSTI)

This presentation begins with a description of U.S. Energy Challenges, particularly Power Generation Capacity and Clean Energy Plant Operations. It goes on to describe the missions and goals of the Advanced Virtual Energy Simulation Training And Research (AVESTARTM). It moves on to the subject of Integrated Gasification Combined Cycle (IGCC) with CO{sub 2} Capture, particularly a Process/Project Overview, Dynamic Simulator/Operator Training System (OTS), 3D Virtual Immersive Training System (ITS), Facilities, Training, Education, and R&D, and Future Simulators/Directions

Provost, G,

2012-01-01T23:59:59.000Z

29

AVESTAR Center for operational excellence of IGCC power plants with CO2 capture  

SciTech Connect (OSTI)

This slideshow presentation begins by outlining US energy challenges, particularly with respect to power generation capacity and clean energy plant operations. It goes on to describe the Advanced Virtual Energy Simulation Training And Research (AVESTAR{sup TM}). Its mission and goals are given, followed by an overview of integrated gasification combined cycle (IGCC) with CO{sub 2} capture. The Dynamic Simulator/Operator Training System (OTS) and 3D Virtual Immersive Training System (ITS) are then presented. Facilities, training, education, and R&D are covered, followed by future simulators and directions.

Provost, G,

2012-01-01T23:59:59.000Z

30

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

SciTech Connect (OSTI)

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.

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

1996-10-16T23:59:59.000Z

31

Ultra Low NOx Catalytic Combustion for IGCC Power Plants  

SciTech Connect (OSTI)

In order to meet DOE's goals of developing low-emissions coal-based power systems, PCI has further developed and adapted it's Rich-Catalytic Lean-burn (RCL{reg_sign}) catalytic reactor to a combustion system operating on syngas as a fuel. The technology offers ultra-low emissions without the cost of exhaust after-treatment, with high efficiency (avoidance of after-treatment losses and reduced diluent requirements), and with catalytically stabilized combustion which extends the lower Btu limit for syngas operation. Tests were performed in PCI's sub-scale high-pressure (10 atm) test rig, using a two-stage (catalytic then gas-phase) combustion process for syngas fuel. In this process, the first stage consists of a fuel-rich mixture reacting on a catalyst with final and excess combustion air used to cool the catalyst. The second stage is a gas-phase combustor, where the air used for cooling the catalyst mixes with the catalytic reactor effluent to provide for final gas-phase burnout and dilution to fuel-lean combustion products. During testing, operating with a simulated Tampa Electric's Polk Power Station syngas, the NOx emissions program goal of less than 0.03 lbs/MMBtu (6 ppm at 15% O{sub 2}) was met. NOx emissions were generally near 0.01 lbs/MMBtu (2 ppm at 15% O{sub 2}) (PCI's target) over a range on engine firing temperatures. In addition, low emissions were shown for alternative fuels including high hydrogen content refinery fuel gas and low BTU content Blast Furnace Gas (BFG). For the refinery fuel gas increased resistance to combustor flashback was achieved through preferential consumption of hydrogen in the catalytic bed. In the case of BFG, stable combustion for fuels as low as 88 BTU/ft{sup 3} was established and maintained without the need for using co-firing. This was achieved based on the upstream catalytic reaction delivering a hotter (and thus more reactive) product to the flame zone. The PCI catalytic reactor was also shown to be active in ammonia reduction in fuel allowing potential reductions in the burner NOx production. These reductions of NOx emissions and expanded alternative fuel capability make the rich catalytic combustor uniquely situated to provide reductions in capital costs through elimination of requirements for SCR, operating costs through reduction in need for NOx abating dilution, SCR operating costs, and need for co-firing fuels allowing use of lower value but more available fuels, and efficiency of an engine through reduction in dilution flows.

Shahrokh Etemad; Benjamin Baird; Sandeep Alavandi; William Pfefferle

2008-03-31T23:59:59.000Z

32

Toms Creek IGCC Demonstration Project  

SciTech Connect (OSTI)

The Toms Creek Integrated Gasification Combined Cycle (IGCC) Demonstration Project was selected by DOE in September 1991 to participate in Round Four of the Clean Coal Technology Demonstration Program. The project will demonstrate a simplified IGCC process consisting of an air-blown, fluidized-bed gasifier (Tampella U-Gas), a gas cooler/steam generator, and a hot gas cleanup system in combination with a gas turbine modified for use with a low-Btu content fuel and a conventional steam bottoming cycle. The demonstration plant will be located at the Toms Creek coal mine near Coeburn, Wise County, Virginia. Participants in the project are Tampella Power Corporation and Coastal Power Production Company. The plant will use 430 tons per day of locally mined bituminous coal to produce 55 MW of power from the gasification section of the project. A modern pulverized coal fired unit will be located adjacent to the Demonstration Project producing an additional 150 MW. A total 190 MW of power will be delivered to the electric grid at the completion of the project. In addition, 50,000 pounds per hour of steam will be exported to be used in the nearby coal preparation plant. Dolomite is used for in-bed gasifier sulfur capture and downs cleanup is accomplished in a fluidized-bed of regenerative zinc titanate. Particulate clean-up, before the gas turbine, will be performed by high temperature candle filters (1020[degree]F). The demonstration plant heat rate is estimated to be 8,700 Btu/kWh. The design of the project goes through mid 1995, with site construction activities commencing late in 1995 and leading to commissioning and start-up by the end of 1997. This is followed by a three year demonstration period.

Virr, M.J.

1992-01-01T23:59:59.000Z

33

Toms Creek IGCC Demonstration Project  

SciTech Connect (OSTI)

The Toms Creek Integrated Gasification Combined Cycle (IGCC) Demonstration Project was selected by DOE in September 1991 to participate in Round Four of the Clean Coal Technology Demonstration Program. The project will demonstrate a simplified IGCC process consisting of an air-blown, fluidized-bed gasifier (Tampella U-Gas), a gas cooler/steam generator, and a hot gas cleanup system in combination with a gas turbine modified for use with a low-Btu content fuel and a conventional steam bottoming cycle. The demonstration plant will be located at the Toms Creek coal mine near Coeburn, Wise County, Virginia. Participants in the project are Tampella Power Corporation and Coastal Power Production Company. The plant will use 430 tons per day of locally mined bituminous coal to produce 55 MW of power from the gasification section of the project. A modern pulverized coal fired unit will be located adjacent to the Demonstration Project producing an additional 150 MW. A total 190 MW of power will be delivered to the electric grid at the completion of the project. In addition, 50,000 pounds per hour of steam will be exported to be used in the nearby coal preparation plant. Dolomite is used for in-bed gasifier sulfur capture and downs cleanup is accomplished in a fluidized-bed of regenerative zinc titanate. Particulate clean-up, before the gas turbine, will be performed by high temperature candle filters (1020{degree}F). The demonstration plant heat rate is estimated to be 8,700 Btu/kWh. The design of the project goes through mid 1995, with site construction activities commencing late in 1995 and leading to commissioning and start-up by the end of 1997. This is followed by a three year demonstration period.

Virr, M.J.

1992-11-01T23:59:59.000Z

34

Evaluation of sorbents for the cleanup of coal-derived synthesis gas at elevated temperatures  

E-Print Network [OSTI]

Integrated Gasification Combined Cycle (IGCC) with carbon dioxide capture is a promising technology to produce electricity from coal at a higher efficiency than with traditional subcritical pulverized coal (PC) power plants. ...

Couling, David Joseph

2012-01-01T23:59:59.000Z

35

Enabling Technology for Monitoring & Predicting Gas Turbine Health & Performance in IGCC Powerplants  

SciTech Connect (OSTI)

The ''Enabling & Information Technology To Increase RAM for Advanced Powerplants'' program, by DOE request, was re-directed, de-scoped to two tasks, shortened to a 2-year period of performance, and refocused to develop, validate and accelerate the commercial use of enabling materials technologies and sensors for coal/IGCC powerplants. The new program was re-titled ''Enabling Technology for Monitoring & Predicting Gas Turbine Health & Performance in IGCC Powerplants''. This final report summarizes the work accomplished from March 1, 2003 to March 31, 2004 on the four original tasks, and the work accomplished from April 1, 2004 to July 30, 2005 on the two re-directed tasks. The program Tasks are summarized below: Task 1--IGCC Environmental Impact on high Temperature Materials: The first task was refocused to address IGCC environmental impacts on high temperature materials used in gas turbines. This task screened material performance and quantified the effects of high temperature erosion and corrosion of hot gas path materials in coal/IGCC applications. The materials of interest included those in current service as well as advanced, high-performance alloys and coatings. Task 2--Material In-Service Health Monitoring: The second task was reduced in scope to demonstrate new technologies to determine the inservice health of advanced technology coal/IGCC powerplants. The task focused on two critical sensing needs for advanced coal/IGCC gas turbines: (1) Fuel Quality Sensor to rapidly determine the fuel heating value for more precise control of the gas turbine, and detection of fuel impurities that could lead to rapid component degradation. (2) Infra-Red Pyrometer to continuously measure the temperature of gas turbine buckets, nozzles, and combustor hardware. Task 3--Advanced Methods for Combustion Monitoring and Control: The third task was originally to develop and validate advanced monitoring and control methods for coal/IGCC gas turbine combustion systems. This task was refocused to address pre-mixed combustion phenomenon for IGCC applications. The work effort on this task was shifted to another joint GE Energy/DOE-NETL program investigation, High Hydrogen Pre-mixer Designs, as of April 1, 2004. Task 4--Information Technology (IT) Integration: The fourth task was originally to demonstrate Information Technology (IT) tools for advanced technology coal/IGCC powerplant condition assessment and condition based maintenance. The task focused on development of GateCycle. software to model complete-plant IGCC systems, and the Universal On-Site Monitor (UOSM) to collect and integrate data from multiple condition monitoring applications at a power plant. The work on this task was stopped as of April 1, 2004.

Kenneth A. Yackly

2005-12-01T23:59:59.000Z

36

Dynamic simulation and load-following control of an integrated gasification combined cycle (IGCC) power plant with CO{sub 2} capture  

SciTech Connect (OSTI)

Load-following control of future integrated gasification combined cycle (IGCC) plants with pre-combustion CO{sub 2} capture is expected to be far more challenging as electricity produced by renewable energy is connected to the grid and strict environmental limits become mandatory requirements. To study control performance during load following, a plant-wide dynamic simulation of a coal-fed IGCC plant with CO{sub 2} capture has been developed. The slurry-fed gasifier is a single-stage, downward-fired, oxygen-blown, entrained-flow type with a radiant syngas cooler (RSC). The syngas from the outlet of the RSC goes to a scrubber followed by a two-stage sour shift process with inter-stage cooling. The acid gas removal (AGR) process is a dual-stage physical solvent-based process for selective removal of H{sub 2}S in the first stage and CO{sub 2} in the second stage. Sulfur is recovered using a Claus unit with tail gas recycle to the AGR. The recovered CO{sub 2} is compressed by a split-shaft multistage compressor and sent for sequestration after being treated in an absorber with triethylene glycol for dehydration. The clean syngas is sent to two advanced “F”-class gas turbines (GTs) partially integrated with an elevated-pressure air separation unit. A subcritical steam cycle is used for heat recovery steam generation. A treatment unit for the sour water strips off the acid gases for utilization in the Claus unit. The steady-state model developed in Aspen Plus® is converted to an Aspen Plus Dynamics® simulation and integrated with MATLAB® for control studies. The results from the plant-wide dynamic model are compared qualitatively with the data from a commercial plant having different configuration, operating condition, and feed quality than what has been considered in this work. For load-following control, the GT-lead with gasifier-follow control strategy is considered. A modified proportional–integral–derivative (PID) control is considered for the syngas pressure control. For maintaining the desired CO{sub 2} capture rate while load-following, a linear model predictive controller (LMPC) is implemented in MATLAB®. A combined process and disturbance model is identified by considering a number of model forms and choosing the final model based on an information-theoretic criterion. The performance of the LMPC is found to be superior to the conventional PID control for maintaining CO{sub 2} capture rates in an IGCC power plant while load following.

Bhattacharyya, D,; Turton, R.; Zitney, S.

2012-01-01T23:59:59.000Z

37

Load-following control of an IGCC plant with CO2 capture  

SciTech Connect (OSTI)

In this paper, a decentralized control strategy is considered for load-following control of an integrated gasification combined cycle (IGCC) plant with CO2 capture without flaring the syngas. The control strategy considered is gas turbine (GT) lead with gasifier follow. In this strategy, the GT controls the power load by manipulating its firing rate while the slurry feed flow to the gasifier is manipulated to control the syngas pressure at the GT inlet. However, the syngas pressure control is an integrating process with significant timedelay. In this work, a modified proportional-integral-derivative (PID) control is considered for syngas pressure control given that conventional PID controllers show poor control performance for integrating processes with large time delays. The conventional PID control is augmented with an internal feedback loop. The P-controller used in this internal loop converts the integrating process to an open-loop stable process. The resulting secondorder plus time delay model uses a PID controller where the tuning parameters are found by minimizing the integral time-weighted absolute error (ITAE) for disturbance rejection. A plant model with single integrator and time delay is identified by a P-control method. When a ramp change is introduced in the set-point of the load controller, the performance of both the load and pressure controllers with the modified PID control strategy is found to be superior to that using a traditional PID controller. Key

Bhattacharyya, D.; Turton, R.; Zitney, S.

2011-01-01T23:59:59.000Z

38

AVESTAR Center: Dynamic simulation-based collaboration toward achieving opertional excellence for IGCC plants with crbon capture  

SciTech Connect (OSTI)

To address challenges in attaining operational excellence for clean energy plants, the National Energy Technology Laboratory has launched a world-class facility for Advanced Virtual Energy Simulation Training And Research (AVESTAR(TM)). The AVESTAR Center brings together state-of-the-art, real-time, high-fidelity dynamic simulators with operator training systems and 3D virtual immersive training systems into an integrated energy plant and control room environment. This paper will highlight the AVESTAR Center simulators, facilities, and comprehensive training, education, and research programs focused on the operation and control of an integrated gasification combined cycle power plant (IGCC) with carbon dioxide capture.

Zitney, Strphen E. [U.S. DOE; Liese, Eric A. [U.S. DOE; Mahapatra, Priyadarshi [URS; Turton, Richard [WVU; Bhattacharyya, Debangsu [WVU; Provost, Graham [Fossil Consulting Services

2012-01-01T23:59:59.000Z

39

Integrated Coal Gasification Power Plant Credit (Kansas)  

Broader source: Energy.gov [DOE]

Integrated Coal Gasification Power Plant Credit states that an income taxpayer that makes a qualified investment in a new integrated coal gasification power plant or in the expansion of an existing...

40

Steam Plant Conversion Eliminating Campus Coal Use  

E-Print Network [OSTI]

Steam Plant Conversion Eliminating Campus Coal Use at the Steam Plant #12;· Flagship campus region produce 14% of US coal (TN only 0.2%) Knoxville and the TN Valley #12;· UT is one of about 70 U.S. colleges and universities w/ steam plant that burns coal · Constructed in 1964, provides steam for

Dai, Pengcheng

Note: This page contains sample records for the topic "igcc coal plants" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


41

Technology status and project development risks of advanced coal power generation technologies in APEC developing economies  

SciTech Connect (OSTI)

The report reviews the current status of IGCC and supercritical/ultrasupercritical pulverized-coal power plants and summarizes risks associated with project development, construction and operation. The report includes an economic analysis using three case studies of Chinese projects; a supercritical PC, an ultrasupercritical PC, and an IGCC plant. The analysis discusses barriers to clean coal technologies and ways to encourage their adoption for new power plants. 25 figs., 25 tabs.

Lusica, N.; Xie, T.; Lu, T.

2008-10-15T23:59:59.000Z

42

Optimal control system design of an acid gas removal unit for an IGCC power plants with CO2 capture  

SciTech Connect (OSTI)

Future IGCC plants with CO{sub 2} capture should be operated optimally in the face of disturbances without violating operational and environmental constraints. To achieve this goal, a systematic approach is taken in this work to design the control system of a selective, dual-stage Selexol-based acid gas removal (AGR) unit for a commercial-scale integrated gasification combined cycle (IGCC) power plant with pre-combustion CO{sub 2} capture. The control system design is performed in two stages with the objective of minimizing the auxiliary power while satisfying operational and environmental constraints in the presence of measured and unmeasured disturbances. In the first stage of the control system design, a top-down analysis is used to analyze degrees of freedom, define an operational objective, identify important disturbances and operational/environmental constraints, and select the control variables. With the degrees of freedom, the process is optimized with relation to the operational objective at nominal operation as well as under the disturbances identified. Operational and environmental constraints active at all operations are chosen as control variables. From the results of the optimization studies, self-optimizing control variables are identified for further examination. Several methods are explored in this work for the selection of these self-optimizing control variables. Modifications made to the existing methods will be discussed in this presentation. Due to the very large number of candidate sets available for control variables and due to the complexity of the underlying optimization problem, solution of this problem is computationally expensive. For reducing the computation time, parallel computing is performed using the Distributed Computing Server (DCS®) and the Parallel Computing® toolbox from Mathworks®. The second stage is a bottom-up design of the control layers used for the operation of the process. First, the regulatory control layer is designed followed by the supervisory control layer. Finally, an optimization layer is designed. In this paper, the proposed two-stage control system design approach is applied to the AGR unit for an IGCC power plant with CO{sub 2} capture. Aspen Plus Dynamics® is used to develop the dynamic AGR process model while MATLAB is used to perform the control system design and for implementation of model predictive control (MPC).

Jones, D.; Bhattacharyya, D.; Turton, R.; Zitney, S.

2012-01-01T23:59:59.000Z

43

Potential market penetration of IGCC in the northeast United States  

SciTech Connect (OSTI)

This study examines IGCC market penetration potential for baseload power generation in the Northeast US, an important market area for IGCC because of the existing coal generation infrastructure and its proximity to coal producing regions. Three utility power pools supply most of the power for this region. They are the Pennsylvania, New Jersey, Maryland Power Pool (PJM), the New York Power Pool (NYPP), and the New England Power Exchange (NEPEX). The CONSOL Regional Compliance Model (RCM) was configured to evaluate the power market in the northeast region of the US IGCC was evaluated both as a replacement option for existing power plants and as a new capacity option to satisfy load growth requirements. Using the bus bar cost of electricity as the deciding factor, the RCM considers generation technologies and fuel options to supply power taking into account load projections, emission costs, fuel price projections, plant performance, and capital and operating cost estimates. The emission costs, in the form of a tax or allowance price (or another equivalent mechanism), consider CO{sub 2}, SO{sub 2}, and NO{sub x} emissions.

Gray, D.; Tomlinson, G.; Hawk, E.; Maskew, J.

2000-07-01T23:59:59.000Z

44

Avoiding a Train Wreck: Replacing Old Coal Plants with Energy...  

Office of Energy Efficiency and Renewable Energy (EERE) Indexed Site

Avoiding a Train Wreck: Replacing Old Coal Plants with Energy Efficiency, August 2011 Avoiding a Train Wreck: Replacing Old Coal Plants with Energy Efficiency, August 2011 This...

45

Kemper County IGCC (tm) Project Preliminary Public Design Report  

SciTech Connect (OSTI)

The Kemper County IGCC Project is an advanced coal technology project that is being developed by Mississippi Power Company (MPC). The project is a lignite-fueled 2-on-1 Integrated Gasification Combined-Cycle (IGCC) facility incorporating the air-blown Transport Integrated Gasification (TRIG™) technology jointly developed by Southern Company; Kellogg, Brown, and Root (KBR); and the United States Department of Energy (DOE) at the Power Systems Development Facility (PSDF) in Wilsonville, Alabama. The estimated nameplate capacity of the plant will be 830 MW with a peak net output capability of 582 MW. As a result of advanced emissions control equipment, the facility will produce marketable byproducts of ammonia, sulfuric acid, and carbon dioxide. 65 percent of the carbon dioxide (CO{sub 2}) will be captured and used for enhanced oil recovery (EOR), making the Kemper County facility’s carbon emissions comparable to those of a natural-gas-fired combined cycle power plant. The commercial operation date (COD) of the Kemper County IGCC plant will be May 2014. This report describes the basic design and function of the plant as determined at the end of the Front End Engineering Design (FEED) phase of the project.

Nelson, Matt; Rush, Randall; Madden, Diane; Pinkston, Tim; Lunsford, Landon

2012-07-01T23:59:59.000Z

46

Materials performance in coal gasification pilot plants  

SciTech Connect (OSTI)

This paper presents the results of several materials testing projects which were conducted in operating coal gasification pilot plants in the United States. These projects were designed to test potential materials of construction for commercial plants under actual operating conditions. Pilot plants included in the overall test program included the Hygas, Conoco Coal, Synthane, Bi-Gas, Peatgas (Hygas operating with peat), Battelle, U-Gas, Westinghouse (now KRW), General Electric (Gegas), and Mountain Fuel Resources plants. Test results for a large variety of alloys are discussed and conclusions regarding applicability of these materials in coal gasification environments are presented. 14 refs., 2 tabs.

Judkins, R.R.; Bradley, R.A.

1987-10-15T23:59:59.000Z

47

Improving pulverized coal plant performance  

SciTech Connect (OSTI)

A major deliverable of the U.S. Department of Energy (DOE) project ``Engineering Development of Advanced Coal-Fired Low-Emissions Boiler Systems`` (LEBS) is the design of a large, in this case 400 MWe, commercial generating unit (CGU) which will meet the Project objectives. The overall objective of the LEBS Project is to dramatically improve environmental performance of future pulverized coal fired power plants without adversely impacting efficiency or the cost of electricity. The DOE specified the use of near-term technologies, i.e., advanced technologies that partially developed, to reduce NO{sub x}, SO{sub 2} and particulate emissions to be substantially less than current NSPS limits. In addition, air toxics must be in compliance and waste must be reduced and made more disposable. The design being developed by the ABB Team is projected to meet all the contract objectives and to reduce emission of NO{sub x}, SO{sub 2} and particulates to one-fifth to one-tenth NSPS limits while increasing net station efficiency significantly and reducing the cost of electricity. This design and future work are described in the paper.

Regan, J.W.; Borio, R.W.; Palkes, M.; Mirolli, M. [ABB Combustion Engineering, Inc., Windsor, CT (United States); Wesnor, J.D. [ABB Environmental Systems, Birmingham, AL (United States); Bender, D.J. [Raytheon Engineers and Constructors, Inc., New York, NY (United States)

1995-12-31T23:59:59.000Z

48

A Review of Hazardous Chemical Species Associated with CO2 Capture from Coal-Fired Power Plants and Their Potential Fate in CO2 Geologic Storage  

E-Print Network [OSTI]

the solid waste residues during combustion or gasificationcoal gasification stage in IGCC plants results in a waste

Apps, J.A.

2006-01-01T23:59:59.000Z

49

Combined cycle power plant incorporating coal gasification  

DOE Patents [OSTI]

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.

Liljedahl, Gregory N. (Tariffville, CT); Moffat, Bruce K. (Simsbury, CT)

1981-01-01T23:59:59.000Z

50

Model Based Optimal Sensor Network Design for Condition Monitoring in an IGCC Plant  

SciTech Connect (OSTI)

This report summarizes the achievements and final results of this program. The objective of this program is to develop a general model-based sensor network design methodology and tools to address key issues in the design of an optimal sensor network configuration: the type, location and number of sensors used in a network, for online condition monitoring. In particular, the focus in this work is to develop software tools for optimal sensor placement (OSP) and use these tools to design optimal sensor network configuration for online condition monitoring of gasifier refractory wear and radiant syngas cooler (RSC) fouling. The methodology developed will be applicable to sensing system design for online condition monitoring for broad range of applications. The overall approach consists of (i) defining condition monitoring requirement in terms of OSP and mapping these requirements in mathematical terms for OSP algorithm, (ii) analyzing trade-off of alternate OSP algorithms, down selecting the most relevant ones and developing them for IGCC applications (iii) enhancing the gasifier and RSC models as required by OSP algorithms, (iv) applying the developed OSP algorithm to design the optimal sensor network required for the condition monitoring of an IGCC gasifier refractory and RSC fouling. Two key requirements for OSP for condition monitoring are desired precision for the monitoring variables (e.g. refractory wear) and reliability of the proposed sensor network in the presence of expected sensor failures. The OSP problem is naturally posed within a Kalman filtering approach as an integer programming problem where the key requirements of precision and reliability are imposed as constraints. The optimization is performed over the overall network cost. Based on extensive literature survey two formulations were identified as being relevant to OSP for condition monitoring; one based on LMI formulation and the other being standard INLP formulation. Various algorithms to solve these two formulations were developed and validated. For a given OSP problem the computation efficiency largely depends on the “size” of the problem. Initially a simplified 1-D gasifier model assuming axial and azimuthal symmetry was used to test out various OSP algorithms. Finally these algorithms were used to design the optimal sensor network for condition monitoring of IGCC gasifier refractory wear and RSC fouling. The sensors type and locations obtained as solution to the OSP problem were validated using model based sensing approach. The OSP algorithm has been developed in a modular form and has been packaged as a software tool for OSP design where a designer can explore various OSP design algorithm is a user friendly way. The OSP software tool is implemented in Matlab/Simulink© in-house. The tool also uses few optimization routines that are freely available on World Wide Web. In addition a modular Extended Kalman Filter (EKF) block has also been developed in Matlab/Simulink© which can be utilized for model based sensing of important process variables that are not directly measured through combining the online sensors with model based estimation once the hardware sensor and their locations has been finalized. The OSP algorithm details and the results of applying these algorithms to obtain optimal sensor location for condition monitoring of gasifier refractory wear and RSC fouling profile are summarized in this final report.

Kumar, Rajeeva; Kumar, Aditya; Dai, Dan; Seenumani, Gayathri; Down, John; Lopez, Rodrigo

2012-12-31T23:59:59.000Z

51

The United States of America and the People`s Republic of China experts report on integrated gasification combined-cycle technology (IGCC)  

SciTech Connect (OSTI)

A report written by the leading US and Chinese experts in Integrated Gasification Combined Cycle (IGCC) power plants, intended for high level decision makers, may greatly accelerate the development of an IGCC demonstration project in the People`s Republic of China (PRC). The potential market for IGCC systems in China and the competitiveness of IGCC technology with other clean coal options for China have been analyzed in the report. Such information will be useful not only to the Chinese government but also to US vendors and companies. The goal of this report is to analyze the energy supply structure of China, China`s energy and environmental protection demand, and the potential market in China in order to make a justified and reasonable assessment on feasibility of the transfer of US Clean Coal Technologies to China. The Expert Report was developed and written by the joint US/PRC IGCC experts and will be presented to the State Planning Commission (SPC) by the President of the CAS to ensure consideration of the importance of IGCC for future PRC power production.

NONE

1996-12-01T23:59:59.000Z

52

BOILER MATERIALS FOR ULTRASUPERCRITICAL COAL POWER PLANTS  

SciTech Connect (OSTI)

The principal objective of this project is to develop materials technology for use in ultrasupercritical (USC) plant boilers capable of operating with 760 C (1400 F), 35 MPa (5000 psi) steam. This project has established a government/industry consortium to undertake a five-year effort to evaluate and develop of advanced materials that allow the use of advanced steam cycles in coal-based power plants. These advanced cycles, with steam temperatures up to 760 C, will increase the efficiency of coal-fired boilers from an average of 35% efficiency (current domestic fleet) to 47% (HHV). This efficiency increase will enable coal-fired power plants to generate electricity at competitive rates (irrespective of fuel costs) while reducing CO{sub 2} and other fuel-related emissions by as much as 29%. Success in achieving these objectives will support a number of broader goals. First, from a national prospective, the program will identify advanced materials that will make it possible to maintain a cost-competitive, environmentally acceptable coal-based electric generation option. High sulfur coals will specifically benefit in this respect by having these advanced materials evaluated in high-sulfur coal firing conditions and from the significant reductions in waste generation inherent in the increased operational efficiency. Second, from a national prospective, the results of this program will enable domestic boiler manufacturers to successfully compete in world markets for building high-efficiency coal-fired power plants.

R. Viswanathan; K. Coleman; R.W. Swindeman; J. Sarver; J. Blough; W. Mohn; M. Borden; S. Goodstine; I. Perrin

2003-10-20T23:59:59.000Z

53

Table 23. Coal Receipts at Coke Plants by Census Division  

U.S. Energy Information Administration (EIA) Indexed Site

Division (thousand short tons) U.S. Energy Information Administration | Quarterly Coal Report, April - June 2014 Table 23. Coal Receipts at Coke Plants by Census Division...

54

BOILER MATERIALS FOR ULTRASUPERCRITICAL COAL POWER PLANTS  

SciTech Connect (OSTI)

The principal objective of this project is to develop materials technology for use in ultrasupercritical (USC) plant boilers capable of operating with 760 C (1400 F), and up to 5500 psi with emphasis upon 35 MPa (5000 psi) steam. In the 21st century, the world faces the critical challenge of providing abundant, cheap electricity to meet the needs of a growing global population while at the same time preserving environmental values. Most studies of this issue conclude that a robust portfolio of generation technologies and fuels should be developed to assure that the United States will have adequate electricity supplies in a variety of possible future scenarios. The use of coal for electricity generation poses a unique set of challenges. On the one hand, coal is plentiful and available at low cost in much of the world, notably in the U.S., China, and India. Countries with large coal reserves will want to develop them to foster economic growth and energy security. On the other hand, traditional methods of coal combustion emit pollutants and CO{sub 2} at high levels relative to other generation options. Maintaining coal as a generation option in the 21st century will require methods for addressing these environmental issues. This project has established a government/industry consortium to undertake a five-year effort to evaluate and develop advanced materials that allow the use of advanced steam cycles in coal-based power plants. These advanced cycles, with steam temperatures up to 760 C, will increase the efficiency of coal-fired boilers from an average of 35% efficiency (current domestic fleet) to 47% (HHV). This efficiency increase will enable coal-fired power plants to generate electricity at competitive rates (irrespective of fuel costs) while reducing CO{sub 2} and other fuel-related emissions by as much as 29%. Success in achieving these objectives will support a number of broader goals. First, from a national prospective, the program will identify advanced materials that will make it possible to maintain a cost-competitive, environmentally-acceptable coal-based electric generation option. High sulfur coals will specifically benefit in this respect by having these advanced materials evaluated in high-sulfur coal firing conditions and from the significant reductions in waste generation inherent in the increased operational efficiency. Second, from a national perspective, the results of this program will enable domestic boiler manufacturers to successfully compete in world markets for building high-efficiency coal-fired power plants.

R. Viswanathan

2002-04-15T23:59:59.000Z

55

The H-Coal pilot plant and the Breckinridge Project  

SciTech Connect (OSTI)

A large coal-liquefaction pilot plant is in operation at Catlettsburg, Kentucky, expanding on the H-Coal technology. The pilot plant operated very successfully during 1981, confirming research yield data on eastern bituminous coal, demonstrating operability of the process, and resulting in a significant accumulation of engineering data. Ashland Synthetic Fuels, Inc., and Bechtel Petroleum, Inc., are developing the Breckinridge Project, a commercial coal-liquefaction plant proposed for Breckinridge County, Kentucky, based on the H-Coal technology.

Wigglesworth, T.H.

1982-05-01T23:59:59.000Z

56

A utility`s perspective of the market for IGCC  

SciTech Connect (OSTI)

I believe, in the short-term U. S. market that IGCC`s primary competition is, natural gas-fired combined cycle technology. I believe that in order for IGCC to compete on a commercial basis, that natural gas prices have to rise relative to coal prices, and that the capital cost of the technology must come down. While this statement may seem to be somewhat obvious, it raises two interesting points. The first is that while the relative pricing of natural gas and coal is not generally within the technology supplier`s control, the capital cost is. The reduction of capital cost represents a major challenge for the technology suppliers in order for this technology to become commercialized. The second point is that the improvements being achieved with IGCC efficiencies probably won`t help it outperform the effects of natural gas pricing. This is due to the fact that the combined cycle portion of the IGCC technology is experiencing the most significant improvements in efficiency. I do see, however, a significant advantage for IGCC technology compared to conventional pulverized coal-fired units. As IGCC efficiencies continue to improve, combined with their environmentally superior performance, I believe that IGCC will be the ``technology of choice`` for utilities that install new coal-fired generation. We have achieved economic justification of our project by virtue of the DOE`s funding of $120 million awarded in Round III of their Clean Coal Technology Program. This program provides the bridge between current technology economics and those of the future. And Tampa Electric is pleased to be taking a leadership position in furthering the IGCC knowledge base.

Black, C.R. [Tampa Electric Co., FL (United States)

1993-08-01T23:59:59.000Z

57

An Overview of Coal based  

E-Print Network [OSTI]

An Overview of Coal based Integrated Gasification Combined Cycle (IGCC) Technology September 2005. LFEE 2005-002 WP #12;#12;Table of Contents 1 Integrated Gasification Combined Cycle (IGCC.......................................................................... 17 2.1 Gasification

58

Integrated supercritical water gasification combined cycle (IGCC) systems for improved performance and reduced operating costs in existing plants  

SciTech Connect (OSTI)

A revolutionary hydrothermal heat recovery steam generator (HRSG) is being developed to produce clean fuels for gas turbines from slurries and emulsions of opportunity fuels. Water can be above 80% by weight and solids below 20%, including coal fines, coal water fuels, biomass, composted municipal refuse, sewage sludge and bitumen/Orimulsion. The patented HRSG tubes use a commercial method of particle scrubbing to improve heat transfer and prevent corrosion and deposition on heat transfer surfaces. A continuous-flow pilot plant is planned to test the HRSG over a wide range of operating conditions, including the supercritical conditions of water, above 221 bar (3,205 psia) and 374 C (705 F). Bench scale data shows, that supercritical water gasification below 580 C (1,076 F) and low residence time without catalysts or an oxidizer can produce a char product that can contain carbon up to the amount of fixed carbon in the proximate analysis of the solids in the feed. This char can be burned with coal in an existing combustion system to provide the heat required for gasification. The new HRSG tubes can be retrofitted into existing power plant boilers for repowering of existing plants for improved performance and reduced costs. A special condensing turbine allows final low-temperature cleaning and maintains quality and combustibility of the fuel vapor for modern gas turbine in the new Vapor Transmission Cycle (VTC). Increased power output and efficiency can be provided for existing plants, while reducing fuel costs. A preliminary computer-based process simulation model has been prepared that includes material and energy balances that simulate commercial-scale operations of the VTC on sewage sludge and coal. Results predict over 40% HHV thermal efficiency to electric power from sewage sludge at more than 83% water by weight. The system appears to become autothermal (no supplemental fuel required) at about 35% fixed carbon in the feed. Thus, bituminous and lignite coal slurries could be gasified at less than 25% coal and more than 75% water. Preliminary life cycle cost analyses indicate that disposal fees for sewage sludge improve operating economics over fuel that must be purchased, the cost and schedule advantages of natural gas-fired combined cycle systems are preserved. Sensitivity analyses show that increasing capital costs by 50% can be offset by an increase in sewage sludge disposal fees of $10/metric ton.

Tolman, R.; Parkinson, W.J.

1999-07-01T23:59:59.000Z

59

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

SciTech Connect (OSTI)

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 desalination. Some of the direct approaches, such as dry air cooling, desalination, and recovery of cooling tower water for boiler makeup water, are costly and are deployed primarily in countries with severe water shortages, such as China, Australia, and South Africa. Table 1 shows drivers and approaches for reducing freshwater consumption in several countries outside the United States. Indirect approaches reduce water consumption while meeting other objectives, such as improving plant efficiency. Plants with higher efficiencies use less energy to produce electricity, and because the greater the energy production, the greater the cooling water needs, increased efficiency will help reduce water consumption. Approaches for improving efficiency (and for indirectly reducing water consumption) include increasing the operating steam parameters (temperature and pressure); using more efficient coal-fired technologies such as cogeneration, IGCC, and direct firing of gas turbines with coal; replacing or retrofitting existing inefficient plants to make them more efficient; installing high-performance monitoring and process controls; and coal drying. The motivations for increasing power plant efficiency outside the United States (and indirectly reducing water consumption) include the following: (1) countries that agreed to reduce carbon emissions (by ratifying the Kyoto protocol) find that one of the most effective ways to do so is to improve plant efficiency; (2) countries that import fuel (e.g., Japan) need highly efficient plants to compensate for higher coal costs; (3) countries with particularly large and growing energy demands, such as China and India, need large, efficient plants; (4) countries with large supplies of low-rank coals, such as Germany, need efficient processes to use such low-energy coals. Some countries have policies that encourage or mandate reduced water consumption - either directly or indirectly. For example, the European Union encourages increased efficiency through its cogeneration directive, which requires member states to assess their

Elcock, D. (Environmental Science Division)

2011-05-09T23:59:59.000Z

60

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

SciTech Connect (OSTI)

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.

NONE

1995-12-01T23:59:59.000Z

Note: This page contains sample records for the topic "igcc coal plants" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


61

Arch Coal upgrades a classic West Virginia prep plant  

SciTech Connect (OSTI)

Holden No. 22 coal preparation plant evolves from 1970s 'by zero' technology to modern, efficient fine coal recovery that includes a de-slime dense-media cyclone, compound spiral circuit. 3 figs.

Bethell, P.J.; Waine, C.

2008-07-15T23:59:59.000Z

62

Advanced Coal Wind Hybrid: Economic Analysis  

E-Print Network [OSTI]

G+CC+CCS IGCC+CCS FT HVAC HVDC IGCC PC advanced coal-windthan the Base Case (HVDC Only Transmission) Sensitivity toused in the FEAST model. HVDC transmission lines have lower

Phadke, Amol

2008-01-01T23:59:59.000Z

63

Illinois Coal Revival Program (Illinois)  

Broader source: Energy.gov [DOE]

The Illinois Coal Revival Program is a grants program providing partial funding to assist with the development of new, coal-fueled electric generation capacity and coal gasification or IGCC units...

64

Coal demonstration plants. Quarterly report, July-September 1979  

SciTech Connect (OSTI)

The status of two coal liquefaction demonstration plants and of four coal gasification demonstration plants is reviewed under the following headings: company involved, contract number, funding, process name, process description, flowsheet, schedule, history and progress during the July-September quarter, 1979. Supporting projects in coal feeding systems, valves, grinding equipment, instrumentation, process control and water treatment are discussed in a similar way. Conceptual design work on commercial plants for coal to methanol and for a HYGAS high BTU gas plant were continued. (LTN)

None

1980-07-01T23:59:59.000Z

65

Performance and risks of advanced pulverized-coal plants  

SciTech Connect (OSTI)

This article is based on an in-depth report of the same title published by the IEA Clean Coal Centre, CCC/135 (see Coal Abstracts entry Sep 2008 00535). It discusses the commercial, developmental and future status of pulverized fuel power plants including subcritical supercritical and ultra supercritical systems of pulverized coal combustion, the most widely used technology in coal-fired power generation. 1 fig., 1 tab.

Nalbandian, H. [IEA Clean Coal Centre, London (United Kingdom)

2009-07-01T23:59:59.000Z

66

Sensor placement algorithm development to maximize the efficiency of acid gas removal unit for integrated gasification combined cycle (IGCC) power plant with CO{sub 2} capture  

SciTech Connect (OSTI)

Future integrated gasification combined cycle (IGCC) power plants with CO{sub 2} capture will face stricter operational and environmental constraints. Accurate values of relevant states/outputs/disturbances are needed to satisfy these constraints and to maximize the operational efficiency. Unfortunately, a number of these process variables cannot be measured while a number of them can be measured, but have low precision, reliability, or signal-to-noise ratio. In this work, a sensor placement (SP) algorithm is developed for optimal selection of sensor location, number, and type that can maximize the plant efficiency and result in a desired precision of the relevant measured/unmeasured states. In this work, an SP algorithm is developed for an selective, dual-stage Selexol-based acid gas removal (AGR) unit for an IGCC plant with pre-combustion CO{sub 2} capture. A comprehensive nonlinear dynamic model of the AGR unit is developed in Aspen Plus Dynamics® (APD) and used to generate a linear state-space model that is used in the SP algorithm. The SP algorithm is developed with the assumption that an optimal Kalman filter will be implemented in the plant for state and disturbance estimation. The algorithm is developed assuming steady-state Kalman filtering and steady-state operation of the plant. The control system is considered to operate based on the estimated states and thereby, captures the effects of the SP algorithm on the overall plant efficiency. The optimization problem is solved by Genetic Algorithm (GA) considering both linear and nonlinear equality and inequality constraints. Due to the very large number of candidate sets available for sensor placement and because of the long time that it takes to solve the constrained optimization problem that includes more than 1000 states, solution of this problem is computationally expensive. For reducing the computation time, parallel computing is performed using the Distributed Computing Server (DCS®) and the Parallel Computing® toolbox from Mathworks®. In this presentation, we will share our experience in setting up parallel computing using GA in the MATLAB® environment and present the overall approach for achieving higher computational efficiency in this framework.

Paul, P.; Bhattacharyya, D.; Turton, R.; Zitney, S.

2012-01-01T23:59:59.000Z

67

Sensor placement algorithm development to maximize the efficiency of acid gas removal unit for integrated gasifiction combined sycle (IGCC) power plant with CO2 capture  

SciTech Connect (OSTI)

Future integrated gasification combined cycle (IGCC) power plants with CO{sub 2} capture will face stricter operational and environmental constraints. Accurate values of relevant states/outputs/disturbances are needed to satisfy these constraints and to maximize the operational efficiency. Unfortunately, a number of these process variables cannot be measured while a number of them can be measured, but have low precision, reliability, or signal-to-noise ratio. In this work, a sensor placement (SP) algorithm is developed for optimal selection of sensor location, number, and type that can maximize the plant efficiency and result in a desired precision of the relevant measured/unmeasured states. In this work, an SP algorithm is developed for an selective, dual-stage Selexol-based acid gas removal (AGR) unit for an IGCC plant with pre-combustion CO{sub 2} capture. A comprehensive nonlinear dynamic model of the AGR unit is developed in Aspen Plus Dynamics® (APD) and used to generate a linear state-space model that is used in the SP algorithm. The SP algorithm is developed with the assumption that an optimal Kalman filter will be implemented in the plant for state and disturbance estimation. The algorithm is developed assuming steady-state Kalman filtering and steady-state operation of the plant. The control system is considered to operate based on the estimated states and thereby, captures the effects of the SP algorithm on the overall plant efficiency. The optimization problem is solved by Genetic Algorithm (GA) considering both linear and nonlinear equality and inequality constraints. Due to the very large number of candidate sets available for sensor placement and because of the long time that it takes to solve the constrained optimization problem that includes more than 1000 states, solution of this problem is computationally expensive. For reducing the computation time, parallel computing is performed using the Distributed Computing Server (DCS®) and the Parallel Computing® toolbox from Mathworks®. In this presentation, we will share our experience in setting up parallel computing using GA in the MATLAB® environment and present the overall approach for achieving higher computational efficiency in this framework.

Paul, P.; Bhattacharyya, D.; Turton, R.; Zitney, S.

2012-01-01T23:59:59.000Z

68

Boiler Materials for Ultrasupercritical Coal Power Plants  

SciTech Connect (OSTI)

The U.S. Department of Energy (DOE) and the Ohio Coal Development Office (OCDO) have recently initiated a project aimed at identifying, evaluating, and qualifying the materials needed for the construction of the critical components of coal-fired boilers capable of operating at much higher efficiencies than current generation of supercritical plants. This increased efficiency is expected to be achieved principally through the use of ultrasupercritical steam conditions (USC). A limiting factor in this can be the materials of construction. The project goal is to assess/develop materials technology that will enable achieving turbine throttle steam conditions of 760 C (1400 F)/35 MPa (5000 psi). This goal seems achievable based on a preliminary assessment of material capabilities. The project is further intended to build further upon the alloy development and evaluation programs that have been carried out in Europe and Japan. Those programs have identified ferritic steels capable of meeting the strength requirements of USC plants up to approximately 620 C (1150 F) and nickel-based alloys suitable up to 700 C (1300 F). In this project, the maximum temperature capabilities of these and other available high-temperature alloys are being assessed to provide a basis for materials selection and application under a range of conditions prevailing in the boiler. This report provides a quarterly status report for the period of October 1 to December 30, 2005.

R. Viswanathan; K. Coleman; J. Shingledecker; J. Sarver; G. Stanko; M. Borden; W. Mohn; S. Goodstine; I. Perrin

2006-01-31T23:59:59.000Z

69

BOILER MATERIALS FOR ULTRASUPERCRITICAL COAL POWER PLANTS  

SciTech Connect (OSTI)

The U.S. Department of Energy (DOE) and the Ohio Coal Development Office (OCDO) have recently initiated a project aimed at identifying, evaluating, and qualifying the materials needed for the construction of the critical components of coal-fired boilers capable of operating at much higher efficiencies than current generation of supercritical plants. This increased efficiency is expected to be achieved principally through the use of ultrasupercritical steam conditions (USC). The project goal initially was to assess/develop materials technology that will enable achieving turbine throttle steam conditions of 760 C (1400 F)/35 MPa (5000 psi), although this goal for the main steam temperature had to be revised down to 732 C (1350 F), based on a preliminary assessment of material capabilities. The project is intended to build further upon the alloy development and evaluation programs that have been carried out in Europe and Japan. Those programs have identified ferritic steels capable of meeting the strength requirements of USC plants up to approximately 620 C (1150 F) and nickel-based alloys suitable up to 700 C (1300 F). In this project, the maximum temperature capabilities of these and other available high-temperature alloys are being assessed to provide a basis for materials selection and application under a range of conditions prevailing in the boiler. This report provides a quarterly status report for the period of July 1 to September 30, 2004.

R. Viswanathan; K. Coleman; J. Shingledecker; J. Sarver; G. Stanko; M. Borden; W. Mohn; S. Goodstine; I. Perrin

2005-04-27T23:59:59.000Z

70

Boiler Materials for Ultrasupercritical Coal Power Plants  

SciTech Connect (OSTI)

The U.S. Department of Energy (DOE) and the Ohio Coal Development Office (OCDO) have recently initiated a project aimed at identifying, evaluating, and qualifying the materials needed for the construction of the critical components of coal-fired boilers capable of operating at much higher efficiencies than current generation of supercritical plants. This increased efficiency is expected to be achieved principally through the use of ultrasupercritical steam conditions (USC). The project goal initially was to assess/develop materials technology that will enable achieving turbine throttle steam conditions of 760 C (1400 F)/35 MPa (5000 psi), although this goal for the main steam temperature had to be revised down to 732 C (1350 F), based on a preliminary assessment of material capabilities. The project is intended to build further upon the alloy development and evaluation programs that have been carried out in Europe and Japan. Those programs have identified ferritic steels capable of meeting the strength requirements of USC plants up to approximately 620 C (1150 F) and nickel-based alloys suitable up to 700 C (1300 F). In this project, the maximum temperature capabilities of these and other available high-temperature alloys are being assessed to provide a basis for materials selection and application under a range of conditions prevailing in the boiler. This report provides a quarterly status report for the period of July 1 to September 30, 2004.

R. Viswanathan; J. Sarver; M. Borden; K. Coleman; J. Blough; S. Goodstine; R.W. Swindeman; W. Mohn; I. Perrin

2003-04-21T23:59:59.000Z

71

BOILER MATERIALS FOR ULTRASUPERCRITICAL COAL POWER PLANTS  

SciTech Connect (OSTI)

The U.S. Department of Energy (DOE) and the Ohio Coal Development Office (OCDO) have recently initiated a project aimed at identifying, evaluating, and qualifying the materials needed for the construction of the critical components of coal-fired boilers capable of operating at much higher efficiencies than current generation of supercritical plants. This increased efficiency is expected to be achieved principally through the use of ultrasupercritical steam conditions (USC). A limiting factor in this can be the materials of construction. The project goal is to assess/develop materials technology that will enable achieving turbine throttle steam conditions of 760 C (1400 F)/35 MPa (5000 psi). This goal seems achievable based on a preliminary assessment of material capabilities. The project is further intended to build further upon the alloy development and evaluation programs that have been carried out in Europe and Japan. Those programs have identified ferritic steels capable of meeting the strength requirements of USC plants up to approximately 620 C (1150 F) and nickel-based alloys suitable up to 700 C (1300 F). In this project, the maximum temperature capabilities of these and other available high-temperature alloys are being assessed to provide a basis for materials selection and application under a range of conditions prevailing in the boiler. This report provides a quarterly status report for the period of April 1 to June 30, 2005.

R. Viswanathan; K. Coleman; J. Shingledecker; J. Sarver; G. Stanko; M. Borden; W. Mohn; S. Goodstine; I. Perrin

2005-08-01T23:59:59.000Z

72

Boiler Materials For Ultrasupercritical Coal Power Plants  

SciTech Connect (OSTI)

The U.S. Department of Energy (DOE) and the Ohio Coal Development Office (OCDO) have recently initiated a project aimed at identifying, evaluating, and qualifying the materials needed for the construction of the critical components of coal-fired boilers capable of operating at much higher efficiencies than current generation of supercritical plants. This increased efficiency is expected to be achieved principally through the use of ultrasupercritical steam conditions (USC). A limiting factor in this can be the materials of construction. The project goal is to assess/develop materials technology that will enable achieving turbine throttle steam conditions of 760 C (1400 F)/35 MPa (5000 psi). This goal seems achievable based on a preliminary assessment of material capabilities. The project is further intended to build further upon the alloy development and evaluation programs that have been carried out in Europe and Japan. Those programs have identified ferritic steels capable of meeting the strength requirements of USC plants up to approximately 620 C (1150 F) and nickel-based alloys suitable up to 700 C (1300 F). In this project, the maximum temperature capabilities of these and other available high-temperature alloys are being assessed to provide a basis for materials selection and application under a range of conditions prevailing in the boiler. This report provides a quarterly status report for the period of July 1 to September 30, 2006.

R. Viswanathan; K. Coleman; J. Shingledecker; J. Sarver; G. Stanko; M. Borden; W. Mohn; S. Goodstine; I. Perrin

2006-09-30T23:59:59.000Z

73

Boiler Materials for Ultrasupercritical Coal Power Plants  

SciTech Connect (OSTI)

The U.S. Department of Energy (DOE) and the Ohio Coal Development Office (OCDO) have recently initiated a project aimed at identifying, evaluating, and qualifying the materials needed for the construction of the critical components of coal-fired boilers capable of operating at much higher efficiencies than current generation of supercritical plants. This increased efficiency is expected to be achieved principally through the use of ultrasupercritical steam conditions (USC). A limiting factor in this can be the materials of construction. The project goal is to assess/develop materials technology that will enable achieving turbine throttle steam conditions of 760 C (1400 F)/35 MPa (5000 psi). This goal seems achievable based on a preliminary assessment of material capabilities. The project is further intended to build further upon the alloy development and evaluation programs that have been carried out in Europe and Japan. Those programs have identified ferritic steels capable of meeting the strength requirements of USC plants up to approximately 620 C (1150 F) and nickel-based alloys suitable up to 700 C (1300 F). In this project, the maximum temperature capabilities of these and other available high-temperature alloys are being assessed to provide a basis for materials selection and application under a range of conditions prevailing in the boiler. This report provides a quarterly status report for the period of April 1 to June 30, 2006.

R. Viswanathan; K. Coleman; J. Shingledecker; J. Sarver; G. Stanko; M. Borden; W. Mohn; S. Goodstine; I. Perrin

2006-07-17T23:59:59.000Z

74

Boiler Materials for Ultrasupercritical Coal Power Plants  

SciTech Connect (OSTI)

The U.S. Department of Energy (DOE) and the Ohio Coal Development Office (OCDO) have recently initiated a project aimed at identifying, evaluating, and qualifying the materials needed for the construction of the critical components of coal-fired boilers capable of operating at much higher efficiencies than current generation of supercritical plants. This increased efficiency is expected to be achieved principally through the use of ultrasupercritical steam conditions (USC). A limiting factor in this can be the materials of construction. The project goal is to assess/develop materials technology that will enable achieving turbine throttle steam conditions of 760 C (1400 F)/35 MPa (5000 psi). This goal seems achievable based on a preliminary assessment of material capabilities. The project is further intended to build further upon the alloy development and evaluation programs that have been carried out in Europe and Japan. Those programs have identified ferritic steels capable of meeting the strength requirements of USC plants up to approximately 620 C (1150 F) and nickel-based alloys suitable up to 700 C (1300 F). In this project, the maximum temperature capabilities of these and other available high-temperature alloys are being assessed to provide a basis for materials selection and application under a range of conditions prevailing in the boiler. This report provides a quarterly status report for the period of January 1 to March 31, 2006.

R. Viswanathan; K. Coleman; J. Shingledecker; J. Sarver; G. Stanko; M. Borden; W. Mohn; S. Goodstine; I. Perrin

2006-04-20T23:59:59.000Z

75

BOILER MATERIALS FOR ULTRASUPERCRITICAL COAL POWER PLANTS  

SciTech Connect (OSTI)

The U.S. Department of Energy (DOE) and the Ohio Coal Development Office (OCDO) have recently initiated a project aimed at identifying, evaluating, and qualifying the materials needed for the construction of the critical components of coal-fired boilers capable of operating at much higher efficiencies than current generation of supercritical plants. This increased efficiency is expected to be achieved principally through the use of ultrasupercritical steam conditions (USC). A limiting factor in this can be the materials of construction. The project goal is to assess/develop materials technology that will enable achieving turbine throttle steam conditions of 760 C (1400 F)/35 MPa (5000 psi). This goal seems achievable based on a preliminary assessment of material capabilities. The project is further intended to build further upon the alloy development and evaluation programs that have been carried out in Europe and Japan. Those programs have identified ferritic steels capable of meeting the strength requirements of USC plants up to approximately 620 C (1150 F) and nickel-based alloys suitable up to 700 C (1300 F). In this project, the maximum temperature capabilities of these and other available high-temperature alloys are being assessed to provide a basis for materials selection and application under a range of conditions prevailing in the boiler. This report provides a quarterly status report for the period of July 1 to September 30, 2005.

R. Viswanathan; K. Coleman; J. Shingledecker; J. Sarver; G. Stanko; M. Borden; W. Mohn; S. Goodstine; I. Perrin

2005-10-27T23:59:59.000Z

76

BOILER MATERIALS FOR ULTRASUPERCRITICAL COAL POWER PLANTS  

SciTech Connect (OSTI)

The U.S. Department of Energy (DOE) and the Ohio Coal Development Office (OCDO) have recently initiated a project aimed at identifying, evaluating, and qualifying the materials needed for the construction of the critical components of coal-fired boilers capable of operating at much higher efficiencies than current generation of supercritical plants. This increased efficiency is expected to be achieved principally through the use of ultrasupercritical steam conditions (USC). The project goal initially was to assess/develop materials technology that will enable achieving turbine throttle steam conditions of 760 C (1400 F)/35 MPa (5000 psi), although this goal for the main steam temperature had to be revised down to 732 C (1350 F), based on a preliminary assessment of material capabilities. The project is intended to build further upon the alloy development and evaluation programs that have been carried out in Europe and Japan. Those programs have identified ferritic steels capable of meeting the strength requirements of USC plants up to approximately 620 C (1150 F) and nickel-based alloys suitable up to 700 C (1300 F). In this project, the maximum temperature capabilities of these and other available high-temperature alloys are being assessed to provide a basis for materials selection and application under a range of conditions prevailing in the boiler. This report provides a quarterly status report for the period of October 1 to December 30, 2003.

R. Viswanathan; K. Coleman; J. Shingledecker; J. Sarver; G. Stanko; W. Mohn; M. Borden; S. Goodstine; I. Perrin

2004-04-23T23:59:59.000Z

77

BOILER MATERIALS FOR ULTRASUPERCRITICAL COAL POWER PLANTS  

SciTech Connect (OSTI)

The U.S. Department of Energy (DOE) and the Ohio Coal Development Office (OCDO) have recently initiated a project aimed at identifying, evaluating, and qualifying the materials needed for the construction of the critical components of coal-fired boilers capable of operating at much higher efficiencies than current generation of supercritical plants. This increased efficiency is expected to be achieved principally through the use of ultrasupercritical steam conditions (USC). The project goal initially was to assess/develop materials technology that will enable achieving turbine throttle steam conditions of 760 C (1400 F)/35 MPa (5000 psi), although this goal for the main steam temperature had to be revised down to 732 C (1350 F), based on a preliminary assessment of material capabilities. The project is intended to build further upon the alloy development and evaluation programs that have been carried out in Europe and Japan. Those programs have identified ferritic steels capable of meeting the strength requirements of USC plants up to approximately 620 C (1150 F) and nickel-based alloys suitable up to 700 C (1300 F). In this project, the maximum temperature capabilities of these and other available high-temperature alloys are being assessed to provide a basis for materials selection and application under a range of conditions prevailing in the boiler. This report provides a quarterly status report for the period of October 1 to December 30, 2003.

K. Coleman; R. Viswanathan; J. Shingledecker; J. Sarver; G. Stanko; W. Mohn; M. Borden; S. Goodstine; I. Perrin

2004-01-23T23:59:59.000Z

78

BOILER MATERIALS FOR ULTRASUPERCRITICAL COAL POWER PLANTS  

SciTech Connect (OSTI)

The U.S. Department of Energy (DOE) and the Ohio Coal Development Office (OCDO) have recently initiated a project aimed at identifying, evaluating, and qualifying the materials needed for the construction of the critical components of coal-fired boilers capable of operating at much higher efficiencies than current generation of supercritical plants. This increased efficiency is expected to be achieved principally through the use of ultrasupercritical steam conditions (USC). The project goal initially was to assess/develop materials technology that will enable achieving turbine throttle steam conditions of 760 C (1400 F)/35 MPa (5000 psi), although this goal for the main steam temperature had to be revised down to 732 C (1350 F), based on a preliminary assessment of material capabilities. The project is intended to build further upon the alloy development and evaluation programs that have been carried out in Europe and Japan. Those programs have identified ferritic steels capable of meeting the strength requirements of USC plants up to approximately 620 C (1150 F) and nickel-based alloys suitable up to 700 C (1300 F). In this project, the maximum temperature capabilities of these and other available high-temperature alloys are being assessed to provide a basis for materials selection and application under a range of conditions prevailing in the boiler. This report provides a quarterly status report for the period of July 1 to September 30, 2004.

R. Viswanathan; K. Coleman; J. Shingledecker; J. Sarver; G. Stanko; M. Borden; W. Mohn; S. Goodstine; I. Perrin

2005-01-31T23:59:59.000Z

79

E-Print Network 3.0 - advanced igcc lignite Sample Search Results  

Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

an IGCC plant with ... Source: Massachusetts Institute of Technology, Energy Laboratory, Carbon Sequestration Initiative Collection: Environmental Sciences and Ecology 4 An...

80

EIS-0318: Kentucky Pioneer Integrated Gasification Combined Cycle (IGCC) Demonstration Project, Trapp, Kentucky (Clark County)  

Broader source: Energy.gov [DOE]

This EIS analyzes DOE's decision to provide cost-shared financial support for The Kentucky Pioneer IGCC Demonstration Project, an electrical power station demonstrating use of a Clean Coal Technology in Clark County, Kentucky.

Note: This page contains sample records for the topic "igcc coal plants" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


81

Commercial gasifier for IGCC applications study report  

SciTech Connect (OSTI)

This was a scoping-level study to identify and characterize the design features of fixed-bed gasifiers appearing most important for a gasifier that was to be (1) potentially commercially attractive, and (2) specifically intended for us in integrated coal gasification/combined-cycle (IGCC) applications. It also performed comparative analyses on the impact or value of these design features and on performance characteristics options of the whole IGCC system since cost, efficiency, environmental traits, and operability -- on a system basis -- are what is really important. The study also reviewed and evaluated existing gasifier designs, produced a conceptual-level gasifier design, and generated a moderately advanced system configuration that was utilized as the reference framework for the comparative analyses. In addition, technical issues and knowledge gaps were defined. 70 figs., 31 tabs.

Notestein, J.E.

1990-06-01T23:59:59.000Z

82

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

SciTech Connect (OSTI)

Conventional coal-burning power plants are major contributors of excess CO2 to the atmospheric inventory. Because such plants are stationary, they are particularly amenable to CO2 capture and disposal by deep injection into confined geologic formations. However, the energy penalty for CO2 separation and compression is steep, and could lead to a 30-40 percent reduction in useable power output. Integrated gas combined cycle (IGCC) plants are thermodynamically more efficient, i.e.,produce less CO2 for a given power output, and are more suitable for CO2 capture. Therefore, if CO2 capture and deep subsurface disposal were to be considered seriously, the preferred approach would be to build replacement IGCC plants with integrated CO2 capture, rather than retrofit existing conventional plants. Coal contains minor quantities of sulfur and nitrogen compounds, which are of concern, as their release into the atmosphere leads to the formation of urban ozone and acid rain, the destruction of stratospheric ozone, and global warming. Coal also contains many trace elements that are potentially hazardous to human health and the environment. During CO2 separation and capture, these constituents could inadvertently contaminate the separated CO2 and be co-injected. The concentrations and speciation of the co-injected contaminants would differ markedly, depending on whether CO2 is captured during the operation of a conventional or an IGCC plant, and the specific nature of the plant design and CO2 separation technology. However, regardless of plant design or separation procedures, most of the hazardous constituents effectively partition into the solid waste residue. This would lead to an approximately two order of magnitude reduction in contaminant concentration compared with that present in the coal. Potential exceptions are Hg in conventional plants, and Hg and possibly Cd, Mo and Pb in IGCC plants. CO2 capture and injection disposal could afford an opportunity to deliberately capture environmental pollutants in the gaseous state and co-inject them with the CO2, in order to mitigate problems associated with solid waste disposal in surface impoundments. Under such conditions, the injected pollutant concentrations could be roughly equivalent to their concentrations in the coal feed. The fate of the injected contaminants can only be determined through further testing and geochemical modeling. However, the concentrations of inadvertent contaminants in the injected CO2 would probably be comparable to their ambient concentrations in confining shales of the injection zone. In general, the aqueous concentrations of hazardous constituents in distal parts of the injection zone, regardless of source, are likely to be limited by equilibrium with respect to coexisting solid phases under the acid conditions induced by the dissolved high pressure CO2, rather than by the initial concentrations of injected contaminants. Therefore, even if a deliberate policy of contaminant recovery and injection were to be pursued, water quality in USDWs would more likely depend on thermodynamic controls governing aqueous contaminant concentrations in the presence of high pressure CO2 rather than in the injected CO2. The conclusions reached in this report are preliminary, and should be confirmed through more comprehensive data evaluation and supporting geochemical modeling.

Apps, J.A.

2006-02-23T23:59:59.000Z

83

New coal technology to flourish at Kentucky plant  

SciTech Connect (OSTI)

Within four years a 76 MW (net) advanced supercritical coal unit, TC2, will go into service at the Trimble County power plant on the Ohio River near Louiseville, KY, USA. The unit is designed to burn a blend of eastern bituminous and western sub-bituminous Powder River Basin coals. TC2 is one of four US power plants to receive a $125 m tax credit under the 2005 EPACT Qualifying Advanced Coal Program for high efficiency and low emission generating units. Trimble County is owned and operated by E.ON US subsidiaries Kentucky Utilities and Louiseville Gas & Electric. It was originally designed to accommodate four 500 MW coal-fired units fired by bituminous coal from the Illinois Basin. 1 photo.

Blankinship, S.

2007-08-15T23:59:59.000Z

84

Combustion Engineering IGCC Repowering Project  

SciTech Connect (OSTI)

C-E gasification process uses an entrained-flow, two-stage, slagging bottom gasifier. Figure 1 shows a schematic of the gasifier concept. Some of the coal and all of the char is fed to the combustor section, while the remaining coal is fed to the reducter section of the gasifier. The coal and char in the combustor is mixed with air and the fuel-rich mixture is burned creating the high temperature necessary to gasify the coal and melt the mineral matter in the coal. The slag flows through a slag tap at the bottom of the combustor into a water-filled slag tank where it is quenched and transformed into an inert, glassy, granular material. This vitrified slag is non-leaching, making it easy to dispose of in an environmentally acceptable manner. The hot gas leaving the combustor enters the second stage called the reductor. In the reducter, the char gasification occurs along the length of the reductor zone until the temperature falls to a point where the gasification kinetics become too slow. Once the gas temperature reaches this level, essentially no further gasification takes place and the gases subsequently are cooled with convective surface to a temperature low enough to enter the cleanup system. Nearly all of the liberated energy from the coal that does not produce fuel gas is collected and recovered with steam generating surface either in the walls of the vessel or by conventional boiler convective surfaces in the backpass of the gasifier. A mixture of unburned carbon and ash (called char) is carried out of the gasifier with the product gas strewn. The char is collected and recycled back to the gasifier where it is consumed. Thus, there is no net production of char which results in negligible carbon loss. The product gas enters a desulfurization system where it is cleaned of sulfur compounds present in the fuel gas. The clean fuel gas is now available for use in the gas turbine combuster for an integrated coal gasification combined cycle (IGCC) application.

Andrus, H.E.; Thibeault, P.R.; Gibson, C.R.

1992-11-01T23:59:59.000Z

85

Combustion Engineering IGCC Repowering Project  

SciTech Connect (OSTI)

C-E gasification process uses an entrained-flow, two-stage, slagging bottom gasifier. Figure 1 shows a schematic of the gasifier concept. Some of the coal and all of the char is fed to the combustor section, while the remaining coal is fed to the reducter section of the gasifier. The coal and char in the combustor is mixed with air and the fuel-rich mixture is burned creating the high temperature necessary to gasify the coal and melt the mineral matter in the coal. The slag flows through a slag tap at the bottom of the combustor into a water-filled slag tank where it is quenched and transformed into an inert, glassy, granular material. This vitrified slag is non-leaching, making it easy to dispose of in an environmentally acceptable manner. The hot gas leaving the combustor enters the second stage called the reductor. In the reducter, the char gasification occurs along the length of the reductor zone until the temperature falls to a point where the gasification kinetics become too slow. Once the gas temperature reaches this level, essentially no further gasification takes place and the gases subsequently are cooled with convective surface to a temperature low enough to enter the cleanup system. Nearly all of the liberated energy from the coal that does not produce fuel gas is collected and recovered with steam generating surface either in the walls of the vessel or by conventional boiler convective surfaces in the backpass of the gasifier. A mixture of unburned carbon and ash (called char) is carried out of the gasifier with the product gas strewn. The char is collected and recycled back to the gasifier where it is consumed. Thus, there is no net production of char which results in negligible carbon loss. The product gas enters a desulfurization system where it is cleaned of sulfur compounds present in the fuel gas. The clean fuel gas is now available for use in the gas turbine combuster for an integrated coal gasification combined cycle (IGCC) application.

Andrus, H.E.; Thibeault, P.R.; Gibson, C.R.

1992-01-01T23:59:59.000Z

86

Characterization of feed coal and coal combustion products from power plants in Indiana and Kentucky  

SciTech Connect (OSTI)

The US Geological Survey, Kentucky Geological Survey, and the University of Kentucky Center for Applied Energy Research are collaborating with Indiana and Kentucky utilities to determine the physical and chemical properties of feed coal and coal combustion products (CCP) from three coal-fired power plants. These three plants are designated as Units K1, K2, and I1 and burn high-, moderate-, and low-sulfur coals, respectively. Over 200 samples of feed coal and CCP were analyzed by various chemical and mineralogical methods to determine mode of occurrence and distribution of trace elements in the CCP. Generally, feed coals from all 3 Units contain mostly well-crystallized kaolinite and quartz. Comparatively, Unit K1 feed coals have higher amounts of carbonates, pyrite and sphalerite. Unit K2 feed coals contain higher kaolinite and illite/muscovite when compared to Unit K1 coals. Unit I1 feed coals contain beta-form quartz and alumino-phosphates with minor amounts of calcite, micas, anatase, and zircon when compared to K1 and K2 feed coals. Mineralogy of feed coals indicate that the coal sources for Units K1 and K2 are highly variable, with Unit K1 displaying the greatest mineralogic variability; Unit I1 feed coal however, displayed little mineralogic variation supporting a single source. Similarly, element contents of Units K1 and K2 feed coals show more variability than those of Unit I1. Fly ash samples from Units K1 and K2 consist mostly of glass, mullite, quartz, and spines group minerals. Minor amounts of illite/muscovite, sulfates, hematite, and corundum are also present. Spinel group minerals identified include magnetite, franklinite, magnesioferrite, trevorite, jacobisite, and zincochromite. Scanning Electron Microscope analysis reveals that most of the spinel minerals are dendritic intergrowths within aluminum silicate glass. Unit I1 fly ash samples contain glass, quartz, perovskite, lime, gehlenite, and apatite with minor amounts of periclase, anhydrite, carbonates, pyroxenes, and spinels. The abundant Ca mineral phases in the Unit I1 fly ashes are attributed to the presence of carbonate, clay and phosphate minerals in the coal.

Brownfield, M.E.; Affolter, R.H.; Cathcart, J.D.; O'Connor, J.T.; Brownfield, I.K.

1999-07-01T23:59:59.000Z

87

An efficient process for recovery of fine coal from tailings of coal washing plants  

SciTech Connect (OSTI)

Gravity concentration of hard lignites using conventional jigs and heavy media separation equipment is prone to produce coal-rich fine tailings. This study aims to establish a fine coal recovery process of very high efficiency at reasonable capital investment and operational costs. The technical feasibility to upgrade the properties of the predeslimed fine refuse of a lignite washing plant with 35.9% ash content was investigated by employing gravity separation methods. The laboratory tests carried out with the combination of shaking table and Mozley multi-gravity separator (MGS) revealed that the clean coal with 18% ash content on dry basis could be obtained with 58.9% clean coal recovery by the shaking table stage and 4.1% clean coal recovery by MGS stage, totaling to the sum of 63.0% clean coal recovery from a predeslimed feed. The combustible recovery and the organic efficiency of the shaking table + MGS combination were 79.5% and 95.5%, respectively. Based on the results of the study, a flow sheet of a high-efficiency fine coal recovery process was proposed, which is also applicable to the coal refuse pond slurry of a lignite washing plant.

Cicek, T.; Cocen, I.; Engin, V.T.; Cengizler, H. [Dokuz Eylul University, Izmir (Turkey). Dept. for Mining Engineering

2008-07-01T23:59:59.000Z

88

Assessment of coal gasification/hot gas cleanup based advanced gas turbine systems  

SciTech Connect (OSTI)

The major objectives of the joint SCS/DOE study of air-blown gasification power plants with hot gas cleanup are to: (1) Evaluate various power plant configurations to determine if an air-blown gasification-based power plant with hot gas cleanup can compete against pulverized coal with flue gas desulfurization for baseload expansion at Georgia Power Company's Plant Wansley; (2) determine if air-blown gasification with hot gas cleanup is more cost effective than oxygen-blown IGCC with cold gas cleanup; (3) perform Second-Law/Thermoeconomic Analysis of air-blown IGCC with hot gas cleanup and oxygen-blown IGCC with cold gas cleanup; (4) compare cost, performance, and reliability of IGCC based on industrial gas turbines and ISTIG power island configurations based on aeroderivative gas turbines; (5) compare cost, performance, and reliability of large (400 MW) and small (100 to 200 MW) gasification power plants; and (6) compare cost, performance, and reliability of air-blown gasification power plants using fluidized-bed gasifiers to air-blown IGCC using transport gasification and pressurized combustion.

Not Available

1990-12-01T23:59:59.000Z

89

Accelerating the deployment of cleaner coal plants  

SciTech Connect (OSTI)

The dearth of commercial operating experience for advanced coal-fired facilities is forcing their early adopters and builders to use long development cycles and pay high costs for unique engineering design studies. A broad-based industry collaborative effort fostered by EPRI to address this issue (CoalFleet for Tomorrow) is beginning to show results. 3 figs.

Parkes, J.; Holt, N.; Phillips, J.

2008-02-15T23:59:59.000Z

90

Encoal mild coal gasification project: Commercial plant feasibility study  

SciTech Connect (OSTI)

In order to determine the viability of any Liquids from Coal (LFC) commercial venture, TEK-KOL and its partner, Mitsubishi Heavy Industries (MHI), have put together a technical and economic feasibility study for a commercial-size LFC Plant located at Zeigler Coal Holding Company`s North Rochelle Mine site. This resulting document, the ENCOAL Mild Coal Gasification Plant: Commercial Plant Feasibility Study, includes basic plant design, capital estimates, market assessment for coproducts, operating cost assessments, and overall financial evaluation for a generic Powder River Basin based plant. This document and format closely resembles a typical Phase II study as assembled by the TEK-KOL Partnership to evaluate potential sites for LFC commercial facilities around the world.

NONE

1997-07-01T23:59:59.000Z

91

Impact of Advanced Turbine Systems on coal-based power plants  

SciTech Connect (OSTI)

The advanced power-generation products currently under development in our program show great promise for ultimate commercial use. Four of these products are referred to in this paper: Integrated Gasification Combined Cycle (IGCC), Pressurized Fluidized Bed Combustion (PFBC), Externally Fired Combined Cycle (EFCC), and Integrated Gasification Fuel Cell (IGFC). Three of these products, IGCC, PFBC, and EFCC, rely on advanced gas turbines as a key enabling technology and the foundation for efficiencies in the range of 52 to 55 percent. DOE is funding the development of advanced gas turbines in the newly instituted Advanced Turbine Systems (ATS) Program, one of DOE`s highest priority natural gas initiatives. The turbines, which will have natural gas efficiencies of 60 percent, are being evaluated for coal gas compatibility as part of that program.

Bechtel, T.F.

1993-12-31T23:59:59.000Z

92

USE OF COAL DRYING TO REDUCE WATER CONSUMED IN PULVERIZED COAL POWER PLANTS  

SciTech Connect (OSTI)

Low rank fuels such as subbituminous coals and lignites contain significant amounts of moisture compared to higher rank coals. Typically, the moisture content of subbituminous coals ranges from 15 to 30 percent, while that for lignites is between 25 and 40 percent, where both are expressed on a wet coal basis. High fuel moisture has several adverse impacts on the operation of a pulverized coal generating unit. High fuel moisture results in fuel handling problems, and it affects heat rate, mass rate (tonnage) of emissions, and the consumption of water needed for evaporative cooling. This project deals with lignite and subbituminous coal-fired pulverized coal power plants, which are cooled by evaporative cooling towers. In particular, the project involves use of power plant waste heat to partially dry the coal before it is fed to the pulverizers. Done in a proper way, coal drying will reduce cooling tower makeup water requirements and also provide heat rate and emissions benefits. The technology addressed in this project makes use of the hot circulating cooling water leaving the condenser to heat the air used for drying the coal (Figure 1). The temperature of the circulating water leaving the condenser is usually about 49 C (120 F), and this can be used to produce an air stream at approximately 43 C (110 F). Figure 2 shows a variation of this approach, in which coal drying would be accomplished by both warm air, passing through the dryer, and a flow of hot circulating cooling water, passing through a heat exchanger located in the dryer. Higher temperature drying can be accomplished if hot flue gas from the boiler or extracted steam from the turbine cycle is used to supplement the thermal energy obtained from the circulating cooling water. Various options such as these are being examined in this investigation. This is the eleventh Quarterly Report for this project. The background and technical justification for the project are described, including potential benefits of reducing fuel moisture using power plant waste heat, prior to firing the coal in a pulverized coal boiler. During this last Quarter, the development of analyses to determine the costs and financial benefits of coal drying was continued. The details of the model and key assumptions being used in the economic evaluation are described in this report.

Edward Levy

2005-10-01T23:59:59.000Z

93

Effect of Coal Properties and Operation Conditions on Flow Behavior of Coal Slag in Entrained Flow Gasifiers: A Brief Review  

SciTech Connect (OSTI)

Integrated gasification combined cycle (IGCC) is a potentially promising clean technology with an inherent advantage of low emissions, since the process removes contaminants before combustion instead of from flue gas after combustion, as in a conventional coal steam plant. In addition, IGCC has potential for cost-effective carbon dioxide capture. Availability and high capital costs are the main challenges to making IGCC technology more competitive and fully commercial. Experiences from demonstrated IGCC plants show that, in the gasification system, low availability is largely due to slag buildup in the gasifier and fouling in the syngas cooler downstream of the gasification system. In the entrained flow gasifiers used in IGCC plants, the majority of mineral matter transforms to liquid slag on the wall of the gasifier and flows out the bottom. However, a small fraction of the mineral matter (as fly ash) is entrained with the raw syngas out of the gasifier to downstream processing. This molten/sticky fly ash could cause fouling of the syngas cooler. Therefore, it is preferable to minimize the quantity of fly ash and maximize slag. In addition, the hot raw syngas is cooled to convert any entrained molten fly slag to hardened solid fly ash prior to entering the syngas cooler. To improve gasification availability through better design and operation of the gasification process, better understanding of slag behavior and characteristics of the slagging process are needed. Slagging behavior is affected by char/ash properties, gas compositions in the gasifier, the gasifier wall structure, fluid dynamics, and plant operating conditions (mainly temperature and oxygen/carbon ratio). The viscosity of the slag is used to characterize the behavior of the slag flow and is the dominating factor to determine the probability that ash particles will stick. Slag viscosity strongly depends on the temperature and chemical composition of the slag. Because coal has varying ash content and composition, different operating conditions are required to maintain the slag flow and limit problems downstream. This report briefly introduces the IGCC process, the gasification process, and the main types and operating conditions of entrained flow gasifiers used in IGCC plants. This report also discusses the effects of coal ash and slag properties on slag flow and its qualities required for the entrained flow gasifier. Finally this report will identify the key operating conditions affecting slag flow behaviors, including temperature, oxygen/coal ratio, and flux agents.

Wang,Ping; Massoudi, Mehrdad

2011-01-01T23:59:59.000Z

94

Coal Integrated Gasification Fuel Cell System Study  

SciTech Connect (OSTI)

This study analyzes the performance and economics of power generation systems based on Solid Oxide Fuel Cell (SOFC) technology and fueled by gasified coal. System concepts that integrate a coal gasifier with a SOFC, a gas turbine, and a steam turbine were developed and analyzed for plant sizes in excess of 200 MW. Two alternative integration configurations were selected with projected system efficiency of over 53% on a HHV basis, or about 10 percentage points higher than that of the state-of-the-art Integrated Gasification Combined Cycle (IGCC) systems. The initial cost of both selected configurations was found to be comparable with the IGCC system costs at approximately $1700/kW. An absorption-based CO2 isolation scheme was developed, and its penalty on the system performance and cost was estimated to be less approximately 2.7% and $370/kW. Technology gaps and required engineering development efforts were identified and evaluated.

Chellappa Balan; Debashis Dey; Sukru-Alper Eker; Max Peter; Pavel Sokolov; Greg Wotzak

2004-01-31T23:59:59.000Z

95

USE OF COAL DRYING TO REDUCE WATER CONSUMED IN PULVERIZED COAL POWER PLANTS  

SciTech Connect (OSTI)

This is the twelfth Quarterly Report for this project. The background and technical justification for the project are described, including potential benefits of reducing fuel moisture using power plant waste heat, prior to firing the coal in a pulverized coal boiler. During this last Quarter, the development of analyses to determine the costs and financial benefits of coal drying was continued. The details of the model and key assumptions being used in the economic evaluation are described in this report and results are shown for a drying system utilizing a combination of waste heat from the condenser and thermal energy extracted from boiler flue gas.

Edward Levy; Harun Bilirgen; Ursla Levy; John Sale; Nenad Sarunac

2006-01-01T23:59:59.000Z

96

Dose assessment for various coals in the coal-fired power plant  

SciTech Connect (OSTI)

The radiation exposure of the public in the vicinity of a coal-fired power plant has been studied. The experimental data on uranium, thorium, and potassium content in selected coals from Serbia and Bosnia have been used to calculate the release rates of natural radionuclides from the power plant. A generalized model for analysis of radiological impact of an energy source that includes the two-dimensional version of the cloud model simulates the transport of radionuclides released to the atmosphere. The inhalation dose rates are assessed for various meteorological conditions.

Antic, D.; Sokcic-Kostic, M. (Institute of Nuclear Sciences Vinca, Belgrade (Yugoslavia))

1993-01-01T23:59:59.000Z

97

USE OF COAL DRYING TO REDUCE WATER CONSUMED IN PULVERIZED COAL POWER PLANTS  

SciTech Connect (OSTI)

U.S. low rank coals contain relatively large amounts of moisture, with the moisture content of subbituminous coals typically ranging from 15 to 30 percent and that for lignites from 25 and 40 percent. High fuel moisture has several adverse impacts on the operation of a pulverized coal generating unit, for it can result in fuel handling problems and it affects heat rate, stack emissions and maintenance costs. Theoretical analyses and coal test burns performed at a lignite fired power plant show that by reducing the fuel moisture, it is possible to improve boiler performance and unit heat rate, reduce emissions and reduce water consumption by the evaporative cooling tower. The economic viability of the approach and the actual impact of the drying system on water consumption, unit heat rate and stack emissions will depend critically on the design and operating conditions of the drying system. The present project evaluated the low temperature drying of high moisture coals using power plant waste heat to provide the energy required for drying. Coal drying studies were performed in a laboratory scale fluidized bed dryer to gather data and develop models on drying kinetics. In addition, analyses were carried out to determine the relative costs and performance impacts (in terms of heat rate, cooling tower water consumption and emissions) of drying along with the development of optimized drying system designs and recommended operating conditions.

Edward K. Levy; Nenad Sarunac; Harun Bilirgen; Hugo Caram

2006-03-01T23:59:59.000Z

98

Optimum Design of Coal Gasification Plants  

E-Print Network [OSTI]

This paper deals with the optimum design of heat recovery systems using the Texaco Coal Gasification Process (TCGP). TCGP uses an entrained type gasifier and produces hot gases at approximately 2500oF with high heat flux. This heat is removed...

Pohani, B. P.; Ray, H. P.; Wen, H.

1982-01-01T23:59:59.000Z

99

Using auxiliary gas power for CCS energy needs in retrofitted coal power plants  

E-Print Network [OSTI]

Post-combustion capture retrofits are expected to a near-term option for mitigating CO 2 emissions from existing coal-fired power plants. Much of the literature proposes using power from the existing coal plant and thermal ...

Bashadi, Sarah (Sarah Omer)

2010-01-01T23:59:59.000Z

100

Alaska coal gasification feasibility studies - Healy coal-to-liquids plant  

SciTech Connect (OSTI)

The Alaska Coal Gasification Feasibility Study entailed a two-phase analysis of the prospects for greater use of Alaska's abundant coal resources in industrial applications. Phase 1, Beluga Coal Gasification Feasibility Study (Report DOE/NETL 2006/1248) assessed the feasibility of using gasification technology to convert the Agrium fertilizer plant in Nikiski, Alaska, from natural gas to coal feedstock. The Phase 1 analysis evaluated coals from the Beluga field near Anchorage and from the Usibelli Coal Mine near Healy, both of which are low in sulfur and high in moisture. This study expands the results of Phase 1 by evaluating a similar sized gasification facility at the Usibelli Coal mine to supply Fischer-Tropsch (F-T) liquids to central Alaska. The plant considered in this study is small (14,640 barrels per day, bbl/d) compared to the recommended commercial size of 50,000 bbl/d for coal-to-liquid plants. The coal supply requirements for the Phase 1 analysis, four million tons per year, were assumed for the Phase 2 analysis to match the probable capacity of the Usibelli mining operations. Alaska refineries are of sufficient size to use all of the product, eliminating the need for F-T exports out of the state. The plant could produce marketable by-products such as sulfur as well as electric power. Slag would be used as backfill at the mine site and CO{sub 2} could be vented, captured or used for enhanced coalbed methane recovery. The unexpected curtailment of oil production from Prudhoe Bay in August 2006 highlighted the dependency of Alaskan refineries (with the exception of the Tesoro facility in Nikiski) on Alaska North Slope (ANS) crude. If the flow of oil from the North Slope declines, these refineries may not be able to meet the in-state needs for diesel, gasoline, and jet fuel. Additional reliable sources of essential fuel products would be beneficial. 36 refs., 14 figs., 29 tabs., 3 apps.

Lawrence Van Bibber; Charles Thomas; Robert Chaney [Research & Development Solutions, LLC (United States)

2007-07-15T23:59:59.000Z

Note: This page contains sample records for the topic "igcc coal plants" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


101

Flexible Coal: Evolution from Baseload to Peaking Plant (Brochure)  

SciTech Connect (OSTI)

Twenty-first century power systems, with higher penetration levels of low-carbon energy, smart grids, and other emerging technologies, will favor resources that have low marginal costs and provide system flexibility (e.g., the ability to cycle on and off to follow changes in variable renewable energy plant output). Questions remain about both the fate of coal plants in this scenario and whether they can cost-effectively continue to operate if they cycle routinely. The experience from the CGS plant demonstrates that coal plants can become flexible resources. This flexibility - namely the ability to cycle on and off and run at lower output (below 40% of capacity) - requires limited hardware modifications but extensive modifications to operational practice. Cycling does damage the plant and impact its life expectancy compared to baseload operations. Nevertheless, strategic modifications, proactive inspections and training programs, among other operational changes to accommodate cycling, can minimize the extent of damage and optimize the cost of maintenance. CGS's cycling, but not necessarily the associated price tag, is replicable. Context - namely, power market opportunities and composition of the generation fleet - will help determine for other coal plants the optimal balance between the level of cycling-related forced outages and the level of capital investment required to minimize those outages. Replicating CGS's experience elsewhere will likely require a higher acceptance of forced outages than regulators and plant operators are accustomed to; however, an increase in strategic maintenance can minimize the impact on outage rates.

Cochran, J.; Lew, D.; Kumar, N.

2013-12-01T23:59:59.000Z

102

Clean coal  

SciTech Connect (OSTI)

The article describes the physics-based techniques that are helping in clean coal conversion processes. The major challenge is to find a cost- effective way to remove carbon dioxide from the flue gas of power plants. One industrially proven method is to dissolve CO{sub 2} in the solvent monoethanolamine (MEA) at a temperature of 38{sup o}C and then release it from the solvent in another unit when heated to 150{sup o}C. This produces CO{sub 2} ready for sequestration. Research is in progress with alternative solvents that require less energy. Another technique is to use enriched oxygen in place of air in the combustion process which produces CO{sub 2} ready for sequestration. A process that is more attractive from an energy management viewpoint is to gasify coal so that it is partially oxidized, producing a fuel while consuming significantly less oxygen. Several IGCC schemes are in operation which produce syngas for use as a feedstock, in addition to electricity and hydrogen. These schemes are costly as they require an air separation unit. Novel approaches to coal gasification based on 'membrane separation' or chemical looping could reduce the costs significantly while effectively capturing carbon dioxide. 1 ref., 2 figs., 1 photo.

Liang-Shih Fan; Fanxing Li [Ohio State University, OH (United States). Dept. of Chemical and Biomolecular Engineering

2006-07-15T23:59:59.000Z

103

Coal demonstration plants. Quarterly report, January-March 1979. [US DOE-supported  

SciTech Connect (OSTI)

Progress in US DOE-supported demonstration plants for the gasification and liquefaction of coal is reported: company, contract number, process description and flowsheet, history and progress in the current quarter. Related projects involve coal feeders, lock hoppers, values, etc. for feeding coal into high pressure systems, coal grinding equipment and measuring and process control instrumentation. (LTN)

None

1980-01-01T23:59:59.000Z

104

Scoping Studies to Evaluate the Benefits of an Advanced Dry Feed System on the Use of Low-Rank Coal  

SciTech Connect (OSTI)

The purpose of this project was to evaluate the ability of advanced low rank coal gasification technology to cause a significant reduction in the COE for IGCC power plants with 90% carbon capture and sequestration compared with the COE for similarly configured IGCC plants using conventional low rank coal gasification technology. GE’s advanced low rank coal gasification technology uses the Posimetric Feed System, a new dry coal feed system based on GE’s proprietary Posimetric Feeder. In order to demonstrate the performance and economic benefits of the Posimetric Feeder in lowering the cost of low rank coal-fired IGCC power with carbon capture, two case studies were completed. In the Base Case, the gasifier was fed a dilute slurry of Montana Rosebud PRB coal using GE’s conventional slurry feed system. In the Advanced Technology Case, the slurry feed system was replaced with the Posimetric Feed system. The process configurations of both cases were kept the same, to the extent possible, in order to highlight the benefit of substituting the Posimetric Feed System for the slurry feed system.

Rader, Jeff; Aguilar, Kelly; Aldred, Derek; Chadwick, Ronald; Conchieri, John; Dara, Satyadileep; Henson, Victor; Leininger, Tom; Liber, Pawel; Liber, Pawel; Lopez-Nakazono, Benito; Pan, Edward; Ramirez, Jennifer; Stevenson, John; Venkatraman, Vignesh

2012-03-30T23:59:59.000Z

105

Cost and Performance Baseline for Fossil Energy Plants; Volume 3a: Low Rank Coal to Electricity: IGCC Cases  

Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE:1 First Use of Energy for All Purposes (Fuel and Nonfuel),Feet) Year Jan Feb Mar Apr MayAtmospheric Optical Depth7-1D: Vegetation Proposed Newcatalyst phases on γ-Al2O3. |ID#: 19834 Title:Cost Study Manual Cost

106

[Tampa Electric Company IGCC project]. 1996 DOE annual technical report, January--December 1996  

SciTech Connect (OSTI)

Tampa Electric Company`s Polk Power Station Unit 1 (PPS-1) Integrated Gasification Combined Cycle (IGCC) demonstration project uses a Texaco pressurized, oxygen-blown, entrained-flow coal gasifier to convert approximately 2,000 tons per day of coal to syngas. The gasification plant is coupled with a combined cycle power block to produce a net 250 MW electrical power output. Coal is slurried in water, combined with 95% pure oxygen from an air separation unit, and sent to the gasifier to produce a high temperature, high pressure, medium-Btu syngas with a heat content of about 250 BTUs/cf (HHV). The syngas then flows through a high temperature heat recovery unit which cools the syngas prior to its entering the cleanup systems. Molten coal ash flows from the bottom of the high temperature heat recovery unit into a water-filled quench chamber where it solidifies into a marketable slag by-product. Approximately 10% of the raw, hot syngas at 900 F is designed to pass through an intermittently moving bed of metal-oxide sorbent which removes sulfur-bearing compounds from the syngas. PPS-1 will be the first unit in the world to demonstrate this advanced metal oxide hot gas desulfurization technology on a commercial unit. The emphasis during 1996 centered around start-up activities.

NONE

1997-12-31T23:59:59.000Z

107

Improving pumping system efficiency at coal plants  

SciTech Connect (OSTI)

The industry must employ ultramodern technologies when building or upgrading power plant pumping systems thereby using fuels more efficiently. The article discusses the uses and efficiencies of positive displacement pumps, centrifugal pumps and multiple screw pumps. 1 ref., 4 figs.

Livoti, W.C.; McCandless, S.; Poltorak, R. [Baldor Electric Co. (United States)

2009-03-15T23:59:59.000Z

108

Case studies on recent fossil-fired plants  

SciTech Connect (OSTI)

The article summarises the findings of case studies on fossil-fired power plants carried out by the IEA Clean Coal Centre for the IEA at the request of world leaders at the Gleneagles G8 Summit in July 2005. The studies compared the cost, efficiency and emissions of eight recently constructed coal-fired plants using pulverized coal combustion with subcritical, supercritical or ultra-supercritical steam turbine cycles. Also included was a review of IGCC developments. A case study of a natural gas combined-cycle plant was included for comparison. The full report has been published by the IEA. 1 tab.

Henderson, C. [IEA Clean Coal Centre, London (United Kingdom)

2007-12-31T23:59:59.000Z

109

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

E-Print Network [OSTI]

Does proximity to coal-fired power plants influence fish tissue mercury? Dana K. Sackett · D. Derek+Business Media, LLC 2010 Abstract Much of the mercury contamination in aquatic biota originates from coal of contaminated fish. In this study, we quantified the relative importance of proximity to coal-fired power plants

110

Airborne coal dust reduction in Romanian power plants  

SciTech Connect (OSTI)

Romanian power plant coal handling and preparation areas have not introduced adequate dust collection systems. Therefore, the measurement of airborne coal dust shows that these values are higher than the maximum allowable value under Romanian regulations. The author`s company has been testing a dry dust collection system formed by a ductwork/bagfilter/exhaust fan system. The system was installed at a coal transfer point with a drop height of about 10 meters. The quantity of extracted and cleaned air was about 5,000 m{sup 3}/hr. The airborne dust concentration in the exhausted air was under 4 mg/m{sup 3}. Due to an inadequate skirtboard design that did not prove airtight, there was not enough negative pressure in the containment region. The dust collection system efficiency will be improved with design modifications and tested again. The results have shown that the system can be an efficient solution for local dust collection in power plant coal handling facilities.

Matei, M.; Renel, I. [Energy Research and Modernizing Inst., Bucharest (Romania)

1994-12-31T23:59:59.000Z

111

Plasma-enhanced gasification of low-grade coals for compact power plants  

SciTech Connect (OSTI)

A high temperature of a steam torch ensures an efficient gasification of low-grade coals, which is comparable to that of high-grade coals. Therefore, the coal gasification system energized by microwaves can serve as a moderately sized power plant due to its compact and lightweight design. This plasma power plant of low-grade coals would be useful in rural or sparsely populated areas without access to a national power grid.

Uhm, Han S. [Department of Electrophysics, Kwangwoon University, 447-1 Wolgye-Dong, Nowon-Gu, Seoul 139-701 (Korea, Republic of); Hong, Yong C.; Shin, Dong H.; Lee, Bong J. [Convergence Plasma Research Center, National Fusion Research Institute, 113 Gwahangno, Yuseong-Gu, Daejeon 305-333 (Korea, Republic of)

2011-10-15T23:59:59.000Z

112

Characterization of the chemical variation of feed coal and coal combustion products from a power plant utilizing low sulfur Powder River Basin coal  

SciTech Connect (OSTI)

The US Geological Survey and the University of Kentucky Center for Applied Energy Research, in collaboration with an Indiana utility, are studying a coal-fired power plant burning Powder River Basin coal. This investigation involves a systematic study of the chemical and mineralogical characteristics of feed coal and coal combustion products (CCPs) from a 1,300-megawatt (MW) power unit. The main goal of this study is to characterize the temporal chemical variability of the feed coal, fly ash, and bottom ash by looking at the major-, minor-, and trace-element compositions and their associations with the feed coal mineralogy. Emphasis is also placed on the abundance and modes of occurrence of elements of potential environmental concern that may affect the utilization of these CCPs and coals.

Affolter, R.H.; Brownfield, M.E.; Cathcart, J.D.; Brownfield, I.K.

2000-07-01T23:59:59.000Z

113

Clean coal reference plants: Atmospheric CFB. Topical report, Task 1  

SciTech Connect (OSTI)

The Clean Coal Technology Demonstration Program is a government and industry cofunded technology development effort to demonstrate a new generation of innovative coal utilization processes in a series of full-scale facilities. The goal of the program is to provide the US energy marketplace with a number of advanced, more efficient and environmentally responsive coal-using technologies. The Morgantown Energy Technology Center (METC) has the responsibility for monitoring the CCT Projects within certain technology categories, which correspond to the center`s areas of technology development, including atmospheric fluidized bed combustion, pressurized fluidized bed combustion, integrated gasification combined cycle, mild gasification, and industrial applications. A measure of success in the CCT program will be the commercial acceptance of the new technologies being demonstrated. The dissemination of project information to potential users is being accomplished by producing a series of reference plant designs which will provide the users a basis for the selection of technologies applicable to their future energy requirements. As a part of DOE`s monitoring and evaluation of the CCT Projects, Gilbert/Commonwealth (G/C) has been contracted to assist in this effort by producing the design of a commercial size Reference Plant, utilizing technologies developed in the CCT Program. This report, the first in a series, describes the design of a 400 MW electric power plant, utilizing an atmospheric pressure, circulating fluidized bed combustor (ACFB) similar to the one which was demonstrated at Colorado-Ute`s Nucla station, funded in Round 1 of the CCT Program. The intent of the reference plant design effort was to portray a commercial power plant with attributes considered important to the utility industry. The logical choice for the ACFB combustor was Pyropower since they supplied the ACFB for the Nucla Project.

Rubow, L.N.; Harvey, L.E.; Buchanan, T.L.; Carpenter, R.G.; Hyre, M.R.; Zaharchuk, R.

1992-06-01T23:59:59.000Z

114

Water vulnerabilities for existing coal-fired power plants.  

SciTech Connect (OSTI)

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 consisted of geographical areas where specific conditions can generate demand vulnerabilities. These conditions include high projected future water consumption by thermoelectric power plants, high projected future water consumption by all users, high rates of water withdrawal per square mile (mi{sup 2}), high projected population increases, and areas projected to be in a water crisis or conflict by 2025. The second type of demand indicator was plant specific. These indicators were developed for each plant and include annual water consumption and withdrawal rates and intensities, net annual power generation, and carbon dioxide (CO{sub 2}) emissions. The supply indictors, which are also area based, include areas with low precipitation, high temperatures, low streamflow, and drought. The indicator data, which were in various formats (e.g., maps, tables, raw numbers) were converted to a GIS format and stored, along with the individual plant data from the CPPDB, in a single GIS database. The GIS database allowed the indicator data and plant data to be analyzed and visualized in any combination. To determine the extent to which a plant would be considered 'vulnerable' to a given demand or supply concern (i.e., that the plant's operations could be affected by water shortages represented by a potential demand or supply indicator), criteria were developed to categorize vulnerability according to one of three types: major, moderate, or not vulnerable. Plants with at least two major demand indicator values and/or at least four moderate demand indicator values were considered vulnerable to demand concerns. By using this approach, 144 plants were identified as being subject to demand concerns only. Plants with at least one major supply indicator value and/or at least two moderate supply indicator values were considered vulnerable to supply concerns. By using this approach, 64 plants were identified as being subject to supply concerns only. In addition, 139 plants were identified as subject to both demand and supply concerns. Therefore, a total of 347 plants were considere

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

2010-08-19T23:59:59.000Z

115

Mercury control for coal-fired power plants  

SciTech Connect (OSTI)

On 15 March 2005 the US Environmental Protection Agency issued its Clean Air Mercury Rule (CAMP) to regulate mercury emissions from coal-fired power plants. EPRI is working with the US Department of Energy and the power industry to develop mercury control technologies needed to meet the final 2018 emission limits. Some improvements can be made by modifying existing SO{sub 2} or NOx control devices. Precombustion cleaning reduces mercury content of eastern coals by about one third. Adding a little halogen is another technology being researched - this promotes oxidation improving short-term mercury capture. EPRI is developing the TOXECON{trademark} technology to address a major problem of using sorbents to control mercury emissions: contamination of fly ash. 5 figs.

Haase, P.

2005-06-30T23:59:59.000Z

116

Comparative Assessment of Coal-and Natural Gas-fired Power Plants under a  

E-Print Network [OSTI]

Comparative Assessment of Coal- and Natural Gas-fired Power Plants under a CO2 Emission Performance standard (EPS) for pulverized coal (PC) and natural gas combined cycle (NGCC) power plants; · Evaluate% · Natural Gas-fired Power Plant: Adv. 7F Gas Turbine Capacity Factor 75% · Cost Basis: 2007$, constant 7

117

Quantification of Variability and Uncertainty in Hourly NOx Emissions from Coal-Fired Power Plants  

E-Print Network [OSTI]

to quantify variability and uncertainty for NOx emissions from coal-fired power plants. Data for hourly NOx emissions, heat rate, gross load and capacity factor of 32 units from 9 different power plants were analyzed Uncertainty, Variability, Emission Factors, Coal-Fired Power Plants, NOx emissions, Regression Models

Frey, H. Christopher

118

Development of an Ultra-fine Coal Dewatering Technology and an Integrated Flotation-Dewatering System for Coal Preparation Plants  

SciTech Connect (OSTI)

The project proposal was approved for only the phase I period. The goal for this Phase I project was to develop an industrial model that can perform continuous and efficient dewatering of fine coal slurries of the previous flotation process to fine coal cake of {approx}15% water content from 50-70%. The feasibility of this model should be demonstrated experimentally using a lab scale setup. The Phase I project was originally for one year, from May 2005 to May 2006. With DOE approval, the project was extended to Dec. 2006 without additional cost from DOE to accomplish the work. Water has been used in mining for a number of purposes such as a carrier, washing liquid, dust-catching media, fire-retardation media, temperature-control media, and solvent. When coal is cleaned in wet-processing circuits, waste streams containing water, fine coal, and noncombustible particles (ash-forming minerals) are produced. In many coal preparation plants, the fine waste stream is fed into a series of selection processes where fine coal particles are recovered from the mixture to form diluted coal fine slurries. A dewatering process is then needed to reduce the water content to about 15%-20% so that the product is marketable. However, in the dewatering process currently used in coal preparation plants, coal fines smaller than 45 micrometers are lost, and in many other plants, coal fines up to 100 micrometers are also wasted. These not-recovered coal fines are mixed with water and mineral particles of the similar particle size range and discharged to impoundment. The wasted water from coal preparation plants containing unrecoverable coal fine and mineral particles are called tailings. With time the amount of wastewater accumulates occupying vast land space while it appears as threat to the environment. This project developed a special extruder and demonstrated its application in solid-liquid separation of coal slurry, tailings containing coal fines mostly less than 50 micron. The extruder is special because all of its auger surface and the internal barrier surface are covered with the membranes allowing water to drain and solid particles retained. It is believed that there are four mechanisms working together in the dewatering process. They are hydrophilic diffusion flow, pressure flow, agitation and air purging. Hydrophilic diffusion flow is effective with hydrophilic membrane. Pressure flow is due to the difference of hydraulic pressure between the two sides of the membrane. Agitation is provided by the rotation of the auger. Purging is achieved with the air blow from the near bottom of the extruder, which is in vertical direction.

Wu Zhang; David Yang; Amar Amarnath; Iftikhar Huq; Scott O'Brien; Jim Williams

2006-12-22T23:59:59.000Z

119

Coal-fired open cycle magnetohydrodynamic power plant emissions and energy efficiences  

E-Print Network [OSTI]

This study is a review of projected emissions and energy efficiencies of coal-fired open cycle MHD power plants. Ideally one

Gruhl, Jim

120

Impacts of TMDLs on coal-fired power plants.  

SciTech Connect (OSTI)

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 plants. If a state establishes a new or revised TMDL for one of these pollutants in a water body where a power plant is located, the next renewal of the power plant's National Pollution Discharge Elimination System (NPDES) permit is likely to include more restrictive limits. Power generators may need to modify existing operational and wastewater treatment technologies or employ new ones as TMDLs are revised or new ones are established. The extent to which coal-fired power plants may be impacted by revised and new TMDL development has not been well established. NETL asked Argonne to evaluate how current and potential future TMDLs might influence coal-fired power plant operations and discharges. This information can be used to inform future technology research funded by NETL. The scope of investigation was limited to several eastern U.S. river basins rather than providing a detailed national perspective.

Veil, J. A.; Environmental Science Division

2010-04-30T23:59:59.000Z

Note: This page contains sample records for the topic "igcc coal plants" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


121

Cornell's conversion of a coal fired heating plant to natural Gas -BACKGROUND: In December 2009, the Combined Heat and Power Plant  

E-Print Network [OSTI]

- BACKGROUND: In December 2009, the Combined Heat and Power Plant at Cornell Cornell's conversion of a coal fired heating plant to natural Gas the power plant #12;

Keinan, Alon

122

Florida CFB demo plant yields low emissions on variety of coals  

SciTech Connect (OSTI)

The US Department of Energy (DOE) has reported results of tests conducted at Jacksonville Electric Authority (JEA)'s Northside power plant using mid-to-low-sulfur coal, which indicate the facility is one of the cleanest burning coal-fired power plants in the world. A part of DOE's Clean Coal Technology Demonstration Program, the JEA project is a repowering demonstration of the operating and environmental performance of Foster Wheeler's utility-scale circulating fluidized bed combustion (CFB) technology on a range of high-sulfur coals and blends of coal and high-sulfur petroleum coke. The 300 MW demonstration unit has a non-demonstration 300 MW twin unit.

NONE

2005-07-01T23:59:59.000Z

123

A Joint Workshop on Promoting the Development and Deployment of IGCC/Co-Production/CCS Technologies in China and the United States. Workshop report  

SciTech Connect (OSTI)

With both China and the United States relying heavily on coal for electricity, senior government officials from both countries have urged immediate action to push forward technology that would reduce carbon dioxide emissions from coal-fired plants. They discussed possible actions at a high-level workshop in April 2009 at the Harvard Kennedy School jointly sponsored by the Belfer Center's Energy Technology Innovation Policy (ETIP) research group, China's Ministry of Science and Technology, and the Chinese Academy of Sciences. The workshop examined issues surrounding Integrated Gasification Combined Cycle (IGCC) coal plants, which turn coal into gas and remove impurities before the coal is combusted, and the related carbon capture and sequestration, in which the carbon dioxide emissions are captured and stored underground to avoid releasing carbon dioxide into the atmosphere. Though promising, advanced coal technologies face steep financial and legal hurdles, and almost certainly will need sustained support from governments to develop the technology and move it to a point where its costs are low enough for widespread use.

Zhao, Lifeng; Ziao, Yunhan; Gallagher, Kelly Sims

2009-06-03T23:59:59.000Z

124

MHD (magnetohydrodynamics) retrofit of a coal-fired generating plant  

SciTech Connect (OSTI)

This report presents the following appendices on the design of a coal-fired MHD retrofit: AVCO part load study; AVCO full load calculations; MSE mass balance calculations; Corette/MHD combined plant overall efficiency estimate; Corette boiler efficiency estimate; dynamic modeling and control simulation; combustor and nozzle scaling approach; field inductance and energy calculations; diagnostic instrumentation listing; equipment list; cost estimate factors; equipment and vendor costs data; CFFF test information; HRSR-ESP seed/ash calculations; and K{sub 2}/S molar ratio.

Not Available

1989-01-01T23:59:59.000Z

125

Pilot plant used to develop load and pressure controller  

SciTech Connect (OSTI)

Viewed from the perspective of the power-generation mixture in Japan, nuclear power plants will continue to be operated to meet the base load. Meanwhile, integrated coal gasification combined cycle (IGCC) power plants will be required to serve as thermal power plants to cover the middle load, as is the case with conventional thermal power plants. In terms of operational performance, therefore, IGCC power plants will need to have a capability of following a wide range of load demand at high speed. For this purpose, a load and pressure controller was developed and tested during the operational research on a 200 tons/day entrained flow IGCC pilot plant at the Nakoso Power Station by the Engineering Research Association for IGCC Power Systems (IGC Association). This article reports on the development of the load and pressure controller and the results of the control test carried out to check the load follow capability of the pilot plant, while touching upon the simulation study also being conducted.

Nagata, Kazue; Yamada, Toshihiro; Hiza, Tomoyuki

1997-02-01T23:59:59.000Z

126

Use of the GranuFlow Process in Coal Preparation Plants to Improve Energy Recovery and Reduce Coal Processing Wastes  

SciTech Connect (OSTI)

With the increasing use of screen-bowl centrifuges in today's fine coal cleaning circuits, a significant amount of low-ash, high-Btu coal can be lost during the dewatering step due to the difficulty in capturing coal of this size consist (< 100 mesh or 0.15mm). The GranuFlow{trademark} technology, developed and patented by an in-house research group at DOE-NETL, involves the addition of an emulsified mixture of high-molecular-weight hydrocarbons to a slurry of finesized coal before cleaning and/or mechanical dewatering. The binder selectively agglomerates the coal, but not the clays or other mineral matter. In practice, the binder is applied so as to contact the finest possible size fraction first (for example, froth flotation product) as agglomeration of this fraction produces the best result for a given concentration of binder. Increasing the size consist of the fine-sized coal stream reduces the loss of coal solids to the waste effluent streams from the screen bowl centrifuge circuit. In addition, the agglomerated coal dewaters better and is less dusty. The binder can also serve as a flotation conditioner and may provide freeze protection. The overall objective of the project is to generate all necessary information and data required to commercialize the GranuFlow{trademark} Technology. The technology was evaluated under full-scale operating conditions at three commercial coal preparation plants to determine operating performance and economics. The handling, storage, and combustion properties of the coal produced by this process were compared to untreated coal during a power plant combustion test.

Glenn A. Shirey; David J. Akers

2005-12-31T23:59:59.000Z

127

GASIFICATION PLANT COST AND PERFORMANCE OPTIMIZATION  

SciTech Connect (OSTI)

The goal of this series of design and estimating efforts was to start from the as-built design and actual operating data from the DOE sponsored Wabash River Coal Gasification Repowering Project and to develop optimized designs for several coal and petroleum coke IGCC power and coproduction projects. First, the team developed a design for a grass-roots plant equivalent to the Wabash River Coal Gasification Repowering Project to provide a starting point and a detailed mid-year 2000 cost estimate based on the actual as-built plant design and subsequent modifications (Subtask 1.1). This unoptimized plant has a thermal efficiency of 38.3% (HHV) and a mid-year 2000 EPC cost of 1,681 $/kW. This design was enlarged and modified to become a Petroleum Coke IGCC Coproduction Plant (Subtask 1.2) that produces hydrogen, industrial grade steam, and fuel gas for an adjacent Gulf Coast petroleum refinery in addition to export power. A structured Value Improving Practices (VIP) approach was applied to reduce costs and improve performance. The base case (Subtask 1.3) Optimized Petroleum Coke IGCC Coproduction Plant increased the power output by 16% and reduced the plant cost by 23%. The study looked at several options for gasifier sparing to enhance availability. Subtask 1.9 produced a detailed report on this availability analyses study. The Subtask 1.3 Next Plant, which retains the preferred spare gasification train approach, only reduced the cost by about 21%, but it has the highest availability (94.6%) and produces power at 30 $/MW-hr (at a 12% ROI). Thus, such a coke-fueled IGCC coproduction plant could fill a near term niche market. In all cases, the emissions performance of these plants is superior to the Wabash River project. Subtasks 1.5A and B developed designs for single-train coal and coke-fueled power plants. This side-by-side comparison of these plants, which contain the Subtask 1.3 VIP enhancements, showed their similarity both in design and cost (1,318 $/kW for the coal plant and 1,260 $/kW for the coke plant). Therefore, in the near term, a coke IGCC power plant could penetrate the market and provide a foundation for future coal-fueled facilities. Subtask 1.6 generated a design, cost estimate and economics for a multiple train coal-fueled IGCC powerplant, also based on the Subtaks 1.3 cases. The Subtask 1.6 four gasification train plant has a thermal efficiency of 40.6% (HHV) and cost 1,066 $/kW. The single-train advanced Subtask 1.4 plant, which uses an advanced ''G/H-class'' combustion turbine, can have a thermal efficiency of 45.4% (HHV) and a plant cost of 1,096 $/kW. Multi-train plants will further reduce the cost. Again, all these plants have superior emissions performance. Subtask 1.7 developed an optimized design for a coal to hydrogen plant. At current natural gas prices, this facility is not competitive with hydrogen produced from natural gas. The preferred scenario is to coproduce hydrogen in a plant similar to Subtask 1.3, as described above. Subtask 1.8 evaluated the potential merits of warm gas cleanup technology. This study showed that selective catalytic oxidation of hydrogen sulfide (SCOHS) is promising. As gasification technology matures, SCOHS and other improvements identified in this study will lead to further cost reductions and efficiency improvements.

Samuel S. Tam

2002-05-01T23:59:59.000Z

128

A Review of Hazardous Chemical Species Associated with CO2 Capture from Coal-Fired Power Plants and Their Potential Fate in CO2 Geologic Storage  

E-Print Network [OSTI]

of Toxic Emissions from Coal-Fired Power Plants: Phase Ito restrict SO 2 emissions from coal-burning power plants (Coal-fired Power Plant (after Weber et al. , 1996) .42 Hazardous Organic Compounds in Combined Stack Emissions

Apps, J.A.

2006-01-01T23:59:59.000Z

129

Testing of a coal-fired diesel power plant  

SciTech Connect (OSTI)

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.

Wilson, R.P.; Balles, E.N.; Benedek, K.R.; Benson, C.E. (Little (Arthur D.), Inc., Cambridge, MA (United States)); Rao, K.; Schaub, F. (Cooper-Bessemer, Mount Vernon, OH (United States)); Kimberley, J. (AMBAC, West Springfield, MA (United States)); Itse, D. (PSI Technology Co., Andover, MA (United States))

1993-01-01T23:59:59.000Z

130

Testing of a coal-fired diesel power plant  

SciTech Connect (OSTI)

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.

Wilson, R.P.; Balles, E.N.; Benedek, K.R.; Benson, C.E. [Little (Arthur D.), Inc., Cambridge, MA (United States); Rao, K.; Schaub, F. [Cooper-Bessemer, Mount Vernon, OH (United States); Kimberley, J. [AMBAC, West Springfield, MA (United States); Itse, D. [PSI Technology Co., Andover, MA (United States)

1993-01-01T23:59:59.000Z

131

Planning for coal power plant transition : lessons learned from communities in Massachusetts  

E-Print Network [OSTI]

As coal-fired power plants across the U.S. are retiring in increasing numbers - a trend likely to continue in the years ahead - the communities that host these plants will play a critical role in balancing local concerns ...

Nochur, Aditya Kumar

2013-01-01T23:59:59.000Z

132

Carbon Dioxide Capture from Coal-Fired Power Plants: A Real Options Analysis Ram Chandra Sekar  

E-Print Network [OSTI]

Carbon Dioxide Capture from Coal-Fired Power Plants: A Real Options Analysis by Ram Chandra Sekar;2 #12;3 Carbon Dioxide Capture in Coal-Fired Power Plants: A Real Options Analysis by Ram Chandra Sekar technologies are valued using the "real options" valuation methodology in an uncertain carbon dioxide (CO2

133

Coal gasification for power generation. 2nd ed.  

SciTech Connect (OSTI)

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

NONE

2006-10-15T23:59:59.000Z

134

Incorporating Undesirable Outputs into Malmquist TFP Index: Environmental Performance Growth of Chinese Coal-Fired Power Plants  

E-Print Network [OSTI]

potential remains with regards to the efficiency improvement and emissions control in Chinese coal-fired power plants....

Yang, Hongliang; Pollitt, Michael G.

135

Water Extraction from Coal-Fired Power Plant Flue Gas  

SciTech Connect (OSTI)

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 adjustment. Water produced from this process should require little processing for use, depending on the end application. Test Series II water quality was not as good as that obtained in Test Series I; however, this was believed to be due to a system upset that contaminated the product water system during Test Series II. The amount of water that can be recovered from flue gas with the LDDS is a function of several variables, including desiccant temperature, L/G in the absorber, flash drum pressure, liquid-gas contact method, and desiccant concentration. Corrosion will be an issue with the use of calcium chloride as expected but can be largely mitigated through proper material selection. Integration of the LDDS with either low-grade waste heat and or ground-source heating and cooling can affect the parasitic power draw the LDDS will have on a power plant. Depending on the amount of water to be removed from the flue gas, the system can be designed with no parasitic power draw on the power plant other than pumping loads. This can be accomplished in one scenario by taking advantage of the heat of absorption and the heat of vaporization to provide the necessary temperature changes in the desiccant with the flue gas and precipitates that may form and how to handle them. These questions must be addressed in subsequent testing before scale-up of the process can be confidently completed.

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

2006-06-30T23:59:59.000Z

136

Size distribution of fine Particles in Stack emissions of a 600-MWe coal-fired Power Plant  

E-Print Network [OSTI]

Size distribution of fine Particles in Stack emissions of a 600-MWe coal-fired Power Plant I coal-fired power plant. Aknowledgements: French environment agency ADEME (Contract number 04-74-C0018 that was carried out in March 2006 at a 600-MWe coal-fired power plant. 51 ineris-00973267,version1-4Apr2014 Author

Paris-Sud XI, Université de

137

Implications of Near-Term Coal Power Plant Retirement for SO2 and NOX and Life Cycle GHG Emissions  

E-Print Network [OSTI]

Implications of Near-Term Coal Power Plant Retirement for SO2 and NOX and Life Cycle GHG Emissions emissions in the U.S. will likely result in coal plant retirement in the near-term. Life cycle assessment for electricity generation, by comparing systems that consist of individual natural gas and coal power plants

Jaramillo, Paulina

138

Direct Measurement of Mercury Reactions In Coal Power Plant Plumes  

SciTech Connect (OSTI)

Recent field and pilot-scale results indicate that divalent mercury emitted from power plants may rapidly transform to elemental mercury within the power plant plumes. Simulations of mercury chemistry in plumes based on measured rates to date have improved regional model fits to Mercury Deposition Network wet deposition data for particular years, while not degrading model verification fits for remaining years of the ensemble. The years with improved fit are those with simulated deposition in grid cells in the State of Pennsylvania that have matching MDN station data significantly less than the model values. This project seeks to establish a full-scale data basis for whether or not significant reduction or oxidation reactions occur to mercury emitted from coal-fired power plants, and what numerical redox rate should apply for extension to other sources and for modeling of power plant mercury plumes locally, regionally, and nationally. Although in-stack mercury (Hg) speciation measurements are essential to the development of control technologies and to provide data for input into atmospheric fate and transport models, the determination of speciation in a cooling coal combustion plume is more relevant for use in estimating Hg fate and effects through the atmosphere. It is mercury transformations that may occur in the plume that determine the eventual rate and patterns of mercury deposited to the earth's surface. A necessary first step in developing a supportable approach to modeling any such transformations is to directly measure the forms and concentrations of mercury from the stack exit downwind to full dispersion in the atmosphere. As a result, a study was sponsored by EPRI and jointly funded by EPRI, the U.S Department of Energy (DOE), and the Wisconsin Department of Administration. The study was designed to further our understanding of plume chemistry. The study was carried out at the We Energies Pleasant Prairie Power Plant, Pleasant Prairie, Wisconsin, just west of Kenosha. Aircraft and ground measurements support the occurrence of a reduction in the fraction of reactive gaseous mercury (RGM) (with a corresponding increase in elemental mercury) as part of the Total Gaseous Mercury (TGM) emitted from the Pleasant Prairie stack. This occurrence is based on comparison of the RGM concentrations in the plume (at standard conditions) compared to the RGM in the stack. There was found to be a 44% drop in the fraction of RGM between the stack exit and the first sampling arc and a 66% reduction from the stack to the 5-mile sampling arc, with no additional drop between the 5- and 10-mile arcs. Smaller-scale experiments in both test chambers and pilot-scale coal combustor exhaust streams have indicated the presence of rapid and relatively complete reduction reactions converting divalent into elemental mercury within power plant plumes prior to full dispersion in the atmosphere. These measurements, however, have been unable to identify whether the reactions occur during plume rise from physical to virtual stack height (during positive thermal buoyancy). The presence, rate, completeness, ubiquity, and dependence on source characteristics of these reactions, however, must be demonstrated in plume environments associated with fully operational power plants. That requirement, to capture either the reactions or the reaction products of chemistry that may be occurring very close to stack exits in highly turbulent environments, constrains the precision and reproducibility with which such full-scale experiments can be carried out. The work described here is one of several initial steps required to test whether, and in what direction, such rapid mercury redox reactions might be occurring in such plumes.

Leonard Levin

2005-12-31T23:59:59.000Z

139

University coal research/historically black colleges and universities and other minority institutions contractors review meeting  

SciTech Connect (OSTI)

A variety of papers/posters were presented on topics concerning power generation, including solid oxide fuel cells, hydrogen production, mercury as a combustion product, carbon dioxide separation from flue gas. A total of 31 presentations in slide/overview/viewgraph form and with a separate abstract are available online (one in abstract form only) and 24 poster papers (text). In addition 41 abstracts only are available. Papers of particular interest include: Hydrogen production from hydrogen sulfide in IGCC power plants; Oxidation of mercury in products of coal combustion; Computer aided design of advanced turbine aerofoil alloys for industrial gas turbines in coal fired environments; Developing engineered fuel using flyash and biomass; Conversion of hydrogen sulfide in coal gases to elemental sulfur with monolithic catalysts; Intelligent control via wireless sensor networks for advanced coal combustion systems; and Investment of fly ash and activated carbon obtained from pulverized coal boilers (poster).

NONE

2006-07-01T23:59:59.000Z

140

Potential of hybrid geothermal/coal fired power plants in Arizona  

SciTech Connect (OSTI)

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.

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

1982-08-01T23:59:59.000Z

Note: This page contains sample records for the topic "igcc coal plants" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
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141

E-Print Network 3.0 - advanced coal liquefaction Sample Search...  

Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

and Opportunities for the Illinois Coal Industry Summary: and Storage 11 3.5.2. Gasification, Liquefaction, and IGCC 12 4. Coal Market Projections 13 4.1. Consumption... . The...

142

Energy 42 (2012) 486-496 Thermoeconomic operation optimization of a coal-fired power plant  

E-Print Network [OSTI]

- -,- -------:-:-:-:-:-:-:~:-:-:-:-:---.-- Energy 42 (2012) 486-496 Thermoeconomic operation optimization of a coal-fired power plant Jie Xiong a, Haibo Zhao a.*, Chao Zhang a, Chuguang Zheng a, Peter B. Luh b aState Key Laboratory of Coal Combustion. Huazhong University ofSdence and Technology. Wuhan

Luh, Peter

2012-01-01T23:59:59.000Z

143

Coal flow aids reduce coke plant operating costs and improve production rates  

SciTech Connect (OSTI)

Chemical coal flow aids can provide many benefits to coke plants, including improved production rates, reduced maintenance and lower cleaning costs. This article discusses the mechanisms by which coal flow aids function and analyzes several successful case histories. 2 refs., 10 figs., 1 tab.

Bedard, R.A.; Bradacs, D.J.; Kluck, R.W.; Roe, D.C.; Ventresca, B.P.

2005-06-01T23:59:59.000Z

144

Using Auxiliary Gas Power for CCS Energy Needs in Retrofitted Coal Power Plants  

E-Print Network [OSTI]

1 Using Auxiliary Gas Power for CCS Energy Needs in Retrofitted Coal Power Plants by Sarah Bashadi and Policy Program #12;2 #12;3 Using Auxiliary Gas Power for CCS Energy Needs in Retrofitted Coal Power, a significant amount of excess power was produced using both gas turbine configurations. This excess power could

145

Efficiency and Environmental Impacts of Electricity Restructuring on Coal-fired Power Plants  

E-Print Network [OSTI]

Efficiency and Environmental Impacts of Electricity Restructuring on Coal-fired Power Plants Hei WITHOUT PERMISSION Abstract We investigate the impacts of electricity market restructuring on fuel recent years allows us to examine longer term impacts of restructuring; (2) the focus on coal-fired power

146

Capture-ready coal plants--Options, technologies and Mark C. Bohm a  

E-Print Network [OSTI]

. Introduction Interest in the construction of coal-fired power generation has increased significantly in recentCapture-ready coal plants--Options, technologies and economics Mark C. Bohm a , Howard J. Herzog a facilities, and the current challenges of availability and pricing of alternative generation technologies

147

Steam Turbine Materials for Ultrasupercritical Coal Power Plants  

SciTech Connect (OSTI)

The Ultrasupercritical (USC) Steam Turbine Materials Development Program is sponsored and funded by the U.S. Department of Energy and the Ohio Coal Development Office, through grants to Energy Industries of Ohio (EIO), a non-profit organization contracted to manage and direct the project. The program is co-funded by the General Electric Company, Alstom Power, Siemens Power Generation (formerly Siemens Westinghouse), and the Electric Power Research Institute, each organization having subcontracted with EIO and contributing teams of personnel to perform the requisite research. The program is focused on identifying, evaluating, and qualifying advanced alloys for utilization in coal-fired power plants that need to withstand steam turbine operating conditions up to 760°C (1400°F) and 35 MPa (5000 psi). For these conditions, components exposed to the highest temperatures and stresses will need to be constructed from nickel-based alloys with higher elevated temperature strength than the highchromium ferritic steels currently used in todayâ??s high-temperature steam turbines. In addition to the strength requirements, these alloys must also be weldable and resistant to environmental effects such as steam oxidation and solid particle erosion. In the present project, candidate materials with the required creep strength at desired temperatures have been identified. Coatings that can resist oxidation and solid particle erosion have also been identified. The ability to perform dissimilar welds between nickel base alloys and ferritic steels have been demonstrated, and the properties of the welds have been evaluated. Results of this three-year study that was completed in 2009 are described in this final report. Additional work is being planned and will commence in 2009. The specific objectives of the future studies will include conducting more detailed evaluations of the weld-ability, mechanical properties and repair-ability of the selected candidate alloys for rotors, casings and valves, and to perform scale-up studies to establish a design basis for commercial scale components. A supplemental program funded by the Ohio Coal Development Office will undertake supporting tasks such as testing and trials using existing atmospheric, vacuum and developmental pressure furnaces to define specific metal casting techniques needed for producing commercial scale components.

Viswanathan, R.; Hawk, J.; Schwant, R.; Saha, D.; Totemeier, T.; Goodstine, S.; McNally, M.; Allen, D. B.; Purgert, Robert

2009-06-30T23:59:59.000Z

148

Accumulation of trace elements and growth responses in Corbicula fluminea downstream of a coal-fired power plant  

E-Print Network [OSTI]

Accumulation of trace elements and growth responses in Corbicula fluminea downstream of a coal 2009 Keywords: Corbicula fluminea Coal-fired power plant Selenium Mercury Glutathione Condition index Bioaccumulation a b s t r a c t Lentic organisms exposed to coal-fired power plant (CFPP) discharges can have

Hopkins, William A.

149

Nitrogen Isotopic Composition of Coal-Fired Power Plant NOx: Influence of Emission Controls and Implications for Global Emission  

E-Print Network [OSTI]

Nitrogen Isotopic Composition of Coal-Fired Power Plant NOx: Influence of Emission Controls from coal-fired power plants in the U.S. at typical operating conditions with and without the presence this, a novel method for collection and isotopic analysis of coal-fired stack NOx emission samples

Elliott, Emily M.

150

Future Carbon Regulations and Current Investments in Alternative Coal-Fired Power Plant Designs  

E-Print Network [OSTI]

This paper assesses the role of uncertainty over future U.S. carbon regulations in shaping the current choice of which type of power plant to build. The pulverized coal technology (PC) still offer the lowest cost power— ...

Sekar, Ram C.

151

Using auxiliary gas power for CCS energy needs in retrofitted coal power plants  

E-Print Network [OSTI]

Adding post-combustion capture technology to existing coal-fired power plants is being considered as a near-term option for mitigating CO[subscript 2] emissions. To supply the thermal energy needed for CO[subscript 2] ...

Bashadi, Sarah O.

152

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

SciTech Connect (OSTI)

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.

Chu, P.; Epstein, M. [Electric Power Research Institute, Palo Alto, CA (United States); Gould, L. [Department of Energy, Pittsburgh, PA (United States); Botros, P. [Department of Energy, Morgantown, WV (United States)

1995-12-31T23:59:59.000Z

153

The particulate and vapor phase components of airborne polyaromatic hydrocarbons (PAHs) in coal gasification pilot plants  

E-Print Network [OSTI]

THE PARTICULATE AND VAPOR PHASE COMPONENTS OF AIRBORNE POLYAROMATIC HYDROCARBONS(PAHs) IN COAL GASIFICATION PILOT PLANTS A Thesis by ERIC JON BRINK Submitted to the Graduate College of Texas A & M University in partial fulfillment... of the requirement for the degree of MASTER OF SCIENCE December 1980 Major Subject: Industrial Hygiene THE PARTICULATE AND VAPOR PHASE COMPONENTS OF AIRBORNE POLYAROMATIC HYDROCARBONS (PAHs) IN COAL GASIFICATION PILOT PLANTS A Thesis by ERIC JON BRINK...

Brink, Eric Jon

1980-01-01T23:59:59.000Z

154

Filter systems for IGCC applications  

SciTech Connect (OSTI)

The objectives of this program were to identify metallic filter medium to be utilized in the Integrated Gasification Combined Cycle process (IGCC). In IGCC processes utilizing high efficiency desulfurizing technology, the traditional corrosion attack, sulfidation, is minimized so that metallic filters are viable alternatives over ceramic filters. Tampa Electric Company`s Polk Power Station is being developed to demonstrate Integrated Gasification Combined Cycle technology. The Pall Gas Solid Separation (GSS) System is a self cleaning filtration system designed to remove virtually all particulate matter from gas streams. The heart of the system is the filter medium used to collect the particles on the filter surface. The medium`s filtration efficiency, uniformity, permeability, voids volume, and surface characteristics are all important to establishing a permeable permanent cake. In-house laboratory blowback tests, using representative full scale system particulate, were used to confirm the medium selection for this project. Test elements constructed from six alloys were supplied for exposure tests: PSS 310SC (modified 310S alloy); PSS 310SC heat treated; PSS 310SC-high Cr; PSS 310SC-high Cr heat treated; PSS Hastelloy X; and PSS Hastelloy X heat treated.

Bevan, S.; Gieger, R.; Sobel, N.; Johnson, D.

1995-11-01T23:59:59.000Z

155

Investigation of coal stockpiles of Tuncbilek thermal power plant with respect to time under atmospheric conditions  

SciTech Connect (OSTI)

Thermal power plants have delayed the coal that they will use at stockpiles mandatorily. If these coal stockpiles remain at the stockyards over a certain period of time, a spontaneous combustion can be started itself. Coal stocks under combustion threat can cost too much economically to coal companies. Therefore, it is important to take some precautions for saving the stockpiles from the spontaneous combustion. In this research a coal stockpile at Tuncbilek Thermal Power Plant which was formed in 5 m wide, 10 m long, and 3 m height with a weight of 120 tons to observe internal temperature changes with respect to time under normal atmospheric conditions. Later, internal temperature measurements were obtained at 20 points distributed all over two layers in the stockpile. The parameters, such as air temperature, humidity, atmosphere pressure, wind speed and direction, which are effective on the stockpiles, were measured and used to obtain the graphs of stockpiles' internal temperature.

Ozdeniz, A.H. [Selcuk University, Konya (Turkey). Dept. of Mining Engineering

2009-07-01T23:59:59.000Z

156

Evaluation of Suitability of Selected Set of Coal Plant Sites for Repowering with Small Modular Reactors  

SciTech Connect (OSTI)

This report summarizes the approach that ORNL developed for screening a sample set of small coal stations for possible repowering with SMRs; the methodology employed, including spatial modeling; and initial results for these sample plants. The objective in conducting this type of siting evaluation is to demonstrate the capability to characterize specific sample coal plant sites to identify any particular issues associated with repowering existing coal stations with SMRs using OR-SAGE; it is not intended to be a definitive assessment per se as to the absolute suitability of any particular site.

Belles, Randy [ORNL; Copinger, Donald A [ORNL; Mays, Gary T [ORNL; Omitaomu, Olufemi A [ORNL; Poore III, Willis P [ORNL

2013-03-01T23:59:59.000Z

157

Integrated coal preparation and CWF processing plant: Conceptual design and costing  

SciTech Connect (OSTI)

At the request of the US Department of Energy (DOE), Pittsburgh Energy Technology Center, a study was conducted to provide DOE with a reliable, documented estimate of the cost of producing coal-water fuel (CWF). The approach to the project was to specify a plant capacity and location, identify and analyze a suitable coal, and develop a conceptual design for an integrated coal preparation and CWF processing plant. Using this information, a definitive costing study was then conducted, on the basis of which an economic and sensitivity analysis was performed utilizing a financial evaluation model to determine a price for CWF in 1992. The design output of the integrated plant is 200 tons of coal (dry basis) per hour. Operating at a capacity factor of 83 percent, the baseline design yields approximately 1.5 million tons per year of coal on a dry basis. This is approximately equivalent to the fuel required to continuously generate 500 MW of electric power. The CWF produced by the plant is intended as a replacement for heavy oil or gas in electric utility and large industrial boilers. The particle size distribution, particularly the top size, and the ash content of the coal in the CWF are specified at significantly lower levels than is commonly found in typical pulverized coal grinds. The particle top size is 125 microns (vs typically 300m[mu] for pulverized coal) and the coal ash content is 3.8 percent. The lower top size is intended to promote complete carbon burnout at less derating in boilers that are not designed for coal firing. The reduced mineral matter content will produce ash of very fine particle size during combustion, which leads to less impaction and reduced fouling of tubes in convective passages.

McHale, E.T.; Paul, A.D.; Bartis, J.T. (Science Applications International Corp., McLean, VA (United States)); Korkmaz, M. (Roberts and Schaefer Co., Salt Lake City, UT (United States))

1992-12-01T23:59:59.000Z

158

Integrated coal preparation and CWF processing plant: Conceptual design and costing. Final technical report  

SciTech Connect (OSTI)

At the request of the US Department of Energy (DOE), Pittsburgh Energy Technology Center, a study was conducted to provide DOE with a reliable, documented estimate of the cost of producing coal-water fuel (CWF). The approach to the project was to specify a plant capacity and location, identify and analyze a suitable coal, and develop a conceptual design for an integrated coal preparation and CWF processing plant. Using this information, a definitive costing study was then conducted, on the basis of which an economic and sensitivity analysis was performed utilizing a financial evaluation model to determine a price for CWF in 1992. The design output of the integrated plant is 200 tons of coal (dry basis) per hour. Operating at a capacity factor of 83 percent, the baseline design yields approximately 1.5 million tons per year of coal on a dry basis. This is approximately equivalent to the fuel required to continuously generate 500 MW of electric power. The CWF produced by the plant is intended as a replacement for heavy oil or gas in electric utility and large industrial boilers. The particle size distribution, particularly the top size, and the ash content of the coal in the CWF are specified at significantly lower levels than is commonly found in typical pulverized coal grinds. The particle top size is 125 microns (vs typically 300m{mu} for pulverized coal) and the coal ash content is 3.8 percent. The lower top size is intended to promote complete carbon burnout at less derating in boilers that are not designed for coal firing. The reduced mineral matter content will produce ash of very fine particle size during combustion, which leads to less impaction and reduced fouling of tubes in convective passages.

McHale, E.T.; Paul, A.D.; Bartis, J.T. [Science Applications International Corp., McLean, VA (United States); Korkmaz, M. [Roberts and Schaefer Co., Salt Lake City, UT (United States)

1992-12-01T23:59:59.000Z

159

Mercury emission control for coal fired power plants using coal and biomass  

E-Print Network [OSTI]

were performed in a 100,000 BTU/hr (29.3 kWt) Boiler Burner facility located in the Coal and Biomass Energy laboratory (CBEL); coal and biomass blends in proportions of 80:20, 90:10, 95:5 and 100:0 were investigated as fuels. The percentage reduction...

Arcot Vijayasarathy, Udayasarathy

2009-05-15T23:59:59.000Z

160

GASIFICATION PLANT COST AND PERFORMANCE OPTIMIZATION  

SciTech Connect (OSTI)

This project developed optimized designs and cost estimates for several coal and petroleum coke IGCC coproduction projects that produced hydrogen, industrial grade steam, and hydrocarbon liquid fuel precursors in addition to power. The as-built design and actual operating data from the DOE sponsored Wabash River Coal Gasification Repowering Project was the starting point for this study that was performed by Bechtel, Global Energy and Nexant under Department of Energy contract DE-AC26-99FT40342. First, the team developed a design for a grass-roots plant equivalent to the Wabash River Coal Gasification Repowering Project to provide a starting point and a detailed mid-year 2000 cost estimate based on the actual as-built plant design and subsequent modifications (Subtask 1.1). This non-optimized plant has a thermal efficiency to power of 38.3% (HHV) and a mid-year 2000 EPC cost of 1,681 $/kW.1 This design was enlarged and modified to become a Petroleum Coke IGCC Coproduction Plant (Subtask 1.2) that produces hydrogen, industrial grade steam, and fuel gas for an adjacent Gulf Coast petroleum refinery in addition to export power. A structured Value Improving Practices (VIP) approach was applied to reduce costs and improve performance. The base case (Subtask 1.3) Optimized Petroleum Coke IGCC Coproduction Plant increased the power output by 16% and reduced the plant cost by 23%. The study looked at several options for gasifier sparing to enhance availability. Subtask 1.9 produced a detailed report on this availability analyses study. The Subtask 1.3 Next Plant, which retains the preferred spare gasification train approach, only reduced the cost by about 21%, but it has the highest availability (94.6%) and produces power at 30 $/MW-hr (at a 12% ROI). Thus, such a coke-fueled IGCC coproduction plant could fill a near term niche market. In all cases, the emissions performance of these plants is superior to the Wabash River project. Subtasks 1.5A and B developed designs for single-train coal- and coke-fueled IGCC power plants. A side-by-side comparison of these plants, which contain the Subtask 1.3 VIP enhancements, shows their similarity both in design and cost (1,318 $/kW for the coal plant and 1,260 $/kW for the coke plant). Therefore, in the near term, a coke IGCC power plant could penetrate the market and provide a foundation for future coal-fueled facilities. Subtask 1.6 generated a design, cost estimate and economics for a four-train coal-fueled IGCC power plant, also based on the Subtask 1.3 cases. This plant has a thermal efficiency to power of 40.6% (HHV) and cost 1,066 $/kW. The single-train advanced Subtask 1.4 plant, which uses an advanced ''G/H-class'' combustion turbine, can have a thermal efficiency to power of 44.5% (HHV) and a plant cost of 1,116 $/kW. Multi-train plants will further reduce the cost. Again, all these plants have superior emissions performance. Subtask 1.7 developed an optimized design for a coal to hydrogen plant. At current natural gas prices, this facility is not competitive with hydrogen produced from natural gas. The preferred scenario is to co-produce hydrogen in a plant similar to Subtask 1.3, as described above. Subtask 1.8 evaluated the potential merits of warm gas cleanup technology. This study showed that selective catalytic oxidation of hydrogen sulfide (SCOHS) is promising. Subtask 2.1 developed a petroleum coke IGCC power plant with the coproduction of liquid fuel precursors from the Subtask 1.3 Next Plant by eliminating the export steam and hydrogen production and replacing it with a Fischer-Tropsch hydrocarbon synthesis facility that produced 4,125 bpd of liquid fuel precursors. By maximizing liquids production at the expense of power generation, Subtask 2.2 developed an optimized design that produces 10,450 bpd of liquid fuel precursors and 617 MW of export power from 5,417 tpd of dry petroleum coke. With 27 $/MW-hr power and 30 $/bbl liquids, the Subtask 2.2 plant can have a return on investment of 18%. Subtask 2.3 converted the Subtask 1.6 four-train coal fueled IGCC power plant

Sheldon Kramer

2003-09-01T23:59:59.000Z

Note: This page contains sample records for the topic "igcc coal plants" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


161

A Review of Hazardous Chemical Species Associated with CO2 Capture from Coal-Fired Power Plants and Their Potential Fate in CO2 Geologic Storage  

E-Print Network [OSTI]

from combustion and gasification of coal – an equilibriumHolysh, M. 2005. Coke Gasification: Advanced technology forfrom a Coal-Fired Gasification Plant. Final Report, December

Apps, J.A.

2006-01-01T23:59:59.000Z

162

DIRECT MEASUREMENT OF MERCURY REACTIONS IN COAL POWER PLANT PLUMES  

SciTech Connect (OSTI)

This project was awarded under U.S. Department of Energy (DOE) National Energy Technology Laboratory (NETL) Program Solicitation DE-PS26-02NT41422 and specifically addresses Program Area of Interest: No.5--Environmental and Water Resources. The project team includes the Electric Power Research Institute (EPRI) as the contractor and the University of North Dakota Energy & Environmental Research Center (EERC) and Frontier Geosciences as subcontractors. Wisconsin Energies and its Pleasant Prairie Power Plant acted as host for the field-testing portion of the research. The project is aimed at clarifying the role, rates, and end results of chemical transformations that may occur to mercury that has been emitted from elevated stacks of coal-fired electric power plants. Mercury emitted from power plants emerges in either its elemental, divalent, or particulate-bound form. Deposition of the divalent form is more likely to occur closer to the source than that of the other two forms, due to its solubility in water. Thus, if chemical transformations occur in the stack emissions plume, measurements in the stack may mischaracterize the fate of the material. Initial field and pilot plant measurements have shown significant and rapid chemical reduction of divalent to elemental mercury may occur in these plumes. Mercury models currently assume that the chemical form of mercury occurring in stacks is the same as that which enters the free atmosphere, with no alteration occurring in the emissions plume. Recent data indicate otherwise, but need to be evaluated at full operating scale under field conditions. Prestbo and others have demonstrated the likelihood of significant mercury chemical reactions occurring in power plant plumes (Prestbo et al., 1999; MDNR-PPRP, 2000; EERC, 2001). This experiment will thus increase our understanding of mercury atmospheric chemistry, allowing informed decisions regarding source attribution. The experiment was carried out during the period August 22-September 5, 2003. The experimental site was the Pleasant Prairie Power Plant in Pleasant Prairie, Wisconsin, just west of Kenosha. The experiment involved using an aircraft to capture emissions and document chemistry changes in the plume. While using the airplane for sampling, supplemental fast-response sensors for NOx, connected to data loggers, were used to gauge entry and exit times and transect intervals through plume emissions material. The Frontier Geosciences Static Plume Dilution Chamber (SPDC) was employed simultaneously adjacent to the stack to correlate its findings with the aircraft sampling, as well as providing evaluation of the SPDC as a rapid, less costly sampler for mercury chemistry. A complementary stack plume method, the Dynamic Plume Dilution (DPD) was used in the latter portion of the experiment to measure mercury speciation to observe any mercury reduction reaction with respect to both the reaction time (5 to 30 seconds) and dilution ratio. In addition, stack sampling using the ''Ontario Hydro'' wet chemistry method and continuous mercury monitors (CMM) were used to establish the baseline chemistry in the stack. Comparisons among stack, SPDC, DPD and aircraft measurements allow establishment of whether significant chemical changes to mercury occur in the plume, and of the verisimilitude of the SPDC and DPD methods. This progress report summarizes activities during a period of results review from the stack/aircraft subcontractor, data analysis and synthesis, and preparation and presentation of preliminary results to technical and oversight meetings.

Leonard Levin

2006-06-01T23:59:59.000Z

163

USE OF COAL DRYING TO REDUCE WATER CONSUMED IN PULVERIZED COAL POWER PLANTS  

SciTech Connect (OSTI)

This is the eighth Quarterly Report for this project. The background and technical justification for the project are described, including potential benefits of reducing fuel moisture, prior to firing in a pulverized coal boiler. Analyses were performed to determine the effects of coal product moisture on unit performance. Results are given showing how the coal product moisture level affects parameters such as boiler efficiency, power required to drive the fluidizing air fan, other station service power needed for fans and pulverizers, net unit heat rate, thermal energy rejected by the cooling tower, and stack emissions.

Nenad Sarunac; Edward Levy

2005-03-01T23:59:59.000Z

164

The suitability of coal gasification in India's energy sector  

E-Print Network [OSTI]

Integrated Gasification Combined Cycle (IGCC), an advanced coal-based power generation technology, may be an important technology to help India meet its future power needs. It has the potential to provide higher generating ...

Simpson, Lori Allison

2006-01-01T23:59:59.000Z

165

Advanced coal technologies in Czech heat and power systems  

SciTech Connect (OSTI)

Coal is the only domestic source of fossil fuel in the Czech Republic. The coal reserves are substantial and their share in total energy use is about 60%. Presently necessary steps in making coal utilisation more friendly towards the environment have been taken and fairly well established, and an interest to develop and build advanced coal units has been observed. One IGCC system has been put into operation, and circa 10 AFBC units are in operation or under construction. Preparatory steps have been taken in building an advanced combustion unit fuelled by pulverised coal and retrofit action is taking place in many heating plants. An actual experience has shown two basic problems: (1) Different characteristic of domestic lignite, especially high content of ash, cause problems applying well-tried foreign technologies and apparently a more focused attention shall have to be paid to the quality of coal combusted. (2) Low prices of lignite (regarding energy, lignite is four times cheaper then coal) do not oblige to increase efficiency of the standing equipment applying advanced technologies. It will be of high interest to observe the effect of the effort of the European Union to establish a kind of carbon tax. It could dramatically change the existing scene in clean coal power generation by the logical pressure to increase the efficiency of energy transformation. In like manner the gradual liberalisation of energy prices might have similar consequences and it is a warranted expectation that, up to now not the best, energy balance will improve in near future.

Noskievic, P.; Ochodek, T. [VSB-Technical Univ., Ostrava (Czechoslovakia)

1998-04-01T23:59:59.000Z

166

Development of a Low NOx Burner System for Coal Fired Power Plants Using Coal and Biomass Blends  

E-Print Network [OSTI]

.................................................................................... 36 Figure 19 Result of Combustion Performance Tests after Retrofits of Thermal Power Plant IN in Finland Consisting of Four 265 MW Pulverized Coal-Fired Boilers... on to include the International Energy Agency Bioenergy Task 32 group?s draft position paper that indicates cofiring represents among the lowest risk, least expensive, most efficient, and shortest term options for renewable-based electrical power generation...

Gomez, Patsky O.

2010-01-16T23:59:59.000Z

167

Briefing Book, Interagency Geothermal Coordinating Council (IGCC) Meeting of April 28, 1988  

SciTech Connect (OSTI)

The IGCC of the U.S. government was created under the intent of Public Law 93-410 (1974) to serve as a forum for the discussion of Federal plans, activities, and policies that are related to or impact on geothermal energy. Eight Federal Departments were represented on the IGCC at the time of this meeting. The main presentations in this report were on: Department of Energy Geothermal R&D Program, the Ormat binary power plant at East Mesa, CA, Potential for direct use of geothermal at Defense bases in U.S. and overseas, Department of Defense Geothermal Program at China Lake, and Status of the U.S. Geothermal Industry. The IGCC briefing books and minutes provide a historical snapshot of what development and impact issues were important at various time. (DJE 2005)

None

1988-04-28T23:59:59.000Z

168

Repowering a small coal-fired power plant  

SciTech Connect (OSTI)

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.

Miell, R.

2007-11-15T23:59:59.000Z

169

Liquid CO{sub 2}/Coal Slurry for Feeding Low Rank Coal to Gasifiers  

SciTech Connect (OSTI)

This study investigates the practicality of using a liquid CO{sub 2}/coal slurry preparation and feed system for the E-Gas™ gasifier in an integrated gasification combined cycle (IGCC) electric power generation plant configuration. Liquid CO{sub 2} has several property differences from water that make it attractive for the coal slurries used in coal gasification-based power plants. First, the viscosity of liquid CO{sub 2} is much lower than water. This means it should take less energy to pump liquid CO{sub 2} through a pipe compared to water. This also means that a higher solids concentration can be fed to the gasifier, which should decrease the heat requirement needed to vaporize the slurry. Second, the heat of vaporization of liquid CO{sub 2} is about 80% lower than water. This means that less heat from the gasification reactions is needed to vaporize the slurry. This should result in less oxygen needed to achieve a given gasifier temperature. And third, the surface tension of liquid CO{sub 2} is about 2 orders of magnitude lower than water, which should result in finer atomization of the liquid CO{sub 2} slurry, faster reaction times between the oxygen and coal particles, and better carbon conversion at the same gasifier temperature. EPRI and others have recognized the potential that liquid CO{sub 2} has in improving the performance of an IGCC plant and have previously conducted systemslevel analyses to evaluate this concept. These past studies have shown that a significant increase in IGCC performance can be achieved with liquid CO{sub 2} over water with certain gasifiers. Although these previous analyses had produced some positive results, they were still based on various assumptions for liquid CO{sub 2}/coal slurry properties. This low-rank coal study extends the existing knowledge base to evaluate the liquid CO{sub 2}/coal slurry concept on an E-Gas™-based IGCC plant with full 90% CO{sub 2} capture. The overall objective is to determine if this technology could be used to reduce the cost and improve the efficiency of IGCC plants. The study goes beyond the systems-level analyses and initial lab work that formed the bases of previous studies and includes the following tasks: performing laboratory tests to quantify slurry properties; developing an engineering design of a liquid CO{sub 2} slurry preparation and feed system; conducting a full IGCC plant techno-economic analysis for Powder River Basin (PRB) coal and North Dakota lignite in both water and liquid CO{sub 2} slurries; and identifying a technology development plan to continue the due diligence to conduct a comprehensive evaluation of this technology. The initial task included rheology tests and slurry data analyses that would increase the knowledge and understanding of maximum solids loading capability for both PRB and lignite. Higher coal concentrations have been verified in liquid CO{sub 2} over water slurries, and a coal concentration of 75% by weight in liquid CO{sub 2} has been estimated to be achievable in a commercial application. In addition, lower slurry viscosities have been verified in liquid CO{sub 2} at the same solids loading, where the liquid CO{sub 2}/coal slurry viscosity has been measured to be about a factor of 10 lower than the comparable water slurry and estimated to be less than 100 centipoise in a commercial application. In the following task, an engineering design of a liquid CO{sub 2}/coal slurry preparation and mixing system has been developed for both a batch and continuous system. The capital cost of the design has also been estimated so that it could be used in the economic analysis. An industry search and survey has been conducted to determine if essential components required to construct the feed system are available from commercial sources or if targeted R&D efforts are required. The search and survey concluded that commercial sources are available for selected components that comprise both the batch and continuous type systems. During normal operation, the fuel exits the bottom of the coal silo and is fed to a rod mill fo

Marasigan, Jose; Goldstein, Harvey; Dooher, John

2013-09-30T23:59:59.000Z

170

Influence of Romanian steam coal quality on power plants environmental impact  

SciTech Connect (OSTI)

Coal provides about 25% of primary energy resources for electricity generation in Romania. Coal is burned in pulverized coal (PC) boilers without flue gas desulfurization (FGD). The coal demands are 90% covered by country`s reserves out of which 80% is lignite. The lignite from Oltenia basin represents about 90% of the domestic lignite quantity used in Romanian power plants. The characteristics defining the typical Romanian lignite are: moisture 40--43%; ash dry basis 37--48%; low heat value 6.0--7.5 MJ/kg; sulfur 0.8--1.2%; volatile matter 17--23%. There are some sorts of lignite which have a higher content of sulfur, but these are used in smaller quantities. RENEL`s strategy includes the preferential utilization of domestic fuels (lignite, hard coal) with imported fuels priority in order natural gas, low sulfur content heavy oil and steam hard coal. Low grade quality of Romanian lignites creates many problems, and due to its high ash and water contents, large quantities of raw coal are required in order to generate energy. The high content of sulfur in coal produces high SO{sub 2} emissions. On the other hand, the very low power values of Romanian lignite generate a low flame temperature, so that, even using fuel oil or gas support for lignite combustion, the NOx emissions are low. Environmental laws have been in force in Romania since December 30, 1995. The Waters Forests and Environment Protection Ministry regulated the pollutant concentration for both new and existing coal fired boilers, beginning in January 1998. Comparing the measured values of SO{sub 2}, NOx and CO contents measured in flue gas from some boilers running on different coal types with the pollutants` emissions limits it is obvious that clean coal technologies (CCT) implementation is necessary, especially for SO{sub 2} reduction.

Matei, M. [Romanian Electricity Authority, Bucharest (Romania). Study, Research and Engineering Group

1998-12-31T23:59:59.000Z

171

PFB coal fired combined cycle development program: commercial plant economic analysis (Task 1. 6)  

SciTech Connect (OSTI)

The objectives of this program are to evaluate the Coal Fired Combined Cycle (CFCC) power plant conceptual design and to conduct supporting development programs for pressurized fluidized bed technology advancement in combustion/steam generator, gas turbine and hot gas cleanup technologies. The Coal-Fired Combined Cycle is the unique power plant concept developed under the leadership of the General Electric Company to provide a direct coal-burning gas turbine and steam turbine combined-cycle power plant. The advantages of the combined cycle for higher efficiency and the potential of the pressurized fluidized bed combustor improvements in emissions could offer a new and attractive option to the electric utility industry. The CFCC approach provides for cooling the fluid bed combustor through the use of steam tubes in the bed which supply a steam turbine generator. The partially cooled combustion gases drive a gas turbine generator after passing through a hot gas cleanup train. The Conceptual CFCC Commercial Plant has been defined in Report No. Fe-2357-28. This design, being conceptual in nature, has not been improved through the formal cost reduction iteration/design program. An economic analysis of this baseline plant is provided in this report. The General Electric Company believes that the combustion of coal by the pressurized fluidized bed process is one of the most effective and efficient means for the utilization of coal with respect to both environmental considerations and the cost of electricity.

Not Available

1980-11-01T23:59:59.000Z

172

A coal-fired power plant with zero-atmospheric emissions - article no. 023005  

SciTech Connect (OSTI)

This paper presents the thermodynamic and cost analysis of a coal-based zero-atmospheric emissions electric power plant. The approach involves an oxygen-blown coal gasification unit. The resulting synthetic gas (syngas) is combusted with oxygen in a gas generator to produce the working fluid for the turbines. The combustion produces a gas mixture composed almost entirely of steam and carbon dioxide. These gases drive multiple turbines to produce electricity. The turbine discharge gases pass to a condenser where water is captured. A stream of carbon dioxide then results that can be used for enhanced oil recovery or for sequestration. The term zero emission steam technology is used to describe this technology We present the analysis of a 400 MW electric power plant. The power plant has a net thermal efficiency of 39%. This efficiency is based on the lower heating value of the coal, and includes the energy necessary for coal gasification, air separation, and for carbon dioxide separation and sequestration. This paper also presents an analysis of the cost of electricity and the cost of conditioning carbon dioxide for sequestration. Electricity cost is compared for three different gasification processes (Texaco, Shell, and Koppers-Totzek) and two types of coals (Illinois 6 and Wyodak). COE ranges from 5.95/kW h to 6.15/kW In, indicating a 3.4% sensitivity to the gasification processes considered and the coal types used.

Martinez-Frias, J.; Aceves, S.M.; Smith, J.R.; Brandt, H. [Lawrence Livermore National Laboratory, Livermore, CA (United States)

2008-03-15T23:59:59.000Z

173

CERAMIC MEMBRANE ENABLING TECHNOLOGY FOR IMPROVED IGCC EFFICIENCY  

SciTech Connect (OSTI)

The objective of this program is to conduct a technology development program to advance the state-of-the-art in ceramic Oxygen Transport Membranes (OTM) to the level required to produce step change improvements in process economics, efficiency, and environmental benefits for commercial IGCC systems and other applications. The IGCC program is focused on addressing key issues in materials, processing, manufacturing, engineering and system development that will make the OTM a commercial reality. The objective of the OTM materials development task is to identify a suitable material that can be formed into a thin film to produce the target oxygen flux. This requires that the material have an adequate permeation rate, and thermo-mechanical and thermo-chemical properties such that the material is able to be supported on the desired substrate and sufficient mechanical strength to survive the stresses involved in operation. The objective of the composite OTM development task is to develop the architecture and fabrication techniques necessary to construct stable, high performance, thin film OTMs supported on suitable porous, load bearing substrates. The objective of the process development task of this program to demonstrate the program objectives on a single OTM tube under test conditions simulating those of the optimum process cycle for the power plant. Good progress has been made towards achieving the DOE-IGCC program objectives. Two promising candidates for OTM materials have been identified and extensive characterization will continue. New compositions are being produced and tested which will determine if the material can be further improved in terms of flux, thermo-mechanical and thermo-chemical properties. Process protocols for the composite OTM development of high quality films on porous supports continues to be optimized. Dense and uniform PSO1 films were successfully applied on porous disc and tubular substrates with good bonding between the films and substrates, and no damage to the substrates or films.

Ravi Prasad

2000-04-01T23:59:59.000Z

174

Innovative process for concentration of fine particle coal slurries. Technical report, March 1- May 31, 1996  

SciTech Connect (OSTI)

Williams Technologies, Inc. And Clarke Rajchel Engineering are developing a technology (patent pending) to produce high quality coal water slurries from preparation plant fine coal streams. The WTI/CRE technology uses the novel implementation of high-shear cross-flow separation which replaces and enhances conventional thickening processes by surpassing normally achievable solids loadings. Dilute ultra-fine (minus 100 mesh) solids slurries can be, concentrated to greater than 60 weight percent and re-mixed, as required, with de-watered coarser fractions to produce pumpable, heavily loaded coal slurries. The permeate (filtrate) resulting from this process has been demonstrated to be crystal clear and totally free of suspended solids. The primary objective of this project was to demonstrate the WTI/CRE coal slurry production process technology at the pilot scale. The technology can enable Illinois coal producers and users to realize significant cost and environmental benefits both by eliminating fine coal waste disposal problems and producing an IGCC fuel to produce power which meets all foreseeable clean air standards. Testing was also directed at concentrating mine tailings material to produce a tailings paste which can be mine-back-filled, eliminating the need for tailings ponds. During the grant period, a laboratory-scale test apparatus (up to 3 GPM feed rate) was assembled and operated to demonstrate process performance over a range of feed temperatures and pressures. A dilute coal/water slurry from Consol, Inc.`s Rend Lake Preparation Plant was concentrated using the process to a maximum recorded solids loading of 61.9% solids by weight. Analytical results from the concentrate were evaluated by Destec Energy for suitability as an IGCC fuel.

Rajchel, M.; Ehrlinger, H.P.; Fonseca, A.; Mauer, R.

1996-12-31T23:59:59.000Z

175

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

SciTech Connect (OSTI)

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.

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

1990-10-01T23:59:59.000Z

176

IGCC and PFBC By-Products: Generation, Characteristics, and Management Practices  

SciTech Connect (OSTI)

The following report is a compilation of data on by-products/wastes from clean coal technologies, specifically integrated gasification combined cycle (IGCC) and pressurized fluidized-bed combustion (PFBC). DOE had two objectives in providing this information to EPA: (1) to familiarize EPA with the DOE CCT program, CCT by-products, and the associated efforts by DOE contractors in the area of CCT by-product management and (2) to provide information that will facilitate EPA's effort by complementing similar reports from industry groups, including CIBO (Council of Industrial Boiler Owners) and EEI USWAG (Edison Electric Institute Utility Solid Waste Activities Group). The EERC cooperated and coordinated with DOE CCT contractors and industry groups to provide the most accurate and complete data on IGCC and PFBC by-products, although these technologies are only now being demonstrated on the commercial scale through the DOE CCT program.

Pflughoeft-Hassett, D.F.

1997-09-01T23:59:59.000Z

177

Sulfur meter for blending coal at Plant Monroe: Final report  

SciTech Connect (OSTI)

An on-line sulfur analyzer, installed at the Detroit Edison, Monroe Power station, was placed into service and evaluated for coal blending optimization to minimize the cost of complying with changing stack gas sulfur dioxide regulations. The project involved debugging the system which consisted of an /open quotes/as-fired/close quotes/ sampler and nuclear source sulfur analyzer. The system was initially plagued with mechanical and electronic problems ranging from coal flow pluggages to calibration drifts in the analyzer. Considerable efforts were successfully made to make the system reliable and accurate. On-line testing showed a major improvement in control of sulfur dioxide emission rates and fuel blending optimization equivalent to as much as $6 million in fuel costs at the time of the evaluation. 7 refs., 14 figs., 12 tabs.

Trentacosta, S.D.; Yurko, J.O.

1988-04-01T23:59:59.000Z

178

Flexible Coal: An Example Evolution from Baseload to Peaking Plant (Presentation)  

SciTech Connect (OSTI)

Twenty-first century power systems, with higher penetration levels of low-carbon energy, smart grids, and other emerging technologies, will favor resources that have low marginal costs and provide system flexibility (e.g., the ability to cycle on and off to follow changes in variable renewable energy plant output). Questions remain about both the fate of coal plants in this scenario and whether they can cost-effectively continue to operate if they cycle routinely. The experience from the CGS plant demonstrates that coal plants can become flexible resources. This flexibility - namely the ability to cycle on and off and run at lower output (below 40% of capacity) - requires limited hardware modifications but extensive modifications to operational practice. Cycling does damage the plant and impact its life expectancy compared to baseload operations. Nevertheless, strategic modifications, proactive inspections and training programs, among other operational changes to accommodate cycling, can minimize the extent of damage and optimize the cost of maintenance. CGS's cycling, but not necessarily the associated price tag, is replicable. Context - namely, power market opportunities and composition of the generation fleet - will help determine for other coal plants the optimal balance between the level of cycling-related forced outages and the level of capital investment required to minimize those outages. Replicating CGS's experience elsewhere will likely require a higher acceptance of forced outages than regulators and plant operators are accustomed to; however, an increase in strategic maintenance can minimize the impact on outage rates.

Cochran, J.

2014-05-01T23:59:59.000Z

179

Flexible Coal: An Example Evolution from Baseload to Peaking Plant (Presentation)  

SciTech Connect (OSTI)

Twenty-first century power systems, with higher penetration levels of low-carbon energy, smart grids, and other emerging technologies, will favor resources that have low marginal costs and provide system flexibility (e.g., the ability to cycle on and off to follow changes in variable renewable energy plant output). Questions remain about both the fate of coal plants in this scenario and whether they can cost-effectively continue to operate if they cycle routinely. The experience from the CGS plant demonstrates that coal plants can become flexible resources. This flexibility - namely the ability to cycle on and off and run at lower output (below 40% of capacity) - requires limited hardware modifications but extensive modifications to operational practice. Cycling does damage the plant and impact its life expectancy compared to baseload operations. Nevertheless, strategic modifications, proactive inspections and training programs, among other operational changes to accommodate cycling, can minimize the extent of damage and optimize the cost of maintenance. CGS's cycling, but not necessarily the associated price tag, is replicable. Context - namely, power market opportunities and composition of the generation fleet - will help determine for other coal plants the optimal balance between the level of cycling-related forced outages and the level of capital investment required to minimize those outages. Replicating CGS's experience elsewhere will likely require a higher acceptance of forced outages than regulators and plant operators are accustomed to; however, an increase in strategic maintenance can minimize the impact on outage rates.

Cochran, J.

2014-08-01T23:59:59.000Z

180

ConocoPhillips Sweeny IGCC/CCS Project  

SciTech Connect (OSTI)

Under its Industrial Carbon Capture and Sequestration (ICCS) Program, the United States (U.S.) Department of Energy (DOE) selected ConocoPhillips Company (ConocoPhillips) to receive funding through the American Recovery and Reinvestment Act (ARRA) of 2009 for the proposed Sweeny Integrated Gasification Combined Cycle (IGCC)/Carbon Capture and Storage (CCS) Project (Project) to be located in Brazoria County, Texas. Under the program, the DOE is partnering with industry to demonstrate the commercial viability and operational readiness of technologies that would capture carbon dioxide (CO{sub 2}) emissions from industrial sources and either sequester those emissions, or beneficially reuse them. The primary objective of the proposed Project was to demonstrate the efficacy of advanced technologies that capture CO{sub 2} from a large industrial source and store the CO{sub 2} in underground formations, while achieving a successful business venture for the entity (entities) involved. The Project would capture 85% of the CO{sub 2} produced from a petroleum coke (petcoke) fed, 703 MWnet (1,000 MWgross) IGCC power plant, using the ConocoPhillips (COP) proprietary and commercially proven E-Gas{trademark} gasification technology, at the existing 247,000 barrel per day COP Sweeny Refinery. In addition, a number of other commercially available technologies would be integrated into a conventional IGCC Plant in a unique, efficient, and reliable design that would capture CO{sub 2}. The primary destination for the CO{sub 2} would be a depleted natural gas field suitable for CO{sub 2} storage ('Storage Facility'). COP would also develop commercial options to sell a portion of the IGCC Plant's CO{sub 2} output to the growing Gulf Coast enhanced oil recovery (EOR) market. The IGCC Plant would produce electric power for sale in the Electric Reliability Council of Texas Houston Zone. The existing refinery effluent water would be treated and reused to fulfill all process water needs. The DOE ICCS program adopts a two-phase approach. During the 7-month Phase 1 period, ConocoPhillips further defined the Project by advancing the preliminary design, permits, and contracts. In addition, ConocoPhillips was developing a Phase 2 renewal application to seek continued DOE funding for the Project's design, construction, and early operations. The DOE and ConocoPhillips entered into a Phase1 Cooperative Agreement (DOE Award Number DE-FE0001859) on November 16, 2009, agreeing to share cost on a 50/50 basis during the Phase 1 period, with a DOE budget of $2,989,174. On April 7, 2010, ConocoPhillips informed the DOE that it would not participate in Phase 2 of the DOE ICCS program. The company believes that enabling legislation and regulations at both the federal and state levels will not be approved and implemented in time to make a final investment decision such that the Project would be substantially constructed by September 30, 2015, the end of the AARA funding period. Considering current price assumptions, the Project would not generate investment level returns. ConocoPhillips elected not to submit a Phase 2 renewal application, which was due on April 16, 2010. This Final Scientific/Technical Report provides an overview of the Project, including highlights and benefits of the proposed carbon capture and storage project scope, sites, and technologies. It also summarizes the work accomplishments during the Phase 1 period from November 16, 2009 to June 16, 2010. Due to ConocoPhillips decision not to submit the Phase 2 renewal application and not to enter into related agreements, certain information regarding the proposed CO{sub 2} storage facility cannot be publicly reported due to confidentiality agreements.

Paul Talarico; Charles Sugg; Thomas Hren; Lauri Branch; Joseph Garcia; Alan Rezigh; Michelle Pittenger; Kathleen Bower; Jonathan Philley; Michael Culligan; Jeremy Maslen; Michele Woods; Kevin Elm

2010-06-16T23:59:59.000Z

Note: This page contains sample records for the topic "igcc coal plants" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


181

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

SciTech Connect (OSTI)

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.

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

2008-10-31T23:59:59.000Z

182

Capture-Ready Coal Plants -Options, Technologies and Economics Mark C. Bohm1  

E-Print Network [OSTI]

-five years. While coal-fired power plants offer significant cost and energy security advantages , John E. Parsons2 , Ram C. Sekar1 1 Laboratory for Energy and the Environment, Massachusetts Institute and pricing of alternative generation technologies, such as solar and wind. In the United States alone

183

Testing Kentucky Coal to Set Design Criteria for a Lurgi Gasification Plant  

E-Print Network [OSTI]

commercial scale gasification test with Kentucky 9 coal in a Lurgi Mark IV dry-bottom gasifier at the Sasol One Plant in Sasolburg, Republic of South Africa, in 1981. The test was conducted to confirm the operability of the Lurgi process on Western Kentucky...

Roeger, A., III; Jones, J. E., Jr.

1983-01-01T23:59:59.000Z

184

CERAMIC MEMBRANE ENABLING TECHNOLOGY FOR IMPROVED IGCC EFFICIENCY  

SciTech Connect (OSTI)

The objective of this program is to conduct a technology development program to advance the state-of-the-art in ceramic Oxygen Transport Membranes (OTM) to the level required to produce step change improvements in process economics, efficiency, and environmental benefits for commercial IGCC systems and other applications. The IGCC program is focused on addressing key issues in materials, processing, manufacturing, engineering and system development that will make the OTM a commercial reality. The objective of the OTM materials development task is to identify a suitable material that can be formed into a thin film to produce the target oxygen flux. This requires that the material have an adequate permeation rate, and thermo-mechanical and thermo-chemical properties such that the material is able to be supported on the desired substrate and sufficient mechanical strength to survive the stresses involved in operation. The objective of the composite OTM development task is to develop the architecture and fabrication techniques necessary to construct stable, high performance, thin film OTMs supported on suitable porous, load bearing substrates. The objective of the process development task of this program to demonstrate the program objectives on a single OTM tube under test conditions simulating those of the optimum process cycle for the power plant.

Ravi Prasad

2000-04-01T23:59:59.000Z

185

Methodology for technology evaluation under uncertainty and its application in advanced coal gasification processes  

E-Print Network [OSTI]

Integrated gasification combined cycle (IGCC) technology has attracted interest as a cleaner alternative to conventional coal-fired power generation processes. While a number of pilot projects have been launched to ...

Gong, Bo, Ph. D. Massachusetts Institute of Technology

2011-01-01T23:59:59.000Z

186

Innovative process for concentration of fine particle coal slurries. Final technical report, September 1, 1995--August 31, 1996  

SciTech Connect (OSTI)

Williams Technologies, Inc. And Clarke Rajchel Engineering are developing a technology (patent pending) to produce high quality coal water slurries from preparation plant fine coal streams. The WTI/CRE technology uses the novel implementation of high-shear cross-flow separation which replaces and enhances conventional thickening processes by surpassing normally achievable solids loadings. Dilute ultra-fine (minus 100 mesh) solids slurries can be concentrated to greater than 60 weight percent and remixed, as required, with de-watered coarser fractions to produce pumpable, heavily loaded coal slurries. The permeate (filtrate) resulting from this process has been demonstrated to be crystal clear and totally free of suspended solids. The primary objective of this project was to demonstrate the WTI/CRE coal slurry production process technology at the pilot scale. The technology can enable Illinois coal producers and users to realize significant cost and environmental benefits both by eliminating fine coal waste disposal problems and producing an IGCC fuel to produce power which meets all foreseeable clean air standards. Testing was also directed at concentrating mine tailings material to produce a tailings paste which can be mine-back- filled, eliminating the need for tailings ponds. During the grant period, a laboratory-scale test apparatus (up to 3 GPM feed rate) was assembled and operated to demonstrate process performance over a range of feed temperatures and pressures. A dilute coal/water slurry from Consol, Inc.`s Rend Lake Preparation Plant was concentrated with the process to a maximum recorded solids loading of 61.9% solids by weight. Analytical results from the concentrate were evaluated by Destec Energy for suitability as an IGCC fuel.

Rajchel, M.; Ehrlinger, H.P.; Harnett, D.; Fonseca, A.; Maurer, R.

1997-05-01T23:59:59.000Z

187

Digital Gas Joins Asian Waste-to-Energy Consortium: To Eliminate Coal as a Power Plant Fuel  

E-Print Network [OSTI]

Energy's patented technology produces a clean-burning by-product from the widest variety of processed-efficient technology represented by the coal-substitute technology. The same technology will be deployed by DIGGDigital Gas Joins Asian Waste-to-Energy Consortium: To Eliminate Coal as a Power Plant Fuel Digital

Columbia University

188

Water recovery using waste heat from coal fired power plants.  

SciTech Connect (OSTI)

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

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

2011-01-01T23:59:59.000Z

189

Coal Direct Chemical Looping Retrofit to Pulverized Coal Power Plants for In-Situ CO2 Capture  

SciTech Connect (OSTI)

A novel Coal Direct Chemical Looping (CDCL) system is proposed to effectively capture CO2 from existing PC power plants. The work during the past three years has led to an oxygen carrier particle with satisfactory performance. Moreover, successful laboratory, bench scale, and integrated demonstrations have been performed. The proposed project further advanced the novel CDCL technology to sub-pilot scale (25 kWth). To be more specific, the following objectives attained in the proposed project are: 1. to further improve the oxygen carrying capacity as well as the sulfur/ash tolerance of the current (working) particle; 2. to demonstrate continuous CDCL operations in an integrated mode with > 99% coal (bituminous, subbituminous, and lignite) conversion as well as the production of high temperature exhaust gas stream that is suitable for steam generation in existing PC boilers; 3. to identify, via demonstrations, the fate of sulfur and NOx; 4. to conduct thorough techno-economic analysis that validates the technical and economical attractiveness of the CDCL system. The objectives outlined above were achieved through collaborative efforts among all the participants. CONSOL Energy Inc. performed the techno-economic analysis of the CDCL process. Shell/CRI was able to perform feasibility and economic studies on the large scale particle synthesis and provide composite particles for the sub-pilot scale testing. The experience of B&W (with boilers) and Air Products (with handling gases) assisted the retrofit system design as well as the demonstration unit operations. The experience gained from the sub-pilot scale demonstration of the Syngas Chemical Looping (SCL) process at OSU was able to ensure the successful handling of the solids. Phase 1 focused on studies to improve the current particle to better suit the CDCL operations. The optimum operating conditions for the reducer reactor such as the temperature, char gasification enhancer type, and flow rate were identified. The modifications of the existing bench scale reactor were completed in order to use it in the next phase of the project. In Phase II, the optimum looping medium was selected, and bench scale demonstrations were completed using them. Different types of coal char such as those obtained from bituminous, subbituminous, and lignite were tested. Modifications were made on the existing sub-pilot scale unit for coal injection. Phase III focused on integrated CDCL demonstration in the sub-pilot scale unit. A comprehensive ASPEN® simulations and economic analysis was completed by CONSOL t is expected that the CDCL process will be ready for further demonstrations in a scale up unit upon completion of the proposed project.

Zeng, Liang; Li, Fanxing; Kim, Ray; Bayham, Samuel; McGiveron, Omar; Tong, Andrew; Connell, Daniel; Luo, Siwei; Sridhar, Deepak; Wang, Fei; Sun, Zhenchao; Fan, Liang-Shih

2013-09-30T23:59:59.000Z

190

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

SciTech Connect (OSTI)

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 therefore determines the steam cycle parameters and combustion technology that would yield the lowest cost of electricity (COE) for the next generation of coal-fired steam power plants. The second part of the study (Repowering) explores the means of upgrading the efficiency and output of an older existing coal fired steam power plant. There are currently more than 1,400 coal-fired units in operation in the United States generating about 54 percent of the electricity consumed. Many of these are modern units are clean and efficient. Additionally, there are many older units in excellent condition and still in service that could benefit from this repowering technology. The study evaluates the technical feasibility, thermal performance, and economic viability of this repowering concept.

Richard E. Waryasz; Gregory N. Liljedahl

2004-09-08T23:59:59.000Z

191

Coal demonstration plants. Quarterly report, April-June 1979  

SciTech Connect (OSTI)

The objective of the US DOE demonstration program is to demonstrate and verify second-generation technologies and validate the economic, environmental and productive capacity of a near commercial-size plant by integrating and operating a modular unit using commercial size equipment. These facilities are the final stage in the RD and D process aimed at accelerating and reducing the risks of industrial process implementation. Under the DOE program, contracts for the design, construction, and operation of the demonstration plants are awarded through competitive procedures and are cost shared with the industrial partner. The conceptual design phase is funded by the government, with the detailed design, procurement, construction, and operation phases being co-funded between industry and the government. The government share of the cost involved for a demonstration plant depends on the plant size, location, and the desirability and risk of the process to be demonstrated. The various plants and programs are discussed: Description and status, funding, history, flowsheet and progress during the current quarter. (LTN)

None

1980-04-01T23:59:59.000Z

192

Model Predictive Control of Integrated Gasification Combined Cycle Power Plants  

SciTech Connect (OSTI)

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.

B. Wayne Bequette; Priyadarshi Mahapatra

2010-08-31T23:59:59.000Z

193

New 90,000 PPH Coal Fired Boiler Plant at Liggett & Myers Tobacco Company, Durham North Carolina  

E-Print Network [OSTI]

Liggett & Myers Tobacco Company in Durham, North Carolina is installing a future cogeneration, coal fired boiler system designed and built by Energy Systems (ESI) of Chattanooga, Tennessee. The complete boiler plant is comprised of a 90,000 pph Dorr...

Kaskey, G. T.

1984-01-01T23:59:59.000Z

194

Cost and U.S. public policy for new coal power plants with carbon capture and sequestration  

E-Print Network [OSTI]

This paper provides a financial analysis for new supercritical pulverized coal plants with carbon capture and sequestration (CCS) that compares the effects of two relevant climate policies. First, an updated cost estimate ...

Hamilton, Michael R.

195

Aerosol dispersion and coagulation from a coal-fired power plant: a three dimensional numerical model  

SciTech Connect (OSTI)

A computational model to simulate the dispersion and coagulation of aerosols emitted from coal-fired power plants was constructed. In modeling the dispersion of the aerosol, turbulent diffusion and wind-driven advection are treated by a finite-difference method. Molecular coagulation is incorporated in the model to follow shifts in the particle-size distribution. Particulate coagulation is mathematically described by Timiskii's equation. The relevent semi-empirical work of Smirnov is incorporated in the model to provide for the coagultion constant. Input for the model is a bimodal, particle-size distribution measured at an operating coal-fired power plant. Simulations indicate that dispersion competes against coagulation mechanisms to maintain the bimodal shaped distribution for 32 km. Turbulence and particle settling tend to enchance coagulation effects. The size-dependent spatial segregation of particles within the plume is predicted.

Buckholtz, H.T.; Biermann, A.H.

1980-01-01T23:59:59.000Z

196

Clean coal technologies in electric power generation: a brief overview  

SciTech Connect (OSTI)

The paper talks about the future clean coal technologies in electric power generation, including pulverized coal (e.g., advanced supercritical and ultra-supercritical cycles and fluidized-bed combustion), integrated gasification combined cycle (IGCC), and CO{sub 2} capture technologies. 6 refs., 2 tabs.

Janos Beer; Karen Obenshain [Massachusetts Institute of Technology (MIT), MA (United States)

2006-07-15T23:59:59.000Z

197

Financing Capture Ready Coal-Fired Power Plants in China by Issuing Capture Options  

E-Print Network [OSTI]

) IGCC (Integrated Gasification Combined Cycle) IPCC (Intergovernmental Panel on Climate Change) LHV (Low Heating Value) Local EPA (Local Environment Protection Administration in China) MLR (Ministry of Land Electricity Regulatory Commission in China) Solar PV Power (Solar Photovoltaic Power) Std Dev (Standard

Aickelin, Uwe

198

Abdel-Aziz, A. and H.C. Frey, "Quantification of Hourly Variability in Hourly Activity and NOx Emissions for Baseload Coal-Fired Power Plants," Proceedings, Annual Meeting of the Air & Waste Management Association, Pittsburgh, PA, June 2003  

E-Print Network [OSTI]

Emissions for Baseload Coal- Fired Power Plants," Proceedings, Annual Meeting of the Air & Waste Management emission factors from coal-fired power plants vary over time due to variation in coal composition fed or to evaluate the variability of NOx emission rates for coal-fired power plants of the 100 largest electric

Frey, H. Christopher

199

Simulated coal gas MCFC power plant system verification. Final report  

SciTech Connect (OSTI)

The objective of the main project is to identify the current developmental status of MCFC systems and address those technical issues that need to be resolved to move the technology from its current status to the demonstration stage in the shortest possible time. The specific objectives are separated into five major tasks as follows: Stack research; Power plant development; Test facilities development; Manufacturing facilities development; and Commercialization. This Final Report discusses the M-C power Corporation effort which is part of a general program for the development of commercial MCFC systems. This final report covers the entire subject of the Unocal 250-cell stack. Certain project activities have been funded by organizations other than DOE and are included in this report to provide a comprehensive overview of the work accomplished.

NONE

1998-07-30T23:59:59.000Z

200

US Department of Energy`s high-temperature and high-pressure particulate cleanup for advanced coal-based power systems  

SciTech Connect (OSTI)

The availability of reliable, low-cost electricity is a cornerstone for the United States` ability to compete in the world market. The Department of Energy (DOE) projects the total consumption of electricity in the US to rise from 2.7 trillion kilowatt-hours in 1990 to 3.5 trillion in 2010. Although energy sources are diversifying, fossil fuel still produces 90 percent of the nation`s energy. Coal is our most abundant fossil fuel resource and the source of 56 percent of our electricity. It has been the fuel of choice because of its availability and low cost. A new generation of high-efficiency power systems has made it possible to continue the use of coal while still protecting the environment. Such power systems greatly reduce the pollutants associated with cola-fired plants built before the 1970s. To realize this high efficiency and superior environmental performance, advanced coal-based power systems will require gas stream cleanup under high-temperature and high-pressure (HTHP) process conditions. Presented in this paper are the HTHP particulate capture requirements for the Integrated Gasification Combined Cycle (IGCC) and Pressurized Fluidized-Bed Combustion (PFBC) power systems, the HTHP particulate cleanup systems being implemented in the PFBC and IGCC Clean Coal Technology (CCT) Projects, and the currently available particulate capture performance results.

Dennis, R.A.

1997-05-01T23:59:59.000Z

Note: This page contains sample records for the topic "igcc coal plants" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


201

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

SciTech Connect (OSTI)

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, would reduce energy use and concomitant water consumption. These inefficiencies include air heater inefficiencies, boiler corrosion, low operating temperatures, fuel inefficiencies, and older components that are subject to strain and failure. A variety of nanotechnology applications that could potentially be used to reduce the amount of freshwater consumed - either directly or indirectly - by these areas and activities was identified. These applications include membranes that use nanotechnology or contain nanomaterials for improved water purification and carbon capture; nano-based coatings and lubricants to insulate and reduce heat loss, inhibit corrosion, and improve fuel efficiency; nano-based catalysts and enzymes that improve fuel efficiency and improve sulfur removal efficiency; nanomaterials that can withstand high temperatures; nanofluids that have better heat transfer characteristics than water; nanosensors that can help identify strain and impact damage, detect and monitor water quality parameters, and measure mercury in flue gas; and batteries and capacitors that use nanotechnology to enable utility-scale storage. Most of these potential applications are in the research stage, and few have been deployed at coal-fired power plants. Moving from research to deployment in today's economic environment will be facilitated with federal support. Additional support for research development and deployment (RD&D) for some subset of these applications could lead to reductions in water consumption and could provide lessons learned that could be applied to future efforts. To take advantage of this situation, it is recommended that NETL pursue funding for further research, development, or deployment for one or more of the potential applications identified in this report.

Elcock, D. (Environmental Science Division)

2010-09-17T23:59:59.000Z

202

PFB coal fired combined cycle development program. Commercial plant requirements definition update (Task 1. 1)  

SciTech Connect (OSTI)

The Coal Fired Combined Cycle (CFCC) power system thermodynamic cycle is illustrated schematically. Pressurized air supplied at the discharge of gas turbine compressors is ducted to the pressure vessel of pressurized, fluidized-bed, combustor-steam generator modules. The air is introduced in parallel to the beds, entering through distribution grids beneath each bed. Steam generation tubes are buried within the beds and are also arranged as membrane tube walls enclosing the four sides. Crushed coal (1/4 inch x 0) is pneumatically fed at locations just above the air inlet grids at the bottom of each bed. Dolomite is similarly fed to the individual beds. The coal is burned at a temperature below the ash fusion point. Sulfur is removed in the fluid beds through reaction of the SO/sub 2/ with CaCO/sub 3/ and O/sub 2/ to form solid CaSO/sub 4/ and CO/sub 2/ gas. The combustion gases leave the beds at a temperature in the range of 1400/sup 0/F to 1750/sup 0/F, depending upon the plant load fraction, and combustion heat is also transferred from the bed to the steam generation tubes. For the PFB combustor at full load, approximately 39% of the heating value of the coal appears i the exhaust gas, 57% appears in the steam, and 4% is apportioned among various losses. The steam circuitry is the supercritical once-through type. Steam is generated at 3500 psi and 1000/sup 0/F and is reheated to 1000/sup 0/F after expansion through the high pressure section of the steam turbine. The exhaust gases from the fluidized beds, which entrain a high percentage of the coal ash as well as dolomite fines, are ducted to conventional cyclones and then to electrocyclones before being admitted to the gas turbine.

Not Available

1980-05-01T23:59:59.000Z

203

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

SciTech Connect (OSTI)

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.

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

2004-12-01T23:59:59.000Z

204

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

SciTech Connect (OSTI)

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.

Holt, N.; Findsen, J.

2008-11-15T23:59:59.000Z

205

Integrated Gasification Combined Cycle (IGCC) demonstration project, Polk Power Station -- Unit No. 1. Annual report, October 1993--September 1994  

SciTech Connect (OSTI)

This describes the Tampa Electric Company`s Polk Power Station Unit 1 (PPS-1) Integrated Gasification Combined Cycle (IGCC) demonstration project which will use a Texaco pressurized, oxygen-blown, entrained-flow coal gasifier to convert approximately 2,300 tons per day of coal (dry basis) coupled with a combined cycle power block to produce a net 250 MW electrical power output. Coal is slurried in water, combined with 95% pure oxygen from an air separation unit, and sent to the gasifier to produce a high temperature, high pressure, medium-Btu syngas with a heat content of about 250 Btu/scf (LHV). The syngas then flows through a high temperature heat recovery unit which cools the syngas prior to its entering the cleanup systems. Molten coal ash flows from the bottom of the high temperature heat recovery unit into a water-filled quench chamber where it solidifies into a marketable slag by-product.

NONE

1995-05-01T23:59:59.000Z

206

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

SciTech Connect (OSTI)

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 deposition and fish content. Soil and vegetation sampling programs were performed around two mid-size coal fired power plants. 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 model predictions. These programs found the following: (1) At both sites, there was no correlation between modeled mercury deposition and either soil concentrations or vegetation concentrations. At the Kincaid plant, there was excess soil Hg along heavily traveled roads. The spatial pattern of soil mercury concentrations did not match the pattern of vegetation Hg concentrations at either plant. (2) At both sites, the subsurface (5-10 cm) samples the Hg concentration correlated strongly with the surface samples (0-5 cm). Average subsurface sample concentrations were slightly less than the surface samples; however, the difference was not statistically significant. (3) An unequivocal definition of background Hg was not possible at either site. Using various assumed background soil mercury concentrations, the percentage of mercury deposited within 10 km of the plant ranged between 1.4 and 8.5% of the RGM emissions. Based on computer modeling, Hg deposition was primarily RGM with much lower deposition from elemental mercury. Estimates of the percentage of total Hg deposition ranged between 0.3 and 1.7%. These small percentages of deposition are consistent with the empirical findings of only minor perturbations in environmental levels, as opposed to ''hot spots'', near the plants. The major objective of this study was to determine if there was evidence for ''hot-spots'' of mercury deposition around coal-fired power plants. Although the term has been used extensively, it has never been defined. 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 affect water bodies large enough to support a population of subsistence fishers. The results of this study support the hypothesis that n

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

2005-12-01T23:59:59.000Z

207

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

SciTech Connect (OSTI)

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.

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

1990-05-01T23:59:59.000Z

208

PSNH's Northern Wood power project repowers coal-fired plant with new fluidized-bed combustor  

SciTech Connect (OSTI)

The Northern Wood Power project permanently replaced a 50-MW coal-burning boiler (Unit 5) at Public Service of New Hampshire's Schiller station with a state-of-the-art circulating fluidized bed wood-burning boiler of the same capacity. The project, completed in December 2006, reduced emissions and expanded the local market for low-grade wood. For planning and executing the multiyear, $75 million project at no cost to its ratepayers, PSNH wins Power's 2007 Marmaduke Award for excellence in O & M. The award is named for Marmaduke Surfaceblow, the fictional marine engineer/plant troubleshoot par excellence. 7 figs., 1 tab.

Peltier, R.

2007-08-15T23:59:59.000Z

209

Feasibility study for the Ao Phai coal fired power plant. Export trade information  

SciTech Connect (OSTI)

The report presents the results of a study by Burns and Roe commissioned by the Electricity Generating Authority of Thailand to unify data obtained in a previous series of studies which investigated the location and design of a new fossil fired power station. The Ao Phai location was selected as the preferred sight. To unify existing data, the study was performed with the following objectives: To upgrade and update previous site investigations at Ao Phai; To carry out additional investigations required to complete the preparation of a feasibility study; and To prepare an integrated and bankable feasibility report of the Ao Phai Coal Fired Power Plant.

Mahr, D.; Shamamian, V.; Zisman, E.D.; Richards, R.T.

1988-12-01T23:59:59.000Z

210

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

SciTech Connect (OSTI)

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.

Radisav Vidic; Joseph Flora; Eric Borguet

2008-12-31T23:59:59.000Z

211

Utilization of Lightweight Materials Made from Coal Gasificaiton Slags  

SciTech Connect (OSTI)

The integrated gasification combined-cycle (IGCC) coal conversion process has been demonstrated to be a clean, efficient, and environmentally acceptable method of generating power; however, it generates solid waste materials in relatively large quantities. For example, a 400-MW power plant using 4000 tons of 10% ash coal per day may generate over 440 tons/day of solid waste of slag, consisting of vitrified mineral matter and unburned carbon. The disposal of the wastes represents significant costs. Regulatory trends with respect to solid wastes disposal, landfill development costs and public concern make utilization of solid wastes a high-priority issue. As coal gasification technologies find increasing commercial applications for power generation or production of chemical feed stocks, it becomes imperative that slag utilization methods be developed, tested and commercialized in order to offset disposal costs. Praxis is working on a DOE/METC funded project to demonstrate the technical and economic feasibility of making lightweight and ultra-lightweight aggregates from slags left as solid by-products from the coal gasification process. The project objectives are to develop and demonstrate the technology for producing slag-based lightweight aggregates (SLA), to produce 10 tons of SLA products with different unit weights from two slags, to collect operational and emissions data from pilot-scale operations, and to conduct laboratory and commercial scale evaluations of SLA with conventional lightweight and ultra-lightweight aggregates.

Choudhry, V.; Hadley, S. [Praxis Engineers, Inc., Milpitas, CA (United States)

1996-12-31T23:59:59.000Z

212

Optimal Synthesis of a Pulverized Coal Power Plant with Carbon Capture  

SciTech Connect (OSTI)

Coal constitutes an important source of fuel for the production of power in the United States. For instance, in January 2009, pulverized coal (PC) power plants alone contributed to over 45 percent of the Nation's total electric power production. However, PC power plants also contribute to increased emissions of greenhouse gases principally carbon-dioxide (CO2). Recently, various carbon capture strategies have been under active investigation so as to make these plants compete with the more environmental friendly renewable energy sources. One such technology that has received considerable success is the capture of CO2 by an amine-based solvent extraction process. However, an aqueous absorption/stripping technology when used in a PC power plant can reduce the net power output of the plant by as much as 20-40%. The energy penalty comes from heating up the solvent in the regenerator, balancing the enthalpy of reaction, and water stripping. This energy penalty poses considerable limitations on commercial viability of the solvent extraction process and, as a result, various energy-saving modifications have been proposed in the literature ranging from the use of hybrid solvents to novel stripper configurations. In this paper, we show that the energy penalty can be further reduced by heat integration of various PC plant components with the carbon capture system. In addition to the release of greenhouse gases to the environment, PC plants also consume a large amount of freshwater. It is estimated that subcritical and supercritical PC plants have water losses of 714 gal/MWh and 639 gal/MWh, respectively. Water loss is based on an overall balance of the plant source and exit streams. This includes coal moisture, air humidity, process makeup, cooling tower makeup (equivalent to evaporation plus blowdown), process losses (including losses through reactions, solids entrainment, and process makeup/blowdown) and flue gas losses. The primary source of water used in PC power plants is the closed-loop steam-based (Rankine) power cycles. These plants need to condense large quantities of low-pressure steam back to water so that it can be reused to produce high pressure steam. However, this requires the removal of large quantities of heat from the low pressure steam in the condensation process. This is usually done by transferring the heat to cooling water, which in turn transfers this heat to the environment by evaporation to the atmosphere. Also, the inclusion of a carbon capture process can increase the raw water usage by as much as 95 percent. In this work, we use heat exchanger network synthesis followed by an optimization approach to process synthesis for developing strategies for reducing water use in a supercritical PC power plant with a carbon capture and compression system. Uncertainties associated with dry bulb temperature, relative humidity, and demand will also be considered in this analysis.

Prakash R. Kotecha; Juan M. Salazar; Stephen Zitney

2009-01-01T23:59:59.000Z

213

Mechanical sampling systems for coal quality control in Romanian power plants  

SciTech Connect (OSTI)

According to ISO 1988 samples must be taken from moving currents by using certain mechanical devices, and, only, exceptionally, by an understanding between party`s, by manually sampling. The principal requirements when designing and constructing a mechanical sampling system are that: it shall be capable of collecting and preparing increments or samples, as the case may be, that are free from relevant bias; it shall maintain this capability under all such conditions of sampling that are stipulated in the relevant specifications and without necessitating that sampling be interrupted for cleaning or maintenance. Actually, coal quality control in Romanian power plants are usually performed by a manual system. In order to meet ISO 1988 requirements, RENEL-GSCI (formerly ICEMENERG) has designed and achieved a falling stream sampler with cutter bucket in accordance with ISO 9411-1 (solid mineral fuels - Mechanical sampling from moving stream) provisions. This device has been installed in the Oradea 2 cogeneration power plant in the coal falling stream at the end of the belt conveyor. When the mechanical sampling installation was commissioned, experiments to check for precision and bias had been out for the installation as a whole. The method of checking for bias was by comparison with stopped-belt sampling. The mechanical sampling device is still under testing. The paper presents the result obtained during the preliminary test period in order to certify the mechanical sampler.

Matei, M. [Romanian Electricity Authority, Bucharest (Romania). Study, Research and Engineering Group

1998-12-31T23:59:59.000Z

214

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

SciTech Connect (OSTI)

Carbon capture and sequestration (CCS) has the ability to dramatically reduce carbon dioxide (CO2) emissions from power production. Most studies find the potential for 70 to 80 percent reductions in CO2 emissions on a life-cycle basis, depending on the technology. Because of this potential, utilities and policymakers are considering the wide-spread implementation of CCS technology on new and existing coal plants to dramatically curb greenhouse gas (GHG) emissions from the power generation sector. However, the implementation of CCS systems will have many other social, economic, and environmental impacts beyond curbing GHG emissions that must be considered to achieve sustainable energy generation. For example, emissions of nitrogen oxides (NOx), sulfur oxides (SOx), and particulate matter (PM) are also important environmental concerns for coal-fired power plants. For example, several studies have shown that eutrophication is expected to double and acidification would increase due to increases in NOx emissions for a coal plant with CCS provided by monoethanolamine (MEA) scrubbing. Potential for human health risks is also expected to increase due to increased heavy metals in water from increased coal mining and MEA hazardous waste, although there is currently not enough information to relate this potential to actual realized health impacts. In addition to environmental and human health impacts, supply chain impacts and other social, economic, or strategic impacts will be important to consider. A thorough review of the literature for life-cycle analyses of power generation processes using CCS technology via the MEA absorption process, and other energy generation technologies as applicable, yielded large variability in methods and core metrics. Nonetheless, a few key areas of impact for CCS were developed from the studies that we reviewed. These are: the impact of MEA generation on increased eutrophication and acidification from ammonia emissions and increased toxicity from MEA production and the impact of increased coal use including the increased generation of NOx from combustion and transportation, impacts of increased mining of coal and limestone, and the disposal of toxic fly ash and boiler ash waste streams. Overall, the implementing CCS technology could contribute to a dramatic decrease in global GHG emissions, while most other environmental and human health impact categories increase only slightly on a global scale. However, the impacts on human toxicity and ecotoxicity have not been studied as extensively and could have more severe impacts on a regional or local scale. More research is needed to draw strong conclusions with respect to the specific relative impact of different CCS technologies. Specifically, a more robust data set that disaggregates data in terms of component processes and treats a more comprehensive set of environmental impacts categories from a life-cycle perspective is needed. In addition, the current LCA framework lacks the required temporal and spatial scales to determine the risk of environmental impact from carbon sequestration. Appropriate factors to use when assessing the risk of water acidification (groundwater/oceans/aquifers depending on sequestration site), risk of increased human toxicity impact from large accidental releases from pipeline or wells, and the legal and public policy risk associated with licensing CO2 sequestration sites are also not currently addressed. In addition to identifying potential environmental, social, or risk-related issues that could impede the large-scale deployment of CCS, performing LCA-based studies on energy generation technologies can suggest places to focus our efforts to achieve technically feasible, economically viable, and environmentally conscious energy generation technologies for maximum impact.

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

2011-11-30T23:59:59.000Z

215

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

SciTech Connect (OSTI)

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).

Not Available

1992-11-01T23:59:59.000Z

216

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

SciTech Connect (OSTI)

This final report describes work conducted for the U.S. Department of Energy National Energy Technology Laboratory (DOE NETL) on development of an efficient membrane process to capture carbon dioxide (CO{sub 2}) from power plant flue gas (award number DE-NT0005312). The primary goal of this research program was to demonstrate, in a field test, the ability of a membrane process to capture up to 90% of CO{sub 2} in coal-fired flue gas, and to evaluate the potential of a full-scale version of the process to perform this separation with less than a 35% increase in the levelized cost of electricity (LCOE). Membrane Technology and Research (MTR) conducted this project in collaboration with Arizona Public Services (APS), who hosted a membrane field test at their Cholla coal-fired power plant, and the Electric Power Research Institute (EPRI) and WorleyParsons (WP), who performed a comparative cost analysis of the proposed membrane CO{sub 2} capture process. The work conducted for this project included membrane and module development, slipstream testing of commercial-sized modules with natural gas and coal-fired flue gas, process design optimization, and a detailed systems and cost analysis of a membrane retrofit to a commercial power plant. The Polaris? membrane developed over a number of years by MTR represents a step-change improvement in CO{sub 2} permeance compared to previous commercial CO{sub 2}-selective membranes. During this project, membrane optimization work resulted in a further doubling of the CO{sub 2} permeance of Polaris membrane while maintaining the CO{sub 2}/N{sub 2} selectivity. This is an important accomplishment because increased CO{sub 2} permeance directly impacts the membrane skid cost and footprint: a doubling of CO{sub 2} permeance halves the skid cost and footprint. In addition to providing high CO{sub 2} permeance, flue gas CO{sub 2} capture membranes must be stable in the presence of contaminants including SO{sub 2}. Laboratory tests showed no 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 CO{sub 2} and 50 for CO{sub 2}/N{sub 2}), operating with no feed compression and l

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

2012-03-31T23:59:59.000Z

217

Elemental Modes of Occurrence in an Illinois #6 Coal and Fractions Prepared by Physical Separation Techniques at a Coal Preparation Plant  

SciTech Connect (OSTI)

In order to gain better insight into elemental partitioning between clean coal and tailings, modes of occurrence have been determined for a number of major and trace elements (S, K, Ca, V, Cr, Mn, Fe, Zn, As, Se, Pb) in an Illinois No.6 coal and fractions prepared by physical separation methods at a commercial coal preparation plant. Elemental modes of occurrence were largely determined directly by XAFS or Moessbauer spectroscopic methods because the concentrations of major minerals and wt.% ash were found to be highly correlated for this coal and derived fractions, rendering correlations between individual elements and minerals ambiguous for inferring elemental modes of occurrence. Of the major elements investigated, iron and potassium are shown to be entirely inorganic in occurrence. Most (90%) of the iron is present as pyrite, with minor fractions in the form of clays and sulfates. All potassium is present in illitic clays. Calcium in the original coal is 80-90% inorganic and is divided between calcite, gypsum, and illite, with the remainder of the calcium present as carboxyl-bound calcium. In the clean coal fraction, organically associated Ca exceeds 50% of the total calcium. This organically-associated form of Ca explains the poorer separation of Ca relative to both K and ash. Among the trace elements, V and Cr are predominantly inorganically associated with illite, but minor amounts (5-15% Cr, 20-30% V) of these elements are also organically associated. Estimates of the V and Cr contents of illite are 420 ppm and 630 ppm, respectively, whereas these elements average 20 and 8 ppm in the macerals. Arsenic in the coal is almost entirely associated with pyrite, with an average As content of about 150 ppm, but some As ({approx} 10%) is present as arsenate due to minor oxidation of the pyrite. The mode of occurrence of Zn, although entirely inorganic, is more complex than normally noted for Illinois basin coals; about 2/3 is present in sphalerite, with lesser amounts associated with illite and a third form yet to be conclusively identified. The non-sulfide zinc forms are removed predominantly by the first stage of separation (rotary breaker), whereas the sphalerite is removed by the second stage (heavy media). Germanium is the only trace element determined to have a predominantly organic association.

Huggins, F.; Seidu, L; Shah, N; Huffman, G; Honaker, R; Kyger, J; Higgins, B; Robertson, J; Pal, S; Seehra, M

2009-01-01T23:59:59.000Z

218

Autothermal coal gasification  

SciTech Connect (OSTI)

Test data from the Ruhrchemie/Ruhrkohle Texaco coal gasification demonstration plant at Oberhausen are reported. (5 refs.)

Konkol. W.; Ruprecht, P.; Cornils, B.; Duerrfeld, R.; Langhoff, J.

1982-03-01T23:59:59.000Z

219

The ADESORB Process for Economical Production of Sorbents for Mercury Removal from Coal Fired Power Plants  

SciTech Connect (OSTI)

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 significant shortages in supply if response to new demand is not well-timed.

Robin Stewart

2008-03-12T23:59:59.000Z

220

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

SciTech Connect (OSTI)

Coal-fired power plants, equipped either with oxycombustion or post-combustion CO{sub 2} capture, will require a CO{sub 2} compression system to increase the pressure of the CO{sub 2} to the level needed for sequestration. Most analyses show that CO{sub 2} compression will have a significant effect on parasitic load, will be a major capital cost, and will contribute significantly to reduced unit efficiency. This project used first principle engineering analyses and computer simulations to determine the effects of utilizing compressor waste heat to improve power plant efficiency and increase net power output of coal-fired power plants with carbon capture. This was done for units with post combustion solvent-based CO{sub 2} capture systems and for oxyfired power plants, firing bituminous, PRB and lignite coals. The thermal integration opportunities analyzed for oxycombustion capture are use of compressor waste heat to reheat recirculated flue gas, preheat boiler feedwater and predry high-moisture coals prior to pulverizing the coal. Among the thermal integration opportunities analyzed for post combustion capture systems are use of compressor waste heat and heat recovered from the stripper condenser to regenerate post-combustion CO{sub 2} capture solvent, preheat boiler feedwater and predry high-moisture coals. The overall conclusion from the oxyfuel simulations is that thermal integration of compressor heat has the potential to improve net unit heat rate by up to 8.4 percent, but the actual magnitude of the improvement will depend on the type of heat sink used and to a lesser extent, compressor design and coal rank. The simulations of a unit with a MEA post combustion capture system showed that thermal integration of either compressor heat or stripper condenser heat to preheat boiler feedwater would result in heat rate improvements from 1.20 percent to 4.19 percent. The MEA capture simulations further showed that partial drying of low rank coals, done in combination with feedwater heating, would result in heat rate reductions of 7.43 percent for PRB coal and 10.45 percent for lignite.

Edward Levy

2012-06-29T23:59:59.000Z

Note: This page contains sample records for the topic "igcc coal plants" from the National Library of EnergyBeta (NLEBeta).
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221

Conceptual design of a coal-fired MHD retrofit of the J. E. Corette Plant: Design definition  

SciTech Connect (OSTI)

The design, construction, and operation of a fully integrated coal burning MHD/steam-power system has been identified as a necessary step for commercialization of MHD power gerneation. The addition of an MHD power system to an existing utility's conventional steam power plant is presently considered an efficient and attractive method for realization of this, and the conceptual design of a coal-fired MHD power plant has been initiated as an important item of the National MHD development program. Current activities of the MHD development program comprise proof-of-concepts testing of MHD topping cycle components and bottoming cycle components at the Components Development and Integration Facility (CDIF) and the Coal Fired Flow Facility (CFFF), respectively, at subscale levels. The MHD plant will provide for operation and testing of a fully integrated MHD/steam power system in a utility environment at a larger size consistent with its objectives. Its main objectives are to verify the technical and economic feasibility of commercial MHD power genration including environmental aspects and to provide electric utilities and equipment manufacturers with the necessary information and confidence to proceed with commercialization of MHD. The coal-fired J.E. Corette steam plant unit of the Montana Power Company at Billings, Montana has been selected for this MHD conceptual design activity.

Not Available

1988-02-01T23:59:59.000Z

222

Investigation of feasibility of injecting power plant waste gases for enhanced coalbed methane recovery from low rank coals in Texas  

E-Print Network [OSTI]

such as power plants. CO2 emissions can be offset by sequestration of produced CO2 in natural reservoirs such as coal seams, which may initially contain methane. Production of coalbed methane can be enhanced through CO2 injection, providing an opportunity...

Saugier, Luke Duncan

2004-09-30T23:59:59.000Z

223

7-29 A coal-burning power plant produces 300 MW of power. The amount of coal consumed during a one-day period and the rate of air flowing through the furnace are to be determined.  

E-Print Network [OSTI]

7-11 7-29 A coal-burning power plant produces 300 MW of power. The amount of coal consumed during The heating value of the coal is given to be 28,000 kJ/kg. Analysis (a) The rate and the amount of heat inputs'tQQ The amount and rate of coal consumed during this period are kg/s48.33 s360024 kg10893.2 MJ/kg28 MJ101.8 6

Bahrami, Majid

224

CERAMIC MEMBRANE ENABLING TECHNOLOGY FOR IMPROVED IGCC EFFICIENCY  

SciTech Connect (OSTI)

The objectives of the second year of the program are to define a material composition and composite architecture that enable the oxygen flux and stability targets to be obtained in high-pressure flux tests. Composite technology will be developed to enable the production of high-quality, defect free membranes of a thickness that allows the oxygen flux target to be obtained. The fabrication technology will be scaled up to produce three feet composite tubes with the desired leak rate. A laboratory scale, multi-tube pilot reactor will be designed and constructed to produce oxygen. In the third quarter of the second year of the program, work has focused on materials optimization, composite and manufacturing development and oxygen flux testing at high pressures. This work has led to several major achievements, summarized by the following statements: Oxygen has been produced under conditions similar to IGCC operation using composite OTM elements at a flux greater than the 2001 target. Under conditions with a greater driving force the commercial target flux has been met. Methods to significantly increase the oxygen flux without compromise to its mechanical integrity have been identified. Composite OTM elements have demonstrated stable operation at {Delta}P > 250 psi Design of the pilot plant is complete and construction will begin next quarter.

Ravi Prasad

2001-08-01T23:59:59.000Z

225

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

SciTech Connect (OSTI)

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)

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

1991-05-01T23:59:59.000Z

226

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

SciTech Connect (OSTI)

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)

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

1991-05-01T23:59:59.000Z

227

Proposed finding of no significant impact for the Sakakawea Medical Center coal-fired heating plant  

SciTech Connect (OSTI)

The Department of Energy (the Department) has prepared an environmental assessment (Assessment) (DOE/EA-0949) to identify and evaluate the potential environmental impacts of a proposed action at the Sakakawea Medical Center (the Center) in Hazen, North Dakota. The proposed action would replace the existing No. 2 fuel oil-fired boilers supplemented by electric reheat with a new coal-fired hot water heating plant, using funds provided from a grant under the Institutional Conservation Program. Based on the analysis in DOE/EA-0949, the Department has determined that the proposed action is not a major federal action significantly affecting the quality of the human environment, within the meaning of the National Environmental Policy Act (NEPA) of 1969, as amended. Therefore, preparation of an Environmental Impact Statement is not required, and the Department is issuing this Finding of No Significant Impact (Finding).

Not Available

1994-07-01T23:59:59.000Z

228

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

SciTech Connect (OSTI)

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.

Fthenakis, V.M.; Lipfert, F.; Moskowitz, P. [Brookhaven National Lab., Upton, NY (United States). Analytical Sciences Div.

1994-12-01T23:59:59.000Z

229

Boiler materials for ultra-supercritical coal power plants - steamside oxidation  

SciTech Connect (OSTI)

The corrosion behavior of tubing materials carrying steam at high temperature is of great concern to fossil power plant operators. This is due to the fact that the oxide films formed on the steam side can lead to major failures and consequently to reduced plant availability. The wall loss of the pressure boundary caused by oxidation can increase the hoop stresses and cause premature creep failures; second, the increased insulation of the tubes due to the low thermal conductivity of the oxide film can lead to increased metal temperature, thereby exacerbating the fireside corrosion as well as creep problems. The third concern is that thicker oxides may spall more easily when the plant is cooled down. On restart, the spalled material may lodge somewhere in the system with the potential for causing tube blockages, or it may be swept out with the working fluid and enter the steam turbine causing erosion damage to the turbine nozzles and blades. Failures of tubing and turbine components by these mechanisms have been widely reported in the United States. In view of the importance of the steamside oxidation, a major study of the phenomenon is being carried out as part of a major national program sponsored by the U.S. Department of Energy and the Ohio Coal Development Office. As a prelude to the experimental work, a literature survey was performed to document the state of the art. Results of the review are reported here.

Viswanathan, R.; Sarver, J.; Tanzosh, J.M. [Electric Power Research Institute, Palo Alto, CA (United States)

2006-06-15T23:59:59.000Z

230

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

SciTech Connect (OSTI)

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.

Constance Senior

2004-12-31T23:59:59.000Z

231

Carbon dioxide capture from coal-fired power plants : a real potions analysis  

E-Print Network [OSTI]

Investments in three coal-fired power generation technologies are valued using the "real options" valuation methodology in an uncertain carbon dioxide (CO2) price environment. The technologies evaluated are pulverized coal ...

Sekar, Ram Chandra

2005-01-01T23:59:59.000Z

232

Innovative process for concentration of fine particle coal slurries. Technical report, September 1--November 30, 1995  

SciTech Connect (OSTI)

Williams Technologies, Inc. and Clarke Rajchel Engineering are developing a technology (patent pending) to produce high quality coal water slurries from preparation plant fine coal streams. The WTI/CRE technology uses the novel implementation of high-shear cross-flow separation which replaces and enhances conventional thickening processes by surpassing normally achievable solids loadings. Dilute ultra-fine (minus 100 mesh) solids slurries can be concentrated to greater than 60 weight percent and re-mixed, as required, with de-watered coarser fractions to produce pumpable, heavily loaded coal slurries. The permeate (filtrate) resulting from this process has been demonstrated to be crystal clear and totally free of suspended solids. The primary objective of this project is to demonstrate the WTI/CRE coal slurry production process technology at the pilot scale. The technology will enable Illinois coal producers and users to realize significant coast and environmental benefits both by eliminating fine coal waste disposal problems and producing an IGCC fuel to produce power which meets all foreseeable clean air standards. In addition, testing is also directed at concentrating mine tailings material to produce a tailings paste which can be mine-back-, filled and thus eliminate the need for tailings ponds. This reporting period, September 1, 1995 through November 30, 1995, marked the inception of this project. During this period Task No. 1, Procurement and Set-Up, was completed. The pilot plant apparatus was constructed at the SIU Coal Research Center in Carterville, Illinois. All equipment and feedstock were received at the site.

Rajchel, M. [Williams Technologies, Inc. (United States)]|[Clarke Rajchel Engineering, Arvada, CO (United States); Harnett, D. [Williams Technologies, Inc. (United States); Fonseca, A. [CONSOL, Pittsburgh, PA (United States); Maurer, R. [Destec (United States); Ehrlinger, H.P.

1995-12-31T23:59:59.000Z

233

Reuse of Produced Water from CO2 Enhanced Oil Recovery, Coal-Bed Methane, and Mine Pool Water by Coal-Based Power Plants  

SciTech Connect (OSTI)

Power generation in the Illinois Basin is expected to increase by as much as 30% by the year 2030, and this would increase the cooling water consumption in the region by approximately 40%. This project investigated the potential use of produced water from CO{sub 2} enhanced oil recovery (CO{sub 2}-EOR) operations; coal-bed methane (CBM) recovery; and active and abandoned underground coal mines for power plant cooling in the Illinois Basin. Specific objectives of this project were: (1) to characterize the quantity, quality, and geographic distribution of produced water in the Illinois Basin; (2) to evaluate treatment options so that produced water may be used beneficially at power plants; and (3) to perform a techno-economic analysis of the treatment and transportation of produced water to thermoelectric power plants in the Illinois Basin. Current produced water availability within the basin is not large, but potential flow rates up to 257 million liters per day (68 million gallons per day (MGD)) are possible if CO{sub 2}-enhanced oil recovery and coal bed methane recovery are implemented on a large scale. Produced water samples taken during the project tend to have dissolved solids concentrations between 10 and 100 g/L, and water from coal beds tends to have lower TDS values than water from oil fields. Current pretreatment and desalination technologies including filtration, adsorption, reverse osmosis (RO), and distillation can be used to treat produced water to a high quality level, with estimated costs ranging from $2.6 to $10.5 per cubic meter ($10 to $40 per 1000 gallons). Because of the distances between produced water sources and power plants, transportation costs tend to be greater than treatment costs. An optimization algorithm was developed to determine the lowest cost pipe network connecting sources and sinks. Total water costs increased with flow rate up to 26 million liters per day (7 MGD), and the range was from $4 to $16 per cubic meter ($15 to $60 per 1000 gallons), with treatment costs accounting for 13 â?? 23% of the overall cost. Results from this project suggest that produced water is a potential large source of cooling water, but treatment and transportation costs for this water are large.

Chad Knutson; Seyed Dastgheib; Yaning Yang; Ali Ashraf; Cole Duckworth; Priscilla Sinata; Ivan Sugiyono; Mark Shannon; Charles Werth

2012-04-30T23:59:59.000Z

234

PressurePressure Indiana Coal Characteristics  

E-Print Network [OSTI]

TimeTime PressurePressure · Indiana Coal Characteristics · Indiana Coals for Coke · Coal Indiana Total Consumption Electricity 59,664 Coke 4,716 Industrial 3,493 Major Coal- red power plantsTransportation in Indiana · Coal Slurry Ponds Evaluation · Site Selection for Coal Gasification · Coal-To-Liquids Study, CTL

Fernández-Juricic, Esteban

235

Assessment of instrumentation needs for advanced coal power plant applications: Final report  

SciTech Connect (OSTI)

The purpose of this study was to identify contaminants, identify instrumentation needs, assess available instrumentation and identify instruments that should be developed for controlling and monitoring gas streams encountered in the following power plants: Integrated Gasification Combined Cycle, Pressurized Fluidized Bed Combustion, and Gasification Molten Carbonate Fuel Cell. Emphasis was placed on hot gas cleanup system gas stream analysis, and included process control, research and environmental monitoring needs. Commercial process analyzers, typical of those currently used for process control purposes, were reviewed for the purpose of indicating commercial status. No instrument selection guidelines were found which were capable of replacing user interaction with the process analyzer vendors. This study leads to the following conclusions: available process analyzers for coal-derived gas cleanup applications satisfy current power system process control and regulatory requirements, but they are troublesome to maintain; commercial gas conditioning systems and in situ analyzers continue to be unavailable for hot gas cleanup applications; many research-oriented gas stream characterization and toxicity assessment needs can not be met by commercially available process analyzers; and greater emphasis should be placed on instrumentation and control system planning for future power plant applications. Analyzers for specific compounds are not recommended other than those needed for current process control purposes. Instead, some generally useful on-line laser-based and inductively coupled plasma methods are recommended for further development because of their potential for use in present hot gas cleanup research and future optimization, component protection and regulation compliance activities. 48 refs., 21 figs., 26 tabs.

Nelson, E.T.; Fischer, W.H.; Lipka, J.V.; Rutkowski, M.D.; Zaharchuk, R.

1987-10-01T23:59:59.000Z

236

Meteorological measurements in the vicinity of a coal burning power plant  

SciTech Connect (OSTI)

High concentrations of sulfur dioxide (SO2) are commonly observed during the cool season in the vicinity of a 2.5 GW coal burning power plant located in the Mae Moh Valley of northern Thailand. The power plant is the source for nearly all of the observed SO2 since there are no other major industrial activities in this region. These high pollution fumigation events occur almost on a daily basis, usually lasting for several hours between late morning and early afternoon. One-hour average SO2 concentrations commonly exceed 1,000 micrograms/cu m. As a result, an increase in the number of respiratory type health complaints have been observed by local clinics during this time of the year. Meteorological data were acquired from a variety of observing platforms during an intensive field study from December 1993 to February 1994. The measurements included horizontal and vertical wind velocity, air temperature, relative humidity, and solar radiation. In addition, turbulent flux measurements were acquired by a sonic anemometer. SO2 measurements were made at seven monitoring sites scattered throughout the valley. These data were used to examine the atmospheric processes which are responsible for these high pollution fumigation events.

Crescenti, G.H.; Gaynor, J.E.

1995-05-01T23:59:59.000Z

237

Improved refractories for IGCC power systems  

SciTech Connect (OSTI)

Certain advantages make coal gasification a key element in the US Department of Energy's Vision 21 power system. However, issues of reliability and gasifier operation economics need to be resolved before gasification is widely adopted by the power generation industry.

Dogan, Cynthia P.; Kwong, Kyei-Sing; Bennet, James P.; Chinn, Richard E.; Dahlin, Cheryl L.

2002-09-01T23:59:59.000Z

238

Future Impacts of Coal Distribution Constraints on Coal Cost  

E-Print Network [OSTI]

OF RAIL TRANSPORTATION OF COAL The Federal Energy RegulatoryPlants Due to Coal Shortages”, Federal Energy RegulatoryCouncil (NCC), 2006, “Coal: America’s Energy Future”, Volume

McCollum, David L

2007-01-01T23:59:59.000Z

239

Future Impacts of Coal Distribution Constraints on Coal Cost  

E-Print Network [OSTI]

of total electricity generation is because coal plants haveplants come to play an important role in the electricity generationplants will be built in the years around 2020, thereby increasing coal’s share of electricity generation

McCollum, David L

2007-01-01T23:59:59.000Z

240

URBAN WOOD/COAL CO-FIRING IN THE NIOSH BOILER PLANT  

SciTech Connect (OSTI)

Phase I of this project began by obtaining R&D variances for permits at the NIOSH boilerplant (NBP), Emery Tree Service (ETS) and the J. A. Rutter Company (JARC) for their portions of the project. Wood for the test burn was obtained from the JARC inventory (pallets), Thompson Properties and Seven D Corporation (construction wood), and the Arlington Heights Housing Project (demolition wood). The wood was ground at ETS and JARC, delivered to the Three Rivers Terminal and blended with coal. Three one-day tests using wood/coal blends of 33% wood by volume (both construction wood and demolition wood) were conducted at the NBP. Blends using hammermilled wood were operationally successful. Emissions of SO{sub 2} and NOx decreased and that of CO increased when compared with combusting coal alone. Mercury emissions were measured and evaluated. During the first year of Phase II the principal work focused upon searching for a replacement boilerplant and developing a commercial supply of demolition wood. The NBP withdrew from the project and a search began for another stoker boilerplant in Pennsylvania to replace it on the project. Three potential commercial demolition wood providers were contacted. Two were not be able to supply wood. At the end of the first year of Phase II, discussions were continuing with the third one, a commercial demolition wood provider from northern New Jersey. During the two-and-a-third years of the contract extension it was determined that the demolition wood from northern New Jersey was impractical for use in Pittsburgh, in another power plant in central New Jersey, and in a new wood gasifier being planned in Philadelphia. However, the project team did identify sufficient wood from other sources for the gasifier project. The Principal Investigator of this project assisted a feasibility study of wood gasification in Clarion County, Pennsylvania. As a result of the study, an independent power producer in the county has initiated a small wood gasification project at its site. Throughout much of this total project the Principal Investigator has counseled two small businesses in developing a waxed cardboard pellet business. A recent test burn of this biofuel appears successful and a purchase contract is anticipated soon. During the past two months a major tree-trimming firm has shown an active interest in entering the wood-chip fuel market in the Pittsburgh area and has contacted the NBP, among others, as potential customers. The NBP superintendent is currently in discussion with the facilities management of the Bruceton Research Center about resuming their interest in cofiring this renewable fuel to the stoker there.

James T. Cobb Jr.

2005-02-10T23:59:59.000Z

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241

Near-term implications of a ban on new coal-fired power plants in the United States  

SciTech Connect (OSTI)

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.

Adam Newcomer; Jay Apt [Carnegie Mellon University, Pittsburgh, PA (United States). Carnegie Mellon Electricity Industry Center

2009-06-15T23:59:59.000Z

242

CERAMIC MEMBRANE ENABLING TECHNOLOGY FOR IMPROVED IGCC EFFICIENCY  

SciTech Connect (OSTI)

This quarterly technical progress report will summarize work accomplished for Phase 2 Program during the quarter April to June 2004. In task 7, reactor cost analysis was performed to determine whether OTM technology when integrated with IGCC provides a commercially attractive process. In task 9, discussions with DOE regarding restructuring the program continued. The objectives of the second year of phase 2 of the program are to construct and operate an engineering pilot reactor for OTM oxygen. Work to support this objective is being undertaken in the following areas in this quarter: IGCC process analysis and economics.

John Sirman

2005-01-01T23:59:59.000Z

243

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

SciTech Connect (OSTI)

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

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

2014-01-01T23:59:59.000Z

244

Oxy-fuel Combustion and Integrated Pollutant Removal as Retrofit Technologies for Removing CO2 from Coal Fired Power Plants  

SciTech Connect (OSTI)

One third of the US installed capacity is coal-fired, producing 49.7% of net electric generation in 20051. Any approach to curbing CO2 production must consider the installed capacity and provide a mechanism for preserving this resource while meeting CO2 reduction goals. One promising approach to both new generation and retrofit is oxy-fuel combustion. Using oxygen instead of air as the oxidizer in a boiler provides a concentrated CO2 combustion product for processing into a sequestration-ready fluid.... Post-combustion carbon capture and oxy-fuel combustion paired with a compression capture technology such as IPR are both candidates for retrofitting pc combustion plants to meet carbon emission limits. This paper will focus on oxy-fuel combustion as applied to existing coal power plants.

Ochs, T.L.; Oryshchyn, D.B.; Summers, C.A.; Gerdemann, S.J.

2001-01-01T23:59:59.000Z

245

The Diffusion of Clean Coal Combustion Technologies for Power Plants in China.  

E-Print Network [OSTI]

??China’s energy structure is characterized by a striking dominance of coal. This situation is not expected to change in a foreseeable future and causes serious… (more)

Liu, Liguang

2005-01-01T23:59:59.000Z

246

EA-1642-S1: Small-Scale Pilot Plant for the Gasification of Coal and Coal-Biomass Blends and Conversion of Derived Syngas to Liquid Fuels via Fischer-Tropsch Synthesis, Lexington, KY  

Broader source: Energy.gov [DOE]

This draft Supplemental Environmental Assessment (SEA) analyzes the potential environmental impacts of DOE’s proposed action of providing cost-shared funding for the University of Kentucky (UK) Center for Applied Energy Research (CAER) Small-Scale Pilot Plant for the Gasification of Coal and Coal-Biomass Blends and Conversion of Derived Syngas to Liquid Fuels via Fischer-Tropsch Synthesis project and of the No-Action Alternative.

247

Virtually simulating the next generation of clean energy technologies: NETL's AVESTAR Center is dedicated to the safe, reliable and efficient operation of advanced energy plants with carbon capture  

SciTech Connect (OSTI)

Imagine using a real-time virtual simulator to learn to fly a space shuttle or rebuild your car's transmission without touching a piece of equipment or getting your hands dirty. Now, apply this concept to learning how to operate and control a state-of-the-art, electricity-producing power plant capable of carbon dioxide (CO{sub 2}) capture. That's what the National Energy Technology Laboratory's (NETL) Advanced Virtual Energy Simulation Training and Research (AVESTAR) Center (www.netl.doe.gov/avestar) is designed to do. Established as part of the Department of Energy's (DOE) initiative to advance new clean energy technology for power generation, the AVESTAR Center focuses primarily on providing simulation-based training for process engineers and energy plant operators, starting with the deployment of a first-of-a-kind operator training simulator for an integrated gasification combined cycle (IGCC) power plant with CO{sub 2} capture. The IGCC dynamic simulator builds on, and reaches beyond, conventional power plant simulators to merge, for the first time, a 'gasification with CO{sub 2} capture' process simulator with a 'combined-cycle' power simulator. Based on Invensys Operations Management's SimSci-Esscor DYNSIM software, the high-fidelity dynamic simulator provides realistic training on IGCC plant operations, including normal and faulted operations, as well as plant start-up, shutdown and power demand load changes. The highly flexible simulator also allows for testing of different types of fuel sources, such as petcoke and biomass, as well as co-firing fuel mixtures. The IGCC dynamic simulator is available at AVESTAR's two locations, NETL (Figure 1) and West Virginia University's National Research Center for Coal and Energy (www.nrcce.wvu.edu), both in Morgantown, W.Va. By offering a comprehensive IGCC training program, AVESTAR aims to develop a workforce well prepared to operate, control and manage commercial-scale gasification-based power plants with CO{sub 2} capture. The facility and simulator at West Virginia University promotes NETL's outreach mission by offering hands-on simulator training and education to researchers and university students.

Zitney, S.

2012-01-01T23:59:59.000Z

248

Evolution of particulate emissions from a coal-fired power plant. [Ph. D. Thesis  

SciTech Connect (OSTI)

A numerical model has been developed for the dispersal of aerosols downwind from a coal-fired power plant. The main goals were to evaluate with a mathematical simulation the evolution of the spatial extent and particle size distribution of the aerosol material and to predict settling rates affecting the surface environment in the downwind path. The hot air plume coming out of the power plant stack includes a large quantity of aerosol particles. The plume rises with initial upward emission speed until it reaches thermal and kinetic equilibria with the ambient air, then it is transported by the wind current. The plume disperses vertically and horizontally by wind turbulence. In the model particulate coagulation is mathematically described by Timiskii's equation. The relevant semi-empirical work of Smirnov is incorporated to provide the coagulation constant. Because of coagulation, the concentrations of different sizes of aerosol particles in the plume are changed. The numerical simulation studies the importance of particulate coagulation and turbulent dispersion on the downwind plume profile. The downwind transport of the aerosol particles is described by Fick's diffusion equation with the Brownian diffusion coefficient replaced by the turbulent diffusion coefficient. Particle sedimentation is incorporated into the diffusion equation as a first-order differential term. The transport equation is solved by an unconditionally stable finite difference method. At 20 miles downwind, most of the particles with diameter larger than 10 ..mu..m have settled to the ground. The size distribution is still bimodal. The distribution of larger particles remains almost unchanged, except for the departure of the super-micronic particles, because coagulation losses are approximately balanced by coagulation gains.

Buckholtz, H.T.Y.

1980-08-15T23:59:59.000Z

249

ENERGY UTILIZATION AND ENVIRONMENTAL CONTROL TECHNOLOGIES IN THE COAL-ELECTRIC CYCLE  

E-Print Network [OSTI]

Electric Generation Technology Conventional Coal-Fired PowerPlants Advanced Coal-Electric Plants OperatingCharacteristics for Conventional Coal- Fired Power

Ferrell, G.C.

2010-01-01T23:59:59.000Z

250

The Caterpillar Coal Gasification Facility  

E-Print Network [OSTI]

This paper is a review of one of America's premier coal gasification installations. The caterpillar coal gasification facility located in York, Pennsylvania is an award winning facility. The plant was recognized as the 'pace setter plant of the year...

Welsh, J.; Coffeen, W. G., III

1983-01-01T23:59:59.000Z

251

baepgig-clean | netl.doe.gov  

Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

5 Industrial Carbon Capture and Storage Clean Coal Power Initiative Power Plant Improvement Initiative Clean Coal Technology Demonstration Program FutureGen Kentucky Pioneer IGCC...

252

baepgig-pinon | netl.doe.gov  

Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

4 Industrial Carbon Capture and Storage Clean Coal Power Initiative Power Plant Improvement Initiative Clean Coal Technology Demonstration Program FutureGen Pion Pine IGCC Power...

253

brwtp_tcigcc | netl.doe.gov  

Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

4 Industrial Carbon Capture and Storage Clean Coal Power Initiative Power Plant Improvement Initiative Clean Coal Technology Demonstration Program FutureGen Toms Creek IGCC...

254

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

SciTech Connect (OSTI)

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

Kozhevnikova, M.; Lange, I. [Queens College, Flushing, NY (United States)

2009-05-15T23:59:59.000Z

255

Atmospheric Aerosol Source-Receptor Relationships: The Role of Coal-Fired Power Plants  

SciTech Connect (OSTI)

This report describes the technical progress made on the Pittsburgh Air Quality Study (PAQS) during the period of March 2005 through August 2005. Significant progress was made this project period on the source characterization, source apportionment, and deterministic modeling activities. This report highlights new data on road dust, vegetative detritus and motor vehicle emissions. For example, the results show significant differences in the composition in urban and rural road dust. A comparison of the organic of the fine particulate matter in the tunnel with the ambient provides clear evidence of the significant contribution of vehicle emissions to ambient PM. The source profiles developed from this work are being used by the source-receptor modeling activities. The report presents results on the spatial distribution of PMF-factors. The results can be grouped into three different categories: regional sources, local sources, or potentially both regional and local sources. Examples of the regional sources are the sulfate and selenium PMF-factors which most likely-represent coal fired power plants. Examples of local sources are the specialty steel and lead factors. There is reasonable correspondence between these apportionments and data from the EPA TRI and AIRS emission inventories. Detailed comparisons between PMCAMx predictions and measurements by the STN and IMPROVE measurements in the Eastern US are presented. Comparisons were made for the major aerosol components and PM{sub 2.5} mass in July 2001, October 2001, January 2002, and April 2002. The results are encouraging with average fraction biases for most species less than 0.25. The improvement of the model performance during the last two years was mainly due to the comparison of the model predictions with the continuous measurements in the Pittsburgh Supersite. Major improvements have included the descriptions: of ammonia emissions (CMU inventory), night time nitrate chemistry, EC emissions and their diurnal variation, and nitric acid dry removal.

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

2005-12-01T23:59:59.000Z

256

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

SciTech Connect (OSTI)

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

Dinis, Maria de Lurdes; Fiuza, Antonio; Soeiro de Carvalho, Jose; Gois, Joaquim [Geo-Environment and Resources Research Centre (CIGAR), Porto University, Faculty of Engineering - FEUP, Rua Dr. Roberto Frias, 4200-465 Porto (Portugal)] [Geo-Environment and Resources Research Centre (CIGAR), Porto University, Faculty of Engineering - FEUP, Rua Dr. Roberto Frias, 4200-465 Porto (Portugal); Meira Castro, Ana Cristina [School of Engineering Polytechnic of Porto - ISEP, Rua Dr. Antonio Bernardino de Almeida, 431, 4200-072, Porto (Portugal)] [School of Engineering Polytechnic of Porto - ISEP, Rua Dr. Antonio Bernardino de Almeida, 431, 4200-072, Porto (Portugal)

2013-07-01T23:59:59.000Z

257

Simultaneous removal of H{sub 2}S and NH{sub 3} from coal gas. Final report  

SciTech Connect (OSTI)

Hydrogen sulfide (H{sub 2}S) and ammonia (NH{sub 3}) are the primary sulfur and nitrogen contaminants released when coal is gasified. Before coal gas can be utilized in an integrated gasification combined cycle (IGCC) plant to produce electricity, these contaminants need to be removed. The objective of this research was to develop sorbent-catalysts with the ability to simultaneously remove H{sub 2}S and NH{sub 3} from coal gas. Microreactor tests with HART-49, a zinc-based sorbent-catalyst with Ni, Co, and Mo as catalyst additives, showed that this material had the potential to remove 90% NH{sub 3} and reduce H{sub 2}S to <20 ppmv at 1 atm and 550 to 700 C. HART-49 was prepared in attrition-resistant fluidizable form (HART-56) using up to 75 wt% binder. Bench-scale fluidized-bed multicycle tests were conducted with the attrition-resistant sorbent-catalyst, HART-56, at 20 atm and 550 C. The H{sub 2}S and NH{sub 3} removal performance over the first two cycles was good in the presence of 5% steam but deteriorated thereafter when steam level was increased to 15%. The results point to a complex mechanism for simultaneous H{sub 2}S and NH{sub 3} removal, potentially involving both chemisorption and catalytic decomposition of NH{sub 3}. Further research and development is needed to develop a sorbent-catalyst for simultaneous H{sub 2}S and NH{sub 3} removal at IGCC hot-gas cleanup conditions.

Gangwal, S.K.; Portzer, J.W.

1998-05-01T23:59:59.000Z

258

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

SciTech Connect (OSTI)

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

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

2012-09-30T23:59:59.000Z

259

Design study of a coal-fired thermionic (THX) topped power plant. Volume IV. Thermionic heat exchanger design and costing  

SciTech Connect (OSTI)

This volume deals with the details of how thermionic conversion works, and how it is used in a coal-fired furnace to achieve power plant efficiencies of 45%, and overall costs of 36.3 mills/kWh. A review of the fundamental technical aspects of thermionic conversion is given. The overall Thermionic Heat Exchanger (THX) design, the heat pipe design, and the interaction of the heat pipes with the furnace are presented. Also, the operational characteristics of thermionic converters are described. Details on the computer program used to perform the parametric study are given. The overall program flow is reviewed along with the specifics of how the THX subroutine designed the converter to match the conditions imposed. Also, input costs and variables effecting the THX's performance are detailed. The efficiencies of the various power plants studied are given as a function of the air preheat temperature, size of the power plant, and thermionic level of performance.

Dick, R.S.; Britt, E.J.

1980-10-15T23:59:59.000Z

260

Decommissioning samples from the Ft. Lewis, WA, solvent refined coal pilot plant: chemical analysis and biological testing  

SciTech Connect (OSTI)

This report presents the results from chemical analyses and limited biological assays of three sets of samples from the Ft. Lewis, WA solvent refined coal (SRC) pilot plant. The samples were collected during the process of decommissioning this facility. Chemical composition was determined for chemical class fractions of the samples by using high-resolution gas chromatography (GC), high-resolution GC/mass spectrometry (MS) and high-resolution MS. Biological activity was measuring using both the histidine reversion microbial mutagenicity assay with Salmonella typhimurium, TA98 and an initiation/promotion mouse-skin tumorigenicity assay. 19 refs., 7 figs., 27 tabs.

Weimer, W.C.; Wright, C.W.

1985-10-01T23:59:59.000Z

Note: This page contains sample records for the topic "igcc coal plants" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


261

Influence of coal ash and slag dumping on dump waste waters of the Kostolac power plants (Serbia)  

SciTech Connect (OSTI)

The content of selected trace and major elements in the river water used for transport, as well as in the subcategories of the waste waters (overflow and drainage) were analyzed in order to establish the influence of transport and dumping of coal ash and slag from the 'Kostolac A' and 'Kostolac B' power plants located 100 km from Belgrade (Serbia). It was found that during transport of coal ash and slag to the dump, the water used for transport becomes enriched with manganese, nickel, zinc, chromium, vanadium, titanium, cobalt, arsenic, aluminum, and silicon, while more calcium, iron, cadmium, and lead are adsorbed by the ash and slag than is released from them. There is also an equilibrium between the release and adsorption processes of copper and magnesium during transport. The vertical penetration of the water used for transport results in a release of calcium, magnesium, manganese, and cadmium to the environment, while iron, nickel, zinc, chromium, copper, lead, vanadium, titanium, cobalt, and arsenic are adsorbed by the fractions of coal ash and slag in the dump.

Popovic, A.; Djinovic, J. [University of Belgrade, Belgrade (Serbia)

2006-10-01T23:59:59.000Z

262

Exergy method of power plant systems analysis and its application to a pressurized fluidized bed coal-fired combined-cycle power plant  

SciTech Connect (OSTI)

This thesis surveys the concepts of exergy and extends the exergy method of analysis from the standpoint of its applications to the power plant systems. After a brief historical review of exergy concepts, the general exergy equation is derived from the combined equation of First and Second Law, and it is shown that any special case of exergy equation is a simplified form of the general exergy equation. The mathematical method for the exergy analysis of a steady-state, steady-flow system, analogous to that of the First Law, is given. The exergy losses in a power plant are discussed. Then in order to examine these losses, the Second Law performance of major processes of combustion, compression, heat transfer, mixing and throttling have been analyzed analytically, and the exergy efficiencies are defined that accurately assess the thermodynamic performance of the corresponding processes. The methods for computation of exergy loss and exergy efficiency are given and simplified for practical cases of the corresponding processes. Analytical methods for evaluating the exergy of coal, pure substances (air and water), and combustion gases are presented and the energy-exergy tables for corresponding working substances are constructed. Finally, a comprehensive thermodynamic analysis, with emphasis on the Second Law (exergy) consideration, of an actual coal-fired, combined-cycle (CFCC) power plant, being designed by the General Electric Company, is carried out and suggestions are made as to what (and where), if any, improvement might be made in the design.

Ghamarian, A.

1981-01-01T23:59:59.000Z

263

CERAMIC MEMBRANE ENABLING TECHNOLOGY FOR IMPROVED IGCC EFFICIENCY  

SciTech Connect (OSTI)

This quarterly technical progress report will summarize work accomplished for Phase 2 Program during the quarter April to June 2004. In task 1, long term testing of OTM elements at different temperatures and process conditions continued. In task 2, OTM elements were manufactured as necessary for task 1. In task 7, advanced OTM and cryogenic IGCC cases for near-term integration were developed, leading to cost requirements for commercial viability. In task 9, discussion with DOE regarding restructuring the program for subsequent phases were initiated. The objectives of the second year of phase 2 of the program are to construct and operate an engineering pilot reactor for OTM oxygen. Work to support this objective is being undertaken in the following areas in this quarter: Element reliability; Element fabrication; and IGCC process analysis and economics. The major accomplishments this quarter were: Long term life test of OTM element passed nine months at different testing conditions.

Ravi Prasad

2004-09-01T23:59:59.000Z

264

CERAMIC MEMBRANE ENABLING TECHNOLOGY FOR IMPROVED IGCC EFFICIENCY  

SciTech Connect (OSTI)

The objectives of the first year of phase 2 of the program are to construct and operate an engineering pilot reactor for OTM oxygen. Work to support this objective is being undertaken in the following areas in this quarter: Element reliability; Element fabrication; Systems technology; Power recovery; and IGCC process analysis and economics. The major accomplishments this quarter were Preferred OTM architectures have been identified through stress analysis; and The 01 reactor was operated at target flux and target purity for 1000 hours.

Ravi Prasad

2003-04-30T23:59:59.000Z

265

CERAMIC MEMBRANE ENABLING TECHNOLGOY FOR IMPROVED IGCC EFFICIENCY  

SciTech Connect (OSTI)

This quarterly technical progress report will summarize work accomplished for Phase 2 Program during the quarter April to June 2003. In task 1 OTM development has led to improved flux and strength performance. In task 2, robust PSO1d elements have been fabricated for testing in the pilot reactor. In task 3, the lab-scale pilot reactor has been operated for 1000 hours with improved success. In task 7, economic models substantial benefit of OTM IGCC over CRYO based oxygen production.

Ravi Prasad

2003-07-01T23:59:59.000Z

266

Sustainable development with clean coal  

SciTech Connect (OSTI)

This paper discusses the opportunities available with clean coal technologies. Applications include new power plants, retrofitting and repowering of existing power plants, steelmaking, cement making, paper manufacturing, cogeneration facilities, and district heating plants. An appendix describes the clean coal technologies. These include coal preparation (physical cleaning, low-rank upgrading, bituminous coal preparation); combustion technologies (fluidized-bed combustion and NOx control); post-combustion cleaning (particulate control, sulfur dioxide control, nitrogen oxide control); and conversion with the integrated gasification combined cycle.

NONE

1997-08-01T23:59:59.000Z

267

Advanced Multi-Product Coal Utilization By-Product Processing Plant  

SciTech Connect (OSTI)

The overall objective of this project is to design, construct, and operate an ash beneficiation facility that will generate several products from coal combustion ash stored in a utility ash pond. The site selected is LG&E's Ghent Station located in Carroll County, Kentucky. The specific site under consideration is the lower ash pond at Ghent, a closed landfill encompassing over 100 acres. Coring activities revealed that the pond contains over 7 million tons of ash, including over 1.5 million tons of coarse carbon and 1.8 million tons of fine (<10 {micro}m) glassy pozzolanic material. These potential products are primarily concentrated in the lower end of the pond adjacent to the outlet. A representative bulk sample was excavated for conducting laboratory-scale process testing while a composite 150 ton sample was also excavated for demonstration-scale testing at the Ghent site. A mobile demonstration plant with a design feed rate of 2.5 tph was constructed and hauled to the Ghent site to evaluate unit processes (i.e. primary classification, froth flotation, spiral concentration, secondary classification, etc.) on a continuous basis to determine appropriate scale-up data. Unit processes were configured into four different flowsheets and operated at a feed rate of 2.5 tph to verify continuous operating performance and generate bulk (1 to 2 tons) products for product testing. Cementitious products were evaluated for performance in mortar and concrete as well as cement manufacture process addition. All relevant data from the four flowsheets was compiled to compare product yields and quality while preliminary flowsheet designs were generated to determine throughputs, equipment size specifications and capital cost summaries. A detailed market study was completed to evaluate the potential markets for cementitious products. Results of the study revealed that the Ghent local fly ash market is currently oversupplied by more than 500,000 tpy and distant markets (i.e. Florida) are oversupplied as well. While the total US demand for ultrafine pozzolan is currently equal to demand, there is no reason to expect a significant increase in demand. Despite the technical merits identified in the pilot plant work with regard to beneficiating the entire pond ash stream, market developments in the Ohio River Valley area during 2006-2007 were not conducive to demonstrating the project at the scale proposed in the Cooperative Agreement. As a result, Cemex withdrew from the project in 2006 citing unfavorable local market conditions in the foreseeable future at the demonstration site. During the Budget Period 1 extensions provided by the DOE, CAER has contacted several other companies, including cement producers and ash marketing concerns for private cost share. Based on the prevailing demand-supply situation, these companies had expressed interest only in limited product lines, rather than the entire ash beneficiation product stream. Although CAER had generated interest in the technology, a financial commitment to proceed to Budget Period 2 could not be obtained from private companies. Furthermore, the prospects of any decisions being reached within a reasonable time frame were dim. Thus, CAER concurred with the DOE to conclude the project at the end of Budget Period 1, March 31, 2007. The activities presented in this report were carried out during the Cooperative Agreement period 08 November 2004 through 31 March 2007.

Thomas Robl; John Groppo

2009-06-30T23:59:59.000Z

268

Biological removal of organic constituents in quench waters from high-Btu coal-gasification pilot plants  

SciTech Connect (OSTI)

Studies were initiated to assess the efficiency of bench-scale, activated-sludge treatment for removal of organic constituents from coal-gasification process effluents. Samples of pilot-plant, raw-gas quench waters were obtained from the HYGAS process of the Institute of Gas Technology and from the slagging, fixed-bed (SFB) process of the Grand Forks Energy Technology Center. The types of coal employed were Bituminous Illinois No. 6 for the HYGAS and Indian Head lignite for the SFB process. These pilot-plant quench waters, while not strictly representative of commercial condensates, were considered useful to evaluate the efficiency of biological oxidation for the removal of organics. Biological-reactor influent and effluent samples were extracted using a methylene chloride pH-fractionation method into acid, base, and neutral fractions, which were analyzed by capillary-column gas-chromatography/mass-spectrometry. Influent acid fractions of both HYGAS and SFB condensates showed that nearly 99% of extractable and chromatographable organic material comprised phenol and alkylated phenols. Activated-sludge treatment removed these compounds almost completely. Removal efficiency of base-fraction organics was generally good, except for certain alkylated pyridines. Removal of neutral-fraction organics was also good, except for certain alkylated benzenes, certain polycyclic aromatic hydrocarbons, and certain cycloalkanes and cycloalkenes, especially at low influent concentrations.

Stamoudis, V C; Luthy, R G

1980-02-01T23:59:59.000Z

269

Biological removal of organic constituents in quench water from a slagging, fixed-bed coal-gasification pilot plant  

SciTech Connect (OSTI)

This study is part of an effort to assess the efficiency of activated-sludge treatment for removal of organic constituents from high-Btu coal-gasification pilot-plant quench waters. A sample of raw-gas quench water was obtained from the Grand Forks Energy and Technology Center's pilot plant, which employs the slagging, fixed-bed gasification process. The quench water generated in the processing of Indian Head lignite was pretreated to reduce ammonia and alkalinity, and then diluted and subjected to long-term biological treatment, followed by detailed characterization and analysis of organic constituents. The pretreated (influent) and treated (effluent) samples were extracted using a methylene chloride, pH-fractionation method to obtain acid, base, and neutral fractions, which were analyzed by capillary-column gas chromatography/mass spectrometry (GC/MS). Over 99% of the total extractable and chromatographable organic material in the influent acid fraction was composed of phenol and alkylated phenols. Biological treatment removed these compounds almost completely. Major components of the influent base fraction were alkylated pyridines, anilines, aminopyrroles, imidazoles and/or pyrazoles, diazines, and quinolines. Removal efficiency of these compounds ranged between 90 and 100%. The influent neutral fraction was composed mainly of cycloalkanes, cycloalkenes, naphthalene, indole, acetophenone, and benzonitrile. Alkylated benzenes were generally absent. Removal efficiencies of these compounds were generally very good, except for certain alkylated cycloalkanes and cycloalkenes. Results are compared with those of a similar study on HYGAS coal-gasification quench water.

Stamoudis, V C; Luthy, R G

1980-02-01T23:59:59.000Z

270

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

SciTech Connect (OSTI)

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

Elliott, Jeannine

2013-08-31T23:59:59.000Z

271

Influence by small dispersive coal dust particles of different fractional consistence on characteristics of iodine air filter at nuclear power plant  

E-Print Network [OSTI]

The main purpose of research is to determine the influence by the small dispersive coal dust particles of the different fractional consistence on the technical characteristics of the vertical iodine air filter at nuclear power plant. The research on the transport properties of the small dispersive coal dust particles in the granular filtering medium of absorber in the vertical iodine air filter is completed in the case, when the modeled aerodynamic conditions are similar to the real aerodynamic conditions. It is shown that the appearance of the different fractional consistence of small dispersive coal dust particles with the decreasing dimensions down to the micro and nano sizes at the action of the air dust aerosol stream normally results in a significant change of distribution of the small dispersive coal dust particles masses in the granular filtering medium of an absorber in the vertical iodine air filter, changing the vertical iodine air filter aerodynamic characteristics. The precise characterization of...

Neklyudov, I M; Fedorova, L I; Poltinin, P Ya

2013-01-01T23:59:59.000Z

272

China's Coal: Demand, Constraints, and Externalities  

E-Print Network [OSTI]

coal electricity generation efficiency also varies by plantplants. The unit water requirement of coal-fired electricity generationelectricity generation is comparatively low in China due to the prevalence of small, outdated coal-fired power plants.

Aden, Nathaniel

2010-01-01T23:59:59.000Z

273

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

SciTech Connect (OSTI)

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.

Li, S.Y.; Liu, H.B.; Cai, W.J.; Soh, Y.C.; Xie, L.H. [Shanghai Jiao Tong University, Shanghai (China)

2004-07-01T23:59:59.000Z

274

Physical features of small disperse coal dust fraction transportation and structurization processes in iodine air filters of absorption type in ventilation systems at nuclear power plants  

E-Print Network [OSTI]

The research on the physical features of transportation and structurization processes by the air-dust aerosol in the granular filtering medium with the cylindrical coal adsorbent granules in an air filter of the adsorption type in the heating ventilation and cooling (HVAC) system at the nuclear power plant is completed. The physical origins of the coal dust masses distribution along the absorber with the granular filtering medium with the cylindrical coal granules during the air-dust aerosol intake process in the near the surface layer of absorber are researched. The quantitative technical characteristics of air filtering elements, which have to be considered during the optimization of air filters designs for the application in the ventilation systems at the nuclear power plants, are obtained.

Ledenyov, Oleg P; Poltinin, P Ya; Fedorova, L I

2012-01-01T23:59:59.000Z

275

The Mesaba Energy Project: Clean Coal Power Initiative, Round 2  

SciTech Connect (OSTI)

The Mesaba Energy Project is a nominal 600 MW integrated gasification combine cycle power project located in Northeastern Minnesota. It was selected to receive financial assistance pursuant to code of federal regulations (?CFR?) 10 CFR 600 through a competitive solicitation under Round 2 of the Department of Energy?s Clean Coal Power Initiative, which had two stated goals: (1) to demonstrate advanced coal-based technologies that can be commercialized at electric utility scale, and (2) to accelerate the likelihood of deploying demonstrated technologies for widespread commercial use in the electric power sector. The Project was selected in 2004 to receive a total of $36 million. The DOE portion that was equally cost shared in Budget Period 1 amounted to about $22.5 million. Budget Period 1 activities focused on the Project Definition Phase and included: project development, preliminary engineering, environmental permitting, regulatory approvals and financing to reach financial close and start of construction. The Project is based on ConocoPhillips? E-Gas? Technology and is designed to be fuel flexible with the ability to process sub-bituminous coal, a blend of sub-bituminous coal and petroleum coke and Illinois # 6 bituminous coal. Major objectives include the establishment of a reference plant design for Integrated Gasification Combined Cycle (?IGCC?) technology featuring advanced full slurry quench, multiple train gasification, integration of the air separation unit, and the demonstration of 90% operational availability and improved thermal efficiency relative to previous demonstration projects. In addition, the Project would demonstrate substantial environmental benefits, as compared with conventional technology, through dramatically lower emissions of sulfur dioxide, nitrogen oxides, volatile organic compounds, carbon monoxide, particulate matter and mercury. Major milestones achieved in support of fulfilling the above goals include obtaining Site, High Voltage Transmission Line Route, and Natural Gas Pipeline Route Permits for a Large Electric Power Generating Plant to be located in Taconite, Minnesota. In addition, major pre-construction permit applications have been filed requesting authorization for the Project to i) appropriate water sufficient to accommodate its worst case needs, ii) operate a major stationary source in compliance with regulations established to protect public health and welfare, and iii) physically alter the geographical setting to accommodate its construction. As of the current date, the Water Appropriation Permits have been obtained.

Stone, Richard; Gray, Gordon; Evans, Robert

2014-07-31T23:59:59.000Z

276

2009 Coal Age Buyers Guide  

SciTech Connect (OSTI)

The buyers guide lists more than 1200 companies mainly based in the USA, that provide equipment and services to US coal mines and coal preparation plants. The guide is subdivided by product categories.

NONE

2009-07-15T23:59:59.000Z

277

Tri-State Synfuels Project Review: Volume 12. Fluor project status. [Proposed Henderson, Kentucky coal to gasoline plant; engineering  

SciTech Connect (OSTI)

The purpose of this report is to document and summarize activities associated with Fluor's efforts on the Tri-State Synfuels Project. The proposed facility was to be coal-to-transport fuels facility located in Henderson, Kentucky. Tri-State Synfuels Company was participating in the project as a partner of the US Department of Energy per terms of a Cooperative Agreement resulting from DOE's synfuel's program solicitation. Fluor's initial work plan called for preliminary engineering and procurement services to the point of commitment for construction for a Sasol Fischer-Tropsch plant. Work proceeded as planned until October 1981 when results of alternative coal-to-methanol studies revealed the economic disadvantage of the Synthol design for US markets. A number of alternative process studies followed to determine the best process configuration. In January 1982 Tri-State officially announced a change from Synthol to a Methanol to Gasoline (MTG) design basis. Further evaluation and cost estimates for the MTG facility eventually led to the conclusion that, given the depressed economic outlook for alternative fuels development, the project should be terminated. Official announcement of cancellation was made on April 13, 1982. At the time of project cancellation, Fluor had completed significant portions of the preliminary engineering effort. Included in this report are descriptions and summaries of Fluor's work during this project. In addition location of key project data and materials is identified and status reports for each operation are presented.

Not Available

1982-06-01T23:59:59.000Z

278

Study of the treatability of wastewater from a coal-gasification plant. Final report, July 15, 1978-July 14, 1980  

SciTech Connect (OSTI)

This study focused on the coal gasification facility serving the Holston Army Ammunition Plant in Kingsport, Tennessee. Objectives were to characterize the wastewater produced by the gasification facility, and to evaluate technology for treating the waste in preparation for dischage to the environment. Most wastewater was recycled for scrubbing and cooling the product gas, with the excess requiring disposal found to be an average of only 1170 gallons per day (53 gallons per ton of coal, as received, and 366 gallons per million cubic feet of product gas). Analysis indicated that the waste was warm, high in alkaline material, especially ammonia, high in organic material, especially phenols, and also contaminated with other substances. Sulfides and thiocyanates were especially high in concentration. It was found that pretreatment could be accomplished by stripping (air injection) at high pH, removal of grease and oil (by pH suppression and light aeration) and neutralizatin. Equations were developed to describe the first two steps. Biological treatment through activated sludge was found to be successful, but effected only a moderate degree of treatment, and was troubled with frequent process upset. Attempts to improve treatment efficiency and stability are described. The data indicated the need to study aerated waste stabilization ponds as an alternative to activated sludge. Biological reaction kinetics were studied for activated sludge. Evaluation of the application of granular activated carbon suggested that this could be an effective practical tertiary treatment.

Iglar, A. F.

1980-01-01T23:59:59.000Z

279

U.S. Energy Information Administration (EIA) - Topics  

Gasoline and Diesel Fuel Update (EIA)

CBTL plants, and integrated coal gasification and combined cycle (IGCC) plants without carbon capture and storage (CCS)-is increased by 3 percentage points to reflect the...

280

CERAMIC MEMBRANE ENABLING TECHNOLOGY FOR IMPROVED IGCC EFFICIENCY  

SciTech Connect (OSTI)

This quarterly technical progress report will summarize work accomplished for Phase 2 Program during the quarter January to March 2004. In task 1 OTM development has led to improved strength and composite design for lower temperatures. In task 2, the measurement system of OTM element dimensions was improved. In task 3, a 10-cycle test of a three-tube submodule was reproduced successfully. In task 5, sizing of several potential heat recovery systems was initiated. In task 7, advanced OTM and cryogenic IGCC cases for near-term integration were developed.

Ravi Prasad

2004-03-31T23:59:59.000Z

Note: This page contains sample records for the topic "igcc coal plants" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


281

Design of a laser-induced breakdown spectroscopy system for on-line quality analysis of pulverized coal in power plants  

SciTech Connect (OSTI)

It is vitally important for a power plant to determine the chemical composition of coal prior to combustion in order to obtain optimal boiler control. In this work, a fully software-controlled laser-induced breakdown spectroscopy (LIBS) system comprising a LIBS apparatus and sampling equipment has been designed for possible application to power plants for on-line quality analysis of pulverized coal. Special attention was given to the LIBS system, the data processing methods (especially the normalization with Bode Rule/DC Level) and the specific settings (the software-controlled triggering source, high-pressure gas cleaning device, sample preparation module, sampling module, etc.), which gave the best direct measurement for C, H, Si, Na, Mg, Fe, Al, and Ti with measurement errors less than 10% for pulverized coal. Therefore, the apparatus is accurate enough to be applied to industries for on-line monitoring of pulverized coal. The method of proximate analysis was also introduced and the experimental error of A(ad) (Ash, 'ad' is an abbreviation for 'air dried') was shown in the range of 2.29 to 13.47%. The programmable logic controller (PLC) controlled on-line coal sampling equipment, which is designed based upon aerodynamics, and is capable of performing multipoint sampling and sample-preparation operation.

Yin, W.B.; Zhang, L.; Dong, L.; Ma, W.G.; Jia, S.T. [Shanxi Agricultural University, Taiyuan (China)

2009-08-15T23:59:59.000Z

282

Improved Performance of an Air Cooled Condenser (ACC) Using SPX Wind Guide Technology at Coal-Based Thermoelectric Power Plants  

SciTech Connect (OSTI)

This project added a new airflow enhancement technology to an existing ACC cooling process at a selected coal power plant. Airflow parameters and efficiency improvement for the main plant cooling process using the applied technology were determined and compared with the capabilities of existing systems. The project required significant planning and pre-test execution in order to reach the required Air Cooled Condenser system configuration for evaluation. A host Power Plant ACC system had to be identified, agreement finalized, and addition of the SPX ACC Wind Guide Technology completed on that site. Design of the modification, along with procurement, fabrication, instrumentation, and installation of the new airflow enhancement technology were executed. Baseline and post-modification cooling system data was collected and evaluated. The improvement of ACC thermal performance after SPX wind guide installation was clear. Testing of the improvement indicates there is a 5% improvement in heat transfer coefficient in high wind conditions and 1% improvement at low wind speed. The benefit increased with increasing wind speed. This project was completed on schedule and within budget.

Ken Mortensen

2010-12-31T23:59:59.000Z

283

Composition and chemistry of particulates from the Tidd Clean Coal Demonstration Plant pressurized fluidized bed combustor, cyclone, and filter vessel  

SciTech Connect (OSTI)

In a Pressurized Fluidized Bed Combustion (PFBC)/cyclone/filter system ground coal and sorbent are injected as pastes into the PFBC bed; the hot gases and entrained fine particles of ash and calcined or reacted sorbent are passed through a cyclone (which removes the larger entrained particles); and the very-fine particles that remain are then filtered out, so that the cleaned hot gas can be sent through a non-ruggedized hot-gas turbine. The 70 MWe Tidd PFBC Demonstration Plant in Brilliant, Ohio was completed in late 1990. The initial design utilized seven strings of primary and secondary cyclones to remove 98% of the particulate matter. However, the Plant also included a pressurized filter vessel, placed between the primary and secondary cyclones of one of the seven strings. Coal and dolomitic limestone (i.e, SO{sub 2} sorbent) of various nominal sizes ranging from 12 to 18 mesh were injected into the combustor operating at about 10 atm pressure and 925{degree}C. The cyclone removed elutriated particles larger than about 0.025 mm, and particles larger than ca. 0.0005 mm were filtered at about 750{degree}C by ceramic candle filters. Thus, the chemical reaction times and temperatures, masses of material, particle-size distributions, and chemical compositions were substantially different for particulates removed from the bed drain, the cyclone drain, and the filter unit. Accordingly, we have measured the particle-size distributions and concentrations of calcium, magnesium, sulfur, silicon, and aluminum for material taken from the three units, and also determined the chemical formulas and predominant crystalline forms of the calcium and magnesium sulfate compounds formed. The latter information is particularly novel for the filter-cake material, from which we isolated the ``new`` compound Mg{sub 2}Ca(SO{sub 4}){sub 3}.

Smith, D.H.; Grimm, U.; Haddad, G.

1995-12-31T23:59:59.000Z

284

Table 11a. Coal Prices to Electric Generating Plants, Projected vs. Actual  

Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE:1 First Use of Energy for All Purposes (Fuel and Nonfuel),Feet) Year Jan Feb Mar Apr MayAtmosphericNuclear Security AdministrationcontrollerNanocrystallineForeign ObjectOUR Table 1. Summary statistics for0 Tablea. Coal

285

Table 11b. Coal Prices to Electric Generating Plants, Projected vs. Actual  

U.S. Energy Information Administration (EIA) Indexed Site

AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative Fuels Data Center Home Page on Google Bookmark EERE: Alternative Fuels Data CenterFranconia, Virginia:FAQ <Information Administration (EIA) 10 MECS Survey Data9c : U.S.Welcome to the1,033 15:b. Coal Prices to

286

CERAMIC MEMBRANE ENABLING TECHNOLOGY FOR IMPROVED IGCC EFFICIENCY  

SciTech Connect (OSTI)

This quarterly technical progress report will summarize work accomplished for Phase 2 Program during the quarter July to September 2003. In task 1 OTM development has led to improved strength and composite design. In task 2, the manufacture of robust PSO1d elements has been scaled up. In task 3, operational improvements in the lab-scale pilot reactor have reduced turn-around time and increased product purity. In task 7, economic models show substantial benefit of OTM IGCC over CRYO based oxygen production. The objectives of the first year of phase 2 of the program are to construct and operate an engineering pilot reactor for OTM oxygen. Work to support this objective is being undertaken in the following areas in this quarter: Element reliability; Element fabrication; Systems technology; Power recovery; and IGCC process analysis and economics. The major accomplishments this quarter were Element production at Praxair's manufacturing facility is being scaled up and Substantial improvements to the OTM high temperature strength have been made.

Ravi Prasad

2003-11-01T23:59:59.000Z

287

The development of Clean Coal Technology in China  

SciTech Connect (OSTI)

The resource conditions and energy structures of China determine that coal will continue to play a key role in the development of the electrical power industry in the coming years, thus it is necessary to develop clean coal technology in order to control the high consumption rate of energy and to control serious pollution. Clean coal technology focuses on improving the utilization rate of energy and on the control and reduction of emissions. Considering the condition of China, PC-FGD, supercritical units, CFBC, IGCC and PFBC-CC can be applied and developed under different conditions and in different periods with these technologies developing simultaneously and helping each other forward to improve clean coal technologies. China has broad development prospects and a large market for clean coal technologies. The authors hope to strengthen international exchange and cooperation in this field for the development of CCTs markets in China.

Jie, Z.; Chu, Z.X. [North China Electrical Power Design Inst., Beijing (China)

1996-10-01T23:59:59.000Z

288

Polygeneration Integration of Gasoline Synthesis and IGCC Power Production Using  

E-Print Network [OSTI]

that in coal-rich countries like the US and China, the interest in gasification is very high and a number for a gas turbine in a combined cycle power generation scheme. Coal Residue Gasification Gas Cleaning/S, Nymøllevej 55, 2800 Kongens Lyngby, Denmark Abstract Coal is becoming an increasingly important raw material

289

Coal: the new black  

SciTech Connect (OSTI)

Long eclipsed by oil and natural gas as a raw material for high-volume chemicals, coal is making a comeback, with oil priced at more than $100 per barrel. It is relatively cheap feedstock for chemicals such as methanol and China is building plants to convert coal to polyolefins on a large scale and interest is spreading worldwide. Over the years several companies in the US and China have made fertilizers via the gasification of coal. Eastman in Tennessee gasifies coal to make methanol which is then converted to acetic acid, acetic anhydride and acetate fiber. The future vision is to convert methanol to olefins. UOP and Lurgi are the major vendors of this technology. These companies are the respective chemical engineering arms of Honeywell and Air Liquide. The article reports developments in China, USA and India on coal-to-chemicals via coal gasification or coal liquefaction. 2 figs., 2 photo.

Tullo, A.H.; Tremblay, J.-F.

2008-03-15T23:59:59.000Z

290

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

SciTech Connect (OSTI)

This report describes the technical progress made on the Pittsburgh Air Quality Study (PAQS) during the period of September 2004 through February 2005. Significant progress was made this project period on the analysis of ambient data, source apportionment, and deterministic modeling activities. The major experimental achievement this project period was the characterization of the mercury and fine particle emissions from two modern, large, commercial pulverized coal boilers. This testing completes the field work component of the Source Characterization Activity. This report highlights results from mercury emission measurements made using a dilution sampler. The measurements clearly indicate that mercury is being transformed from an oxidized to an elemental state within the dilution. However, wall effects are significant making it difficult to determine whether or not these changes occur in the gas phase or due to some interaction with the sampler walls. This report also presents results from an analysis that uses spherical aluminum silicate (SAS) particles as a marker for primary PM{sub 2.5} emitted from coal combustion. Primary emissions from coal combustion contribute only a small fraction of the PM{sub 2.5} mass (less than 1.5% in the summer and less than 3% in the winter) at the Pittsburgh site. Ambient SAS concentrations also appear to be reasonably spatially homogeneous. Finally, SAS emission factors measured at pilot-scale are consistent with measurements made at full-scale. This report also presents results from applying the Unmix and PMF models to estimate the contribution of different sources to the PM{sub 2.5} mass concentrations in Pittsburgh using aerosol composition information. Comparison of the two models shows similar source composition and contribution for five factors: crustal material, nitrate, an Fe, Mn, and Zn factor, specialty steel production, and a cadmium factor. PMF found several additional factors. Comparison between source contributions for the similar factors shows reasonable agreement between the two models. The sulfate factor shows the highest contribution to local PM{sub 2.5} with an annual average contribution of approximately 28% (from PMF). The nitrate, crustal material, and primary OC and EC factors also show significant contributions on the order of 10-14%. The sulfate factor is affected by photochemistry and therefore shows maximum values in summer.

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

2005-04-01T23:59:59.000Z

291

Physical features of accumulation and distribution processes of small disperse coal dust precipitations and absorbed radioactive chemical elements in iodine air filter at nuclear power plant  

E-Print Network [OSTI]

The physical features of absorption process of radioactive chemical elements and their isotopes in the iodine air filters of the type of AU-1500 at the nuclear power plants are researched. It is shown that the non-homogenous spatial distribution of absorbed radioactive chemical elements and their isotopes in the iodine air filter, probed by the gamma-activation analysis method, is well correlated with the spatial distribution of small disperse coal dust precipitations in the iodine air filter. This circumstance points out to an important role by the small disperse coal dust fractions of absorber in the absorption process of radioactive chemical elements and their isotopes in the iodine air filter. The physical origins of characteristic interaction between the radioactive chemical elements and the accumulated small disperse coal dust precipitations in an iodine air filter are considered. The analysis of influence by the researched physical processes on the technical characteristics and functionality of iodine ...

Ledenyov, Oleg P; Poltinin, P Ya; Fedorova, L I

2012-01-01T23:59:59.000Z

292

Comprehensive assessment of toxic emissions from coal-fired power plants  

SciTech Connect (OSTI)

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.

NONE

1996-09-01T23:59:59.000Z

293

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

SciTech Connect (OSTI)

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

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

2004-04-01T23:59:59.000Z

294

Engineering support services for the DOE/GRI coal gasification research program. Safety audits of pilot plants and PDU's  

SciTech Connect (OSTI)

M.W. Kellogg (formerly Pullmann Kellogg) was requested by DOE to investigate and to evaluate normal and emergency operating procedures and the drawing record systems of the coal gasification pilot plants and process development units (PDU). The purpose of this Safety Audit was to identify deficiencies in operating policies or procedures which could lead to potential hazards. The evaluation of safety-related documentation at the pilot plants and PDU's was also included in the audit. The safety audit visits and meetings were conducted at the following research sites: Bell Aerosopace, BCR BI-GAS, Exxon, IGT Hygas/Peatgas, Rockwell International, and Westinghouse. Kellogg conducted the safety audits requested by DOE. These reviews show the developers as possessing very sincere, positive attitudes toward safety and as being committed to ongoing safety programs. Kellogg found that (in general) all of the developers: use written statements of objectives, operating procedures and check lists; have some form of formal safety training for operators; review equipment and procedural revisions with operators; and maintain timely and accurate drawing records.

Bostwick, L.E.; Hubbard, D.A.; Lee, M.D.; Miller, G.R.; Bernard, D.M.

1981-04-01T23:59:59.000Z

295

Modeling Creep-Fatigue-Environment Interactions in Steam Turbine Rotor Materials for Advanced Ultra-supercritical Coal Power Plants  

SciTech Connect (OSTI)

The goal of this project is to model creep-fatigue-environment interactions in steam turbine rotor materials for advanced ultra-supercritical (A-USC) coal power Alloy 282 plants, to develop and demonstrate computational algorithms for alloy property predictions, and to determine and model key mechanisms that contribute to the damages caused by creep-fatigue-environment interactions. The nickel based Alloy 282 is selected for this project because it is one of the leading candidate materials for the high temperature/pressure section of an A-USC steam turbine. The methods developed in the project are expected to be applicable to other metal alloys in similar steam/oxidation environments. The major developments are: ? failure mechanism and microstructural characterization ? atomistic and first principles modeling of crack tip oxygen embrittlement ? modeling of gamma prime microstructures and mesoscale microstructure-defect interactions ? microstructure and damage-based creep prediction ? multi-scale crack growth modeling considering oxidation, viscoplasticity and fatigue The technology developed in this project is expected to enable more accurate prediction of long service life of advanced alloys for A-USC power plants, and provide faster and more effective materials design, development, and implementation than current state-of-the-art computational and experimental methods. This document is a final technical report for the project, covering efforts conducted from January 2011 to January 2014.

Shen, Chen

2014-01-20T23:59:59.000Z

296

Oxidation of byproduct calcium sulfite hemihydrate from coal-fired power plant  

E-Print Network [OSTI]

The flue gas desulfurization by-product from the TU Electric Martin Lake power plant near Tatum, Texas was characterized using thermal analysis, x-ray diffraction, microprobe and infrared spectroscopy. The byproduct, called gypsite, consisted of a...

Bhatt, Sandeep

1995-01-01T23:59:59.000Z

297

Commercial Scale Coal to F-T Liquid Plant Using a Dry Feed Gasifier  

Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

design incorporated low-cost efforts to reduce water usage. The CTL plant design that was evaluated utilizes an iron-based catalyst and a low-temperature F- T reactor. The concept...

298

Financing Capture Ready Coal-Fired Power Plants in China by Issuing Capture Options  

E-Print Network [OSTI]

Combined Cycle) IPCC (Intergovernmental Panel on Climate Change) LHV (Low Heating Value) Local EPA (Local Environment Protection Administration in China) MLR (Ministry of Land and Resource in China) MOF (Ministry of Finance in China) 2 NPV (Net... Fired Power Plant) SEPA (State Environment Protection Administration in China) SERC (State Electricity Regulatory Commission in China) Solar PV Power (Solar Photovoltaic Power) Std Dev (Standard Deviation) USC-PC Power Plant (Ultra Supercritical...

Liang, Xi; Reiner, David; Gibbons, Jon; Li, Jia

299

ENGINEERING FEASIBILITY AND ECONOMICS OF CO2 SEQUESTRATION/USE ON AN EXISTING COAL-FIRED POWER PLANT: A LITERATURE REVIEW  

SciTech Connect (OSTI)

The overall objective of this study is to evaluate the technical feasibility and the economics of alternate CO{sub 2} capture and sequestration/use technologies for retrofitting an existing pulverized coal-fired power plant. To accomplish this objective three alternative CO{sub 2} capture and sequestration systems will be evaluated to identify their impact on an existing boiler, associated boiler auxiliary components, overall plant operation and performance and power plant cost, including the cost of electricity. The three retrofit technologies that will be evaluated are as follows: (1) Coal combustion in air, followed by CO{sub 2} separation from flue gas with Kerr-McGee/ABB Lummus Global's commercial MEA-based absorption/stripping process. (2) Coal combustion in an O{sub 2}/CO{sub 2} environment with CO{sub 2} recycle. (3) Coal combustion in air with oxygen removal and CO{sub 2} captured by tertiary amines In support of this objective and execution of the evaluation of the three retrofit technologies a literature survey was conducted. It is presented in an ''annotated'' form, consistent with the following five sections: (1) Coal Combustion in O{sub 2}/CO{sub 2} Media; (2) Oxygen Separation Technologies; (3) Post Combustion CO{sub 2} Separation Technologies; (4) Potential Utilization of CO{sub 2}; and (5) CO{sub 2} Sequestration. The objective of the literature search was to determine if the three retrofit technologies proposed for this project continue to be sound choices. Additionally, a review of the literature would afford the opportunity to determine if other researchers have made significant progress in developing similar process technologies and, in that context, to revisit the current state-of-the-art. Results from this literature survey are summarized in the report.

Carl R. Bozzuto; Nsakala ya Nsakala

2000-01-31T23:59:59.000Z

300

Simulated coal-gas fueled carbonate fuel cell power plant system verification. Final report, September 1990--June 1995  

SciTech Connect (OSTI)

This report summarizes work performed under U.S. Department of Energy, Morgantown Energy Technology Center (DOE/METC) Contract DE-AC-90MC27168 for September 1990 through March 1995. Energy Research Corporation (ERC), with support from DOE, EPRI, and utilities, has been developing a carbonate fuel cell technology. ERC`s design is a unique direct fuel cell (DFC) which does not need an external fuel reformer. An alliance was formed with a representative group of utilities and, with their input, a commercial entry product was chosen. The first 2 MW demonstration unit was planned and construction begun at Santa Clara, CA. A conceptual design of a 10OMW-Class dual fuel power plant was developed; economics of natural gas versus coal gas use were analyzed. A facility was set up to manufacture 2 MW/yr of carbonate fuel cell stacks. A 100kW-Class subscale power plant was built and several stacks were tested. This power plant has achieved an efficiency of {approximately}50% (LHV) from pipeline natural gas to direct current electricity conversion. Over 6,000 hours of operation including 5,000 cumulative hours of stack operation were demonstrated. One stack was operated on natural gas at 130 kW, which is the highest carbonate fuel cell power produced to date, at 74% fuel utilization, with excellent performance distribution across the stack. In parallel, carbonate fuel cell performance has been improved, component materials have been proven stable with lifetimes projected to 40,000 hours. Matrix strength, electrolyte distribution, and cell decay rate have been improved. Major progress has been achieved in lowering stack cost.

NONE

1995-03-01T23:59:59.000Z

Note: This page contains sample records for the topic "igcc coal plants" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


301

ENERGY UTILIZATION AND ENVIRONMENTAL CONTROL TECHNOLOGIES IN THE COAL-ELECTRIC CYCLE  

E-Print Network [OSTI]

Pollutants in Coal- Fired Power Plants Emission Factors forPollutants in Coal-Fired Power Plants(a) Emissions Fly-ash(for a summary. "Emissions from Coal-Fired Power Plants: a

Ferrell, G.C.

2010-01-01T23:59:59.000Z

302

Advanced Multi-Product Coal Utilization By-Product Processing Plant  

SciTech Connect (OSTI)

The objective of the project is to build a multi-product ash beneficiation plant at Kentucky Utilities 2,200-MW Ghent Generating Station, located in Carroll County, Kentucky. This part of the study includes an investigation of the secondary classification characteristics of the ash feedstock excavated from the lower ash pond at Ghent Station.

John Groppo; Thomas Robl

2006-09-30T23:59:59.000Z

303

CERAMIC MEMBRANE ENABLING TECHNOLOGY FOR IMPROVED IGCC EFFICIENCY  

SciTech Connect (OSTI)

This quarterly technical progress report will summarize work accomplished for Phase 1 Program during the quarter January to March 2002. In task 1 improvements to the membrane material have shown increased flux, and high temperature mechanical properties are being measured. In task 2, composite development has shown that alternative fabrication routes of the substrate can improve membrane performance under certain conditions. In task 3, scale-up issues associated with manufacturing large tubes have been identified and are being addressed. The work in task 4 has demonstrated that composite OTM elements can produce oxygen at greater than 95% purity for more than 1000 hours of the target flux under simulated IGCC operating conditions. In task 5 the multi-tube OTM reactor has been operated and produced oxygen.

Ravi Prasad

2002-05-01T23:59:59.000Z

304

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

SciTech Connect (OSTI)

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

Not Available

1994-06-16T23:59:59.000Z

305

Quality Guidelines for Energy System Studies: Detailed Coal Specificat...  

Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

Coal: Assessing the Techno- Economic Impact of Emerging Technologies Life Cycle Analysis: Existing Pulverized Coal Power Plant Life Cycle Analysis: Integrated Gasification...

306

ccpi-multi-product-coal | netl.doe.gov  

Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

1 Industrial Carbon Capture and Storage Clean Coal Power Initiative Power Plant Improvement Initiative Clean Coal Technology Demonstration Program FutureGen Advanced Multi-Product...

307

JV Task-123 Determination of Trace Element Concentrations at an Eastern Bituminous Coal Plant Employing an SCR and Wet FGD  

SciTech Connect (OSTI)

The Energy & Environmental Research Center (EERC), in partnership with Babcock & Wilcox (B&W) and with funding from U.S. Department of Energy (DOE), conducting tests to prove that a high level of mercury control (>90%) can be achieved at a power plant burning a high-sulfur eastern bituminous coal. With funding from the Electric Power Research Institute (EPRI), DOE, and Center for Air Toxic Metals{reg_sign} (CATM{reg_sign}) Affiliates Program, the EERC completed an additional sampling project to provide data as to the behavior of a number of trace elements across the various pollution control devices, with a special emphasis on the wet flue gas desulfurization (FGD) system. Results showed that the concentrations of almost all the elements of interest leaving the stack were very low, and a high percentage of the trace elements were captured in the electrostatic precipitator (ESP) (for most, >80%). Although, with a few exceptions, the overall mass balances were generally quite good, the mass balances across the wet FGD were more variable. This is most likely a result of some of the concentrations being very low and also the uncertainties in determining flows within a wet FGD.

Dennis Laudal

2008-05-01T23:59:59.000Z

308

Carbon Dioxide Capture from Coal-Fired  

E-Print Network [OSTI]

. LFEE 2005-002 Report #12;#12;i ABSTRACT Investments in three coal-fired power generation technologiesCarbon Dioxide Capture from Coal-Fired Power Plants: A Real Options Analysis May 2005 MIT LFEE 2005 environment. The technologies evaluated are pulverized coal (PC), integrated coal gasification combined cycle

309

A new coordinated control strategy for boiler-turbine system of coal-fired power plant  

SciTech Connect (OSTI)

This paper presents the new development of the boiler-turbine coordinated control strategy using fuzzy reasoning and autotuning techniques. The boiler-turbine system is a very complex process that is a multivariable, nonlinear, slowly time-varying plant with large settling time and a lot of uncertainties. 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. Proportional-integral derivative (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. A special subclass of fuzzy inference systems, called the Gaussian partition with evenly (GPE) spaced midpoints systems, is used to self-tune the main steam pressure PID controller's parameters online based on the error signal and its first difference, aimed at overcoming the uncertainties due to changing fuel calorific value, machine wear, contamination of the boiler heating surfaces and plant modeling errors. For the large variation of operating condition, a supervisory control level has been developed by autotuning technique. 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. Indeed, better control performance and economic benefit have been achieved.

Li, S.Y.; Liu, H.B.; Cai, W.J.; Soh, Y.C.; Xie, L.H. [Shanghai Jiao Tong University, Shanghai (China)

2005-11-01T23:59:59.000Z

310

Commercial Scale Coal to F-T Liquid Plant Using a Dry Feed Gasifier  

Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE:1 First Use of Energy for All Purposes (Fuel and Nonfuel),Feet) Year Jan Feb Mar Apr MayAtmospheric Optical Depth7-1D: Vegetation Proposed New SubstationClean CommunitiesEFRCInformationBaseline for Fossil Energy Plants

311

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

SciTech Connect (OSTI)

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

Not Available

1994-07-01T23:59:59.000Z

312

Influence by small dispersive coal dust particles of different fractional consistence on characteristics of iodine air filter at nuclear power plant  

E-Print Network [OSTI]

The main purpose of research is to determine the influence by the small dispersive coal dust particles of the different fractional consistence on the technical characteristics of the vertical iodine air filter at nuclear power plant. The research on the transport properties of the small dispersive coal dust particles in the granular filtering medium of absorber in the vertical iodine air filter is completed in the case, when the modeled aerodynamic conditions are similar to the real aerodynamic conditions. It is shown that the appearance of the different fractional consistence of small dispersive coal dust particles with the decreasing dimensions down to the micro and nano sizes at the action of the air dust aerosol stream normally results in a significant change of distribution of the small dispersive coal dust particles masses in the granular filtering medium of an absorber in the vertical iodine air filter, changing the vertical iodine air filter aerodynamic characteristics. The precise characterization of the aerodynamic resistance of a model of the vertical iodine air filter is completed. The comparative analysis of the technical characteristics of the vertical and horizontal iodine air filters is also made.

I. M. Neklyudov; O. P. Ledenyov; L. I. Fedorova; P. Ya. Poltinin

2013-02-18T23:59:59.000Z

313

Advanced Multi-Product Coal Utilization By-Product Processing Plant  

SciTech Connect (OSTI)

The objective of the project is to build a multi-product ash beneficiation plant at Kentucky Utilities 2,200-MW Ghent Generating Station, located in Carroll County, Kentucky. This part of the study includes an investigation of the secondary classification characteristics of the ash feedstock excavated from the lower ash pond at Ghent Station. The market study for the products of the processing plant (Subtask 1.6), conducted by Cemex, is reported herein. The study incorporated simplifying assumptions and focused only on pozzolan and ultra fine fly ash (UFFA). It found that the market for pozzolan in the Ghent area was oversupplied, with resultant poor pricing structure. Reachable export markets for the Ghent pozzolan market were mostly locally served with the exception of Florida. It was concluded that a beneficiated material for that market may be at a long term disadvantage. The market for the UFFA was more complex as this material would compete with other beneficiated ash and potential metakaolin and silica fume as well. The study concluded that this market represented about 100,000 tons of sales per year and, although lucrative, represented a widely dispersed niche market.

Andrew Jackura; John Groppo; Thomas Robl

2006-12-31T23:59:59.000Z

314

Advanced Coal Wind Hybrid: Economic Analysis  

E-Print Network [OSTI]

advanced coal-wind hybrid combined cycle power plant naturalwhen the wind generation drops, the power plant needs toa CSP plant, a wind plant produces power during all hours of

Phadke, Amol

2008-01-01T23:59:59.000Z

315

Study of factors affecting syngas quality and their interactions in fluidized bed gasification of lignite coal  

E-Print Network [OSTI]

gas emissions from coal-fired power plants has led to renewed interest in gasification as a clean-coal with the Canada's Clean Coal Technology Roadmap [2] and CO2 Capture and Storage Technology Roadmap [3], clean coal

Spiteri, Raymond J.

316

advanced coal conversion: Topics by E-print Network  

Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

the coal plant is transmitted over the transmission lines, Phadke, Amol 2008-01-01 7 Clean Coal Technology Program Advanced Coal Conversion Process Demonstration CiteSeer Summary:...

317

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

SciTech Connect (OSTI)

Section 316(b) of the Clean Water Act requires that cooling water intake structures must reflect the best technology available for minimizing adverse environmental impact. Many existing power plants in the United States utilize once-through cooling systems to condense steam. Once-through systems withdraw large volumes (often hundreds of millions of gallons per day) of water from surface water bodies. As the water is withdrawn, fish and other aquatic organisms can be trapped against the screens or other parts of the intake structure (impingement) or if small enough, can pass through the intake structure and be transported through the cooling system to the condenser (entrainment). Both of these processes can injure or kill the organisms. EPA adopted 316(b) regulations for new facilities (Phase I) on December 18, 2001. Under the final rule, most new facilities could be expected to install recirculating cooling systems, primarily wet cooling towers. The EPA Administrator signed proposed 316(b) regulations for existing facilities (Phase II) on February 28, 2002. The lead option in this proposal would allow most existing facilities to achieve compliance without requiring them to convert once-through cooling systems to recirculating systems. However, one of the alternate options being proposed would require recirculating cooling in selected plants. EPA is considering various options to determine best technology available. Among the options under consideration are wet-cooling towers and dry-cooling towers. Both types of towers are considered to be part of recirculating cooling systems, in which the cooling water is continuously recycled from the condenser, where it absorbs heat by cooling and condensing steam, to the tower, where it rejects heat to the atmosphere before returning to the condenser. Some water is lost to evaporation (wet tower only) and other water is removed from the recirculating system as a blow down stream to control the building up of suspended and dissolved solids. Makeup water is withdrawn, usually from surface water bodies, to replace the lost water. The volume of makeup water is many times smaller than the volume needed to operate a once-through system. Although neither the final new facility rule nor the proposed existing facility rule require dry cooling towers as the national best technology available, the environmental community and several States have supported the use of dry-cooling technology as the appropriate technology for addressing adverse environmental impacts. It is possible that the requirements included in the new facility rule and the ongoing push for dry cooling systems by some stakeholders may have a role in shaping the rule for existing facilities. The temperature of the cooling water entering the condenser affects the performance of the turbine--the cooler the temperature, the better the performance. This is because the cooling water temperature affects the level of vacuum at the discharge of the steam turbine. As cooling water temperatures decrease, a higher vacuum can be produced and additional energy can be extracted. On an annual average, once-through cooling water has a lower temperature than recirculated water from a cooling tower. By switching a once-through cooling system to a cooling tower, less energy can be generated by the power plant from the same amount of fuel. This reduction in energy output is known as the energy penalty. If a switch away from once-through cooling is broadly implemented through a final 316(b) rule or other regulatory initiatives, the energy penalty could result in adverse effects on energy supplies. Therefore, in accordance with the recommendations of the Report of the National Energy Policy Development Group (better known as the May 2001 National Energy Policy), the U.S. Department of Energy (DOE), through its Office of Fossil Energy, National Energy Technology Laboratory (NETL), and Argonne National Laboratory (ANL), has studied the energy penalty resulting from converting plants with once-through cooling to wet towers or indirect-dry towers. Five l

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

2006-11-27T23:59:59.000Z

318

Advanced Multi-Product Coal Utilization By-Product Processing Plant  

SciTech Connect (OSTI)

The objective of the project is to build a multi-product ash beneficiation plant at Kentucky Utilities 2,200-MW Ghent Generating Station, located in Carroll County, Kentucky. Phase 1 was completed successfully, but the project did not continue on to Phase 2 due to withdrawal of CEMEX from the project. Attempts at replacing CEMEX were not successful. Problematic to the continuation of the project was its location in the Ohio Valley which is oversupplied and has low prices for fly ash and the change in CEMEX priorities due to merger and acquisitions. Thus, CAER concurred with the DOE to conclude the project at the end of Budget Period 1, March 31, 2007.

Thomas Robl; John Groppo

2007-03-31T23:59:59.000Z

319

Reaching an agreement to build a new coal-fired power plant near a national park by mitigating potential environmental impacts  

SciTech Connect (OSTI)

This paper presents an interesting example of compromise through comprehensive environmental analysis and intensive negotiation to build a coal-fired power plant near an environmentally sensitive area. In December 1993, the US Department of Energy (DOE) completed the final environmental impact statement (EIS) for the Healy Clean Coal Project (HCCP), a proposed demonstration project that would be cost-shared by DOE and the Alaska Industrial Development and Export Authority (AIDEA). The HCCP would be built adjacent to the existing coal-fired Golden Valley Electric Association, Inc. (GVEA) Unit No. 1 in Healy, Alaska, about 4 miles north of Denali National Park and Preserve (DNPP). In response to US Department of the Interior (DOI) concerns about potential air quality related impacts on DNPP, DOE facilitated negotiations among DOI, AIDEA, and GVEA which overcame a ``stalemate`` situation. A Memorandum of Agreement was signed by all four parties, enabling DOI to withdraw its objections. The cornerstone of the Agreement is the planned retrofit of Unit No. 1 to reduce emissions of sulfur dioxide and oxides of nitrogen. if the demonstration technologies operate as expected, combined emissions from the Healy site would increase by only about 8% but electrical generation would triple. The Agreement is a ``win/win`` outcome: DOE can demonstrate the new technologies, AIDEA can build a new power plant for GVEA to operate, and DOI can safeguard the pristine environment of DNPP.

Miller, R.L. [Oak Ridge National Lab., TN (United States); Ruppel, T.C.; Evans, E.W.; Heintz, S.J. [USDOE Pittsburgh Energy Technology Center, PA (United States)

1994-12-31T23:59:59.000Z

320

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

SciTech Connect (OSTI)

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

Not Available

1994-07-01T23:59:59.000Z

Note: This page contains sample records for the topic "igcc coal plants" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


321

Comparative analyses for selected clean coal technologies in the international marketplace  

SciTech Connect (OSTI)

Clean coal technologies (CCTs) are being demonstrated in research and development programs under public and private sponsorship. Many of these technologies could be marketed internationally. To explore the scope of these international opportunities and to match particular technologies with markets appearing to have high potential, a study was undertaken that focused on seven representative countries: Italy, Japan, Morocco, Turkey, Pakistan, the Peoples' Republic of China, and Poland. The results suggest that there are international markets for CCTs and that these technologies can be cost competitive with more conventional alternatives. The identified markets include construction of new plants and refurbishment of existing ones, especially when decision makers want to decrease dependence on imported oil. This report describes potential international market niches for U.S. CCTs and discusses the status and implications of ongoing CCT demonstration activities. Twelve technologies were selected as representative of technologies under development for use in new or refurbished industrial or electric utility applications. Included are the following: Two generic precombustion technologies: two-stage froth-flotation coal beneficiation and coal-water mixtures (CWMs); Four combustion technologies: slagging combustors, integrated-gasification combined-cycle (IGCC) systems, atmospheric fluidized-bed combustors (AFBCs), and pressurized fluidized-bed combustors (PFBCs); and Six postcombustion technologies: limestone-injection multistage burner (LIMB) systems, gas-reburning sorbent-injection (GRSI) systems, dual-alkali flue-gas desulfurization (FGD), spray-dryer FGD, the NOXSO process, and selective catalytic reduction (SCR) systems. Major chapters of this report have been processed separately for inclusion on the data base.

Szpunar, C.B.; Gillette, J.L.

1990-07-01T23:59:59.000Z

322

Kinetics of Direct Oxidation of H2S in Coal Gas to Elemental Sulfur  

SciTech Connect (OSTI)

Removal of hydrogen sulfide (H{sub 2}S) from coal gasifier gas and sulfur recovery are key steps in the development of Department of Energy's (DOE's) advanced Vision 21 plants that produce electric power and clean transportation fuels with coal and natural gas. These Vision 21 plants will require highly clean coal gas with H{sub 2}S below 1 ppm and negligible amounts of trace contaminants such as hydrogen chloride, ammonia, alkali, heavy metals, and particulate. The conventional method of sulfur removal and recovery employing amine, Claus, and tail-gas treatment is very expensive. A second generation approach developed under DOE's sponsorship employs hot-gas desulfurization (HGD) using regenerable metal oxide sorbents followed by Direct Sulfur Recovery Process (DSRP). However, this process sequence does not remove trace contaminants and is targeted primarily towards the development of advanced integrated gasification combined cycle (IGCC) plants that produce electricity (not both electricity and transportation fuels). There is an immediate as well as long-term need for the development of cleanup processes that produce highly clean coal gas for next generation Vision 21 plants. To this end, a novel process is now under development at several research organizations in which the H{sub 2}S in coal gas is directly oxidized to elemental sulfur over a selective catalyst. Such a process is ideally suited for coal gas from commercial gasifiers with a quench system to remove essentially all the trace contaminants except H{sub 2}S. The direct oxidation of H{sub 2}S to elemental sulfur in the presence of SO{sub 2} is ideally suited for coal gas from commercial gasifiers with a quench system to remove essentially all the trace contaminants except H{sub 2}S. This direct oxidation process has the potential to produce a super clean coal gas more economically than both conventional amine-based processes and HGD/DSRP. The objectives of this research are to measure kinetics of direct oxidation of H{sub 2}S to elemental sulfur in the presence of a simulated coal gas mixture containing SO{sub 2}, H{sub 2}, and moisture, using 160-{micro}m C-500-04 alumina catalyst particles and 400 square cells/inch{sup 2}, {gamma}-Al{sub 2}O{sub 3}-wash-coated monolithic catalyst, and various reactors such as a micro packed-bed reactor, a micro bubble reactor, and a monolithic catalyst reactor, and to develop kinetic rate equations and model the direct oxidation process to assist in the design of large-scale plants. This heterogeneous catalytic reaction has gaseous reactants such as H{sub 2}S and SO{sub 2}. However, this heterogeneous catalytic reaction has heterogeneous products such as liquid elemental sulfur and steam.

K.C. Kwon

2005-11-01T23:59:59.000Z

323

Clean coal technology applications  

SciTech Connect (OSTI)

{open_quotes}Coal is a stratified rock formed of the more or less altered remains of plants (together with associated mineral matter) which flourished in past ages{hor_ellipsis} The problem of the origin and maturing of coal is complicated by the fact that every coal contains, in addition to carbon, hydrogen and oxygen, variable proportions of nitrogen and sulfur which are combined in unknown ways in the organic molecules...{close_quotes}. The challenge with coal has always been the management of its mineral matter, sulfur and nitrogen contents during use. The carbon content of fuels, including coal, is a more recent concern. With clean coal technologies, there are opportunities for ensuring the sustained use of coal for a very long time. The clean coal technologies of today are already capable of reducing, if not eliminating, harmful emissions. The technologies of the future will allow coal to be burned with greatly reduced emissions, thus eliminating the necessity to treat them after they occur.

Bharucha, N.

1993-12-31T23:59:59.000Z

324

Low-rank coal research  

SciTech Connect (OSTI)

This work is a compilation of reports on ongoing research at the University of North Dakota. Topics include: Control Technology and Coal Preparation Research (SO{sub x}/NO{sub x} control, waste management), Advanced Research and Technology Development (turbine combustion phenomena, combustion inorganic transformation, coal/char reactivity, liquefaction reactivity of low-rank coals, gasification ash and slag characterization, fine particulate emissions), Combustion Research (fluidized bed combustion, beneficiation of low-rank coals, combustion characterization of low-rank coal fuels, diesel utilization of low-rank coals), Liquefaction Research (low-rank coal direct liquefaction), and Gasification Research (hydrogen production from low-rank coals, advanced wastewater treatment, mild gasification, color and residual COD removal from Synfuel wastewaters, Great Plains Gasification Plant, gasifier optimization).

Weber, G. F.; Laudal, D. L.

1989-01-01T23:59:59.000Z

325

Clean and Secure Energy from Coal  

SciTech Connect (OSTI)

The University of Utah, through their Institute for Clean and Secure Energy (ICSE), performed research to utilize the vast energy stored in our domestic coal resources and to do so in a manner that will capture CO2 from combustion from stationary power generation. The research was organized around the theme of validation and uncertainty quantification (V/UQ) through tightly coupled simulation and experimental designs and through the integration of legal, environment, economics and policy issues. The project included the following tasks: • Oxy-Coal Combustion – To ultimately produce predictive capability with quantified uncertainty bounds for pilot-scale, single-burner, oxy-coal operation. • High-Pressure, Entrained-Flow Coal Gasification – To ultimately provide a simulation tool for industrial entrained-flow integrated gasification combined cycle (IGCC) gasifier with quantified uncertainty. • Chemical Looping Combustion (CLC) – To develop a new carbon-capture technology for coal through CLC and to transfer this technology to industry through a numerical simulation tool with quantified uncertainty bounds. • Underground Coal Thermal Treatment – To explore the potential for creating new in-situ technologies for production of synthetic natural gas (SNG) from deep coal deposits and to demonstrate this in a new laboratory-scale reactor. • Mercury Control – To understand the effect of oxy-firing on the fate of mercury. • Environmental, Legal, and Policy Issues – To address the legal and policy issues associated with carbon management strategies in order to assess the appropriate role of these technologies in our evolving national energy portfolio. • Validation/Uncertainty Quantification for Large Eddy Simulations of the Heat Flux in the Tangentially Fired Oxy-Coal Alstom Boiler Simulation Facility – To produce predictive capability with quantified uncertainty bounds for the heat flux in commercial-scale, tangentially fired, oxy-coal boilers.

Smith, Philip; Davies, Lincoln; Kelly, Kerry; Lighty, JoAnn; Reitze, Arnold; Silcox, Geoffrey; Uchitel, Kirsten; Wendt, Jost; Whitty, Kevin

2014-08-31T23:59:59.000Z

326

Assessment of Metal Media Filters for Advanced Coal-Based Power Generation Applications  

SciTech Connect (OSTI)

Advanced coal and biomass-based gas turbine power generation technologies (IGCC, PFBC, PCFBC, and Hipps) are currently under development and demonstration. Efforts at Siemens Westinghouse Power Corporation (SWPC) have been focused on the development and demonstration of hot gas filter systems as an enabling technology for power generation. This paper reviews SWPC's material and component assessment efforts, identifying the performance, stability, and life of porous metal, advanced alloy, and intermetallic filters under simulated, pressurized fluidized-bed combustion conditions.

Alvin, M.A.

2002-09-19T23:59:59.000Z

327

THE LOCAL IMPACTS OF MERCURY EMISSIONS FROM COAL FIRED POWER PLANTS ON HUMAN HEALTH RISK. PROGRESS REPORT FOR THE PERIOD OF MARCH 2003 - MARCH 2003.  

SciTech Connect (OSTI)

This report presents a follow-up to previous assessments of the health risks of mercury that BNL performed for the Department of Energy. Methylmercury is an organic form of mercury that has been implicated as the form of mercury that impacts human health. A comprehensive risk assessment report was prepared (Lipfert et al., 1994) that led to several journal articles and conference presentations (Lipfert et al. 1994, 1995, 1996). In 2001, a risk assessment of mercury exposure from fish consumption was performed for 3 regions of the U.S (Northeast, Southeast, and Midwest) identified by the EPA as regions of higher impact from coal emissions (Sullivan, 2001). The risk assessment addressed the effects of in utero exposure to children through consumption of fish by their mothers. Two population groups (general population and subsistence fishers) were considered. Three mercury levels were considered in the analysis, current conditions based on measured data, and hypothetical reductions in Hg levels due to a 50% and 90% reduction in mercury emissions from coal fired power plants. The findings of the analysis suggested that a 90% reduction in coal-fired emissions would lead to a small reduction in risk to the general population (population risk reduction on the order of 10{sup -5}) and that the population risk is born by less than 1% of the population (i.e. high end fish consumers). The study conducted in 2001 focused on the health impacts arising from regional deposition patterns as determined by measured data and modeling. Health impacts were assessed on a regional scale accounting for potential percent reductions in mercury emissions from coal. However, quantitative assessment of local deposition near actual power plants has not been attempted. Generic assessments have been performed, but these are not representative of any single power plant. In this study, general background information on the mercury cycle, mercury emissions from coal plants, and risk assessment are provided to provide the basis for examining the impacts of local deposition. A section that covers modeling of local deposition of mercury emitted from coal power plants follows. The code ISCST3 was used with mercury emissions data from two power plants and local meteorological conditions to assess local deposition. The deposition modeling results were used to estimate the potential increase in mercury deposition that could occur in the vicinity of the plant. Increased deposition was assumed to lead to a linearly proportional increase in mercury concentrations in fish in local water bodies. Fish are the major pathway for human health impacts and the potential for increased mercury exposure was evaluated and the risks of such exposure estimated. Based on the findings recommendations for future work and conclusions are provided. Mercury is receiving substantial attention in a number of areas including: understanding of mercury deposition, bioaccumulation, and transport through the atmosphere, and improvements to the understanding of health impacts created by exposure to mercury. A literature review of key articles is presented as Appendix A.

SULLIVAN,T.M.LIPFERT,F.D.MORRIS,S.M.

2003-05-01T23:59:59.000Z

328

CERAMIC MEMBRANE ENABLING TECHNOLOGY FOR IMPROVED IGCC EFFICIENCY  

SciTech Connect (OSTI)

The objectives of the first year of phase 2 of the program are to construct and operate an engineering pilot reactor for OTM oxygen. Work to support this objective is being undertaken in the following areas in this quarter: Element reliability; Element fabrication; Systems technology; Power recovery; and IGCC process analysis and economics. The major accomplishments this quarter were: (1) Methods to improve the strength and stability of PSO1x were identified. (2) The O1 reactor was operated at target flux and target purity for 1000 hours. This quarterly technical progress report will summarize work accomplished for Phase 2 Program during the quarter October to December 2002. In task 1 improvements to PSO1x have shown increased performance in strength and stability. In task 2, PSO1d and PSO1x elements have been fabricated for testing in the pilot reactor. In task 3, the lab-scale pilot reactor has been operated for 1000 hours. In task 6 initial power recovery simulation has begun. In task 7, HYSIS models have been developed to optimize the process for a future demonstration unit.

Ravi Prasad

2003-03-01T23:59:59.000Z

329

Energy, Environmental, and Economic Analyses of Design Concepts for the Co-Production of Fuels and Chemicals with Electricity via Co-Gasification of Coal and Biomass  

SciTech Connect (OSTI)

The overall objective of this project was to quantify the energy, environmental, and economic performance of industrial facilities that would coproduce electricity and transportation fuels or chemicals from a mixture of coal and biomass via co-gasification in a single pressurized, oxygen-blown, entrained-flow gasifier, with capture and storage of CO{sub 2} (CCS). The work sought to identify plant designs with promising (Nth plant) economics, superior environmental footprints, and the potential to be deployed at scale as a means for simultaneously achieving enhanced energy security and deep reductions in U.S. GHG emissions in the coming decades. Designs included systems using primarily already-commercialized component technologies, which may have the potential for near-term deployment at scale, as well as systems incorporating some advanced technologies at various stages of R&D. All of the coproduction designs have the common attribute of producing some electricity and also of capturing CO{sub 2} for storage. For each of the co-product pairs detailed process mass and energy simulations (using Aspen Plus software) were developed for a set of alternative process configurations, on the basis of which lifecycle greenhouse gas emissions, Nth plant economic performance, and other characteristics were evaluated for each configuration. In developing each set of process configurations, focused attention was given to understanding the influence of biomass input fraction and electricity output fraction. Self-consistent evaluations were also carried out for gasification-based reference systems producing only electricity from coal, including integrated gasification combined cycle (IGCC) and integrated gasification solid-oxide fuel cell (IGFC) systems. The reason biomass is considered as a co-feed with coal in cases when gasoline or olefins are co-produced with electricity is to help reduce lifecycle greenhouse gas (GHG) emissions for these systems. Storing biomass-derived CO{sub 2} underground represents negative CO{sub 2} emissions if the biomass is grown sustainably (i.e., if one ton of new biomass growth replaces each ton consumed), and this offsets positive CO{sub 2} emissions associated with the coal used in these systems. Different coal:biomass input ratios will produce different net lifecycle greenhouse gas (GHG) emissions for these systems, which is the reason that attention in our analysis was given to the impact of the biomass input fraction. In the case of systems that produce only products with no carbon content, namely electricity, ammonia and hydrogen, only coal was considered as a feedstock because it is possible in theory to essentially fully decarbonize such products by capturing all of the coal-derived CO{sub 2} during the production process.

Eric Larson; Robert Williams; Thomas Kreutz; Ilkka Hannula; Andrea Lanzini; Guangjian Liu

2012-03-11T23:59:59.000Z

330

Wabash River Coal Gasification Repowering Project: A DOE Assessment  

SciTech Connect (OSTI)

The goal of the U.S. Department of Energy (DOE) Clean Coal Technology Program (CCT) 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 (PPA) of a project selected in CCT Round IV, the Wabash River Coal Gasification Repowering (WRCGR) Project, as described in a Report to Congress (U.S. Department of Energy 1992). Repowering consists of replacing an existing coal-fired boiler with one or more clean coal technologies to achieve significantly improved environmental performance. The desire to demonstrate utility repowering with a two-stage, pressurized, oxygen-blown, entrained-flow, integrated gasification combined-cycle (IGCC) system prompted Destec Energy, Inc., and PSI Energy, Inc., to form a joint venture and submit a proposal for this project. In July 1992, the Wabash River Coal Gasification Repowering Project Joint Venture (WRCGRPJV, the Participant) entered into a cooperative agreement with DOE to conduct this project. The project was sited at PSI Energy's Wabash River Generating Station, located in West Terre Haute, Indiana. The purpose of this CCT project was to demonstrate IGCC repowering using a Destec gasifier and to assess long-term reliability, availability, and maintainability of the system at a fully commercial scale. DOE provided 50 percent of the total project funding (for capital and operating costs during the demonstration period) of $438 million.

National Energy Technology Laboratory

2002-01-15T23:59:59.000Z

331

Coal Transportation Issues (released in AEO2007)  

Reports and Publications (EIA)

Most of the coal delivered to U.S. consumers is transported by railroads, which accounted for 64% of total domestic coal shipments in 2004. Trucks transported approximately 12% of the coal consumed in the United States in 2004, mainly in short hauls from mines in the East to nearby coal-fired electricity and industrial plants. A number of minemouth power plants in the West also use trucks to haul coal from adjacent mining operations. Other significant modes of coal transportation in 2004 included conveyor belt and slurry pipeline (12%) and water transport on inland waterways, the Great Lakes, and tidewater areas (9%).

2007-01-01T23:59:59.000Z

332

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

SciTech Connect (OSTI)

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

J. Daniel Arthur

2011-09-30T23:59:59.000Z

333

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

SciTech Connect (OSTI)

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

Thomas Gale

2010-09-26T23:59:59.000Z

334

CONCEPTUAL STUDIES OF A FUEL-FLEXIBLE LOW-SWIRL COMBUSTION SYSTEM FOR THE GAS TURBINE IN CLEAN COAL POWER PLANTS  

SciTech Connect (OSTI)

This paper reports the results of preliminary analyses that show the feasibility of developing a fuel flexible (natural gas, syngas and high-hydrogen fuel) combustion system for IGCC gas turbines. Of particular interest is the use of Lawrence Berkeley National Laboratory's DLN low swirl combustion technology as the basis for the IGCC turbine combustor. Conceptual designs of the combustion system and the requirements for the fuel handling and delivery circuits are discussed. The analyses show the feasibility of a multi-fuel, utility-sized, LSI-based, gas turbine engine. A conceptual design of the fuel injection system shows that dual parallel fuel circuits can provide range of gas turbine operation in a configuration consistent with low pollutant emissions. Additionally, several issues and challenges associated with the development of such a system, such as flashback and auto-ignition of the high-hydrogen fuels, are outlined.

Smith, K.O.; Littlejohn, David; Therkelsen, Peter; Cheng, Robert K.; Ali, S.

2009-11-30T23:59:59.000Z

335

Distribution of small dispersive coal dust particles and absorbed radioactive chemical elements in conditions of forced acoustic resonance in iodine air filter at nuclear power plant  

E-Print Network [OSTI]

The physical features of distribution of the small dispersive coal dust particles and the adsorbed radioactive chemical elements and their isotopes in the absorber with the granular filtering medium with the cylindrical coal granules were researched in the case of the intensive air dust aerosol stream flow through the iodine air filter (IAF). It was shown that, at the certain aerodynamic conditions in the IAF, the generation of the acoustic oscillations is possible. It was found that the acoustic oscillations generation results in an appearance of the standing acoustic waves of the air pressure (density) in the IAF. In the case of the intensive blow of the air dust aerosol, it was demonstrated that the standing acoustic waves have some strong influences on both: 1) the dynamics of small dispersive coal dust particles movement and their accumulation in the IAF; 2) the oversaturation of the cylindrical coal granules by the adsorbed radioactive chemical elements and their isotopes in the regions, where the antinodes of the acoustic waves are positioned. Finally, we completed the comparative analysis of the theoretical calculations with the experimental results, obtained for the cases of: 1) the experimental aerodynamic modeling of physical processes of the absorbed radioactive chemical elements and their isotopes distribution in the IAF; and 2) the gamma-activation spectroscopy analysis of the absorbed radioactive chemical elements and their isotopes distribution in the IAF. We made the innovative propositions on the necessary technical modifications with the purpose to improve the IAF technical characteristics and increase its operational time at the nuclear power plant (NPP), going from the completed precise characterization of the IAF parameters at the long term operation.

Oleg P. Ledenyov; Ivan M. Neklyudov

2013-06-14T23:59:59.000Z

336

Coal: the cornerstone of America's energy future  

SciTech Connect (OSTI)

In April 2005, US Secretary of Energy Samuel W. Bodman asked the National Coal Council to develop a 'report identifying the challenges and opportunities of more fully exploring our domestic coal resources to meet the nation's future energy needs'. The Council has responded with eight specific recommendations for developing and implementing advanced coal processing and combustion technologies to satisfy our unquenchable thirst for energy. These are: Use coal-to-liquids technologies to produce 2.6 million barrels/day; Use coal-to-natural gas technologies to produce 4 trillion ft{sup 3}/yr; Build 100 GW of clean coal plants by 2025; Produce ethanol from coal; Develop coal-to-hydrogen technologies; Use CO{sub 2} to enhance recovery of oil and coal-bed methane; Increase the capacity of US coal mines and railroads; and Invest in technology development and implementation. 1 ref.; 4 figs.; 1 tab.

Beck, R.A. [National Coal Council (United Kingdom)

2006-06-15T23:59:59.000Z

337

[Tampa Electric Company IGCC project]. Final public design report; Technical progress report  

SciTech Connect (OSTI)

This final Public Design Report (PDR) provides completed design information about Tampa Electric Company`s Polk Power Station Unit No. 1, which will demonstrate in a commercial 250 MW unit the operating parameters and benefits of the integration of oxygen-blown, entrained-flow coal gasification with advanced combined cycle technology. Pending development of technically and commercially viable sorbent for the Hot Gas Cleanup System, the HGCU also is demonstrated. The report is organized under the following sections: design basis description; plant descriptions; plant systems; project costs and schedule; heat and material balances; general arrangement drawings; equipment list; and miscellaneous drawings.

NONE

1996-07-01T23:59:59.000Z

338

Diffusion Coatings for Corrosion-Resistant Components in Coal Gasification Systems  

SciTech Connect (OSTI)

Advanced electric power generation systems use a coal gasifier to convert coal to a gas rich in fuels such as H{sub 2} and CO. The gas stream contains impurities such as H{sub 2}S and HCl, which attack metal components of the coal gas train, causing plant downtime and increasing the cost of power generation. Corrosion-resistant coatings would improve plant availability and decrease maintenance costs, thus allowing the environmentally superior integrated-gasification-combined-cycle (IGCC) plants to be more competitive with standard power-generation technologies. Heat-exchangers, particle filters, turbines, and other components in the IGCC system must withstand the highly sulfiding conditions of the high-temperature coal gas over an extended period of time. The performance of components degrades significantly with time unless expensive high alloy materials are used. Deposition of a suitable coating on a low cost alloy will improve is resistance to such sulfidation attack and decrease capital and operating costs. The alloys used in the gasifier service include austenitic and ferritic stainless steels, nickel-chromium-iron alloys, and expensive nickel-cobalt alloys. The Fe- and Ni-based high-temperature alloys are susceptible to sulfidation attack unless they are fortified with high levels of Cr, Al, and Si. To impart corrosion resistance, these elements need not be in the bulk of the alloy and need only be present at the surface layers. In this study, the use of corrosion-resistant coatings on low alloy steels was investigated for use as high-temperature components in IGCC systems. The coatings were deposited using SRI's fluidized-bed reactor chemical vapor deposition technique. Diffusion coatings of Cr and Al were deposited by this method on to dense and porous, low alloy stainless steel substrates. Bench-scale exposure tests at 900 C with a simulated coal gas stream containing 1.7% H{sub 2}S showed that the low alloy steels such SS405 and SS409 coated with {approx}20%Cr and Al each can be resistant to sulfidation attack for 500 h. However, exposure to an actual coal gasifier gas stream at the Wabash River gasifier facility for 1000 h in the temperature range 900 to 950 C indicated that Cr and Al present in the coating diffused further into the substrate decreasing the protective ability of these elements against attack by H{sub 2}S. Similarly, adherent multilayer coatings containing Si, Ti, Al, and Nb were also deposited with subsequent nitridation of these elements to increase the corrosion resistance. Both dense and porous SS409 or SS 410 alloy substrates were coated by using this method. Multilayer coatings containing Ti-Al-Si nitrides along with a diffusion barrier of Nb were deposited on SS410 and they were found also to be resistant to sulfidation attack in the bench scale tests at 900 C. However, they were corroded during exposure to the actual coal gasifier stream at the Wabash River gasifier facility for 1000 h. The Cr/Al coatings deposited inside a porous substrate was found to be resistant to sulfidation attack in the bench-scale simulated tests at 370 C. The long-term exposure test at the Wabash River gasifier facility at 370 C for 2100 h showed that only a minor sulfidation attack occurred inside the porous SS 409 alloy coupons that contained Cr and Al diffusion coatings. This attack can be prevented by improving the coating process to deposit uniform coatings at the interior of the porous structure. It is recommended that additional studies be initiated to optimize the FBR-CVD process to deposit diffusion coatings of the corrosion resistant elements such as Cr, Al, and Ti inside porous metal filters to increase their corrosion resistance. Long-term exposure tests using an actual gas stream from an operating gasifier need to be conducted to determine the suitability of the coatings for use in the gasifier environment.

Gopala N. Krishnan; Ripudaman Malhotra; Jordi Perez; Marc Hornbostel; Kai-Hung Lau; Angel Sanjurjo

2007-05-31T23:59:59.000Z

339

Gasification Plant Cost and Performance Optimization  

SciTech Connect (OSTI)

As part of an ongoing effort of the U.S. Department of Energy (DOE) to investigate the feasibility of gasification on a broader level, Nexant, Inc. was contracted to perform a comprehensive study to provide a set of gasification alternatives for consideration by the DOE. Nexant completed the first two tasks (Tasks 1 and 2) of the ''Gasification Plant Cost and Performance Optimization Study'' for the DOE's National Energy Technology Laboratory (NETL) in 2003. These tasks evaluated the use of the E-GAS{trademark} gasification technology (now owned by ConocoPhillips) for the production of power either alone or with polygeneration of industrial grade steam, fuel gas, hydrocarbon liquids, or hydrogen. NETL expanded this effort in Task 3 to evaluate Gas Technology Institute's (GTI) fluidized bed U-GAS{reg_sign} gasifier. The Task 3 study had three main objectives. The first was to examine the application of the gasifier at an industrial application in upstate New York using a Southeastern Ohio coal. The second was to investigate the GTI gasifier in a stand-alone lignite-fueled IGCC power plant application, sited in North Dakota. The final goal was to train NETL personnel in the methods of process design and systems analysis. These objectives were divided into five subtasks. Subtasks 3.2 through 3.4 covered the technical analyses for the different design cases. Subtask 3.1 covered management activities, and Subtask 3.5 covered reporting. Conceptual designs were developed for several coal gasification facilities based on the fluidized bed U-GAS{reg_sign} gasifier. Subtask 3.2 developed two base case designs for industrial combined heat and power facilities using Southeastern Ohio coal that will be located at an upstate New York location. One base case design used an air-blown gasifier, and the other used an oxygen-blown gasifier in order to evaluate their relative economics. Subtask 3.3 developed an advanced design for an air-blown gasification combined heat and power facility based on the Subtask 3.2 design. The air-blown case was chosen since it was less costly and had a better return on investment than the oxygen-blown gasifier case. Under appropriate conditions, this study showed a combined heat and power air-blown gasification facility could be an attractive option for upgrading or expanding the utilities area of industrial facilities. Subtask 3.4 developed a base case design for a large lignite-fueled IGCC power plant that uses the advanced GE 7FB combustion turbine to be located at a generic North Dakota site. This plant uses low-level waste heat to dry the lignite that otherwise would be rejected to the atmosphere. Although this base case plant design is economically attractive, further enhancements should be investigated. Furthermore, since this is an oxygen-blown facility, it has the potential for capture and sequestration of CO{sub 2}. The third objective for Task 3 was accomplished by having NETL personnel working closely with Nexant and Gas Technology Institute personnel during execution of this project. Technology development will be the key to the long-term commercialization of gasification technologies. This will be important to the integration of this environmentally superior solid fuel technology into the existing mix of power plants and industrial facilities. As a result of this study, several areas have been identified in which research and development will further advance gasification technology. Such areas include improved system availability, development of warm-gas clean up technologies, and improved subsystem designs.

Samuel Tam; Alan Nizamoff; Sheldon Kramer; Scott Olson; Francis Lau; Mike Roberts; David Stopek; Robert Zabransky; Jeffrey Hoffmann; Erik Shuster; Nelson Zhan

2005-05-01T23:59:59.000Z

340

Zero Emissions Coal Syngas Oxygen Turbo Machinery  

SciTech Connect (OSTI)

Siemens Energy, Inc. (formerly Siemens Westinghouse Power Corporation) worked with Clean Energy Systems and Florida Turbine Technologies to demonstrate the commercial feasibility of advanced turbines for oxy-fuel based power systems that discharge negligible CO{sub 2} into the atmosphere. The approach builds upon ultra supercritical steam turbine and advanced gas turbine technology with the goal of attaining plant efficiencies above 50% in the 2015 timeframe. Conceptual designs were developed for baseline, near term, and long term oxy-fuel turbine cycles, representing commercial introductions of increasingly advanced thermal conditions and increasing exposure to steam-CO{sub 2} mixtures. An economic analysis and market demand study was performed by Science Applications International Corp. (SAIC), and indicated that long-term oxy-fuel turbine cycles start to look attractive in 2025 when the CO{sub 2} tax is assumed to reach $40/ ton, and by 2030 it has a clear advantage over both IGCC with sequestration and pulverized coal with sequestration. A separate risk analysis of the oxy-fuel combustor, HP turbine, re-heater, and IP turbine of the long-term cycle identified and categorized risks and proposed mitigation measures. In 2007 the program began to focus on a potential oxy-fuel turbine power generation demonstration project in the 2012 -13 time period while still maintaining a link to the requirements of the long-term oxy-syngas cycle. The SGT-900 turbine was identified as the best fit for modification into an intermediate pressure turbine (IPT) for this application. The base metals, bond coats, thermal barrier coatings (TBCs), and rotor materials used in the SGT-900 were tested for their ability to operate in the steam- CO{sub 2} environment of the oxy-fuel OFT-900. Test results indicated that these same materials would operate satisfactorily, and the plan, is to use SGT-900materials for the OFT-900. Follow-on programs for corrosion testing and evaluation of crack growth rates in oxy-fuel environments have been proposed to build on these results and provide quantifiable assessments of the effects of oxy-fuel environments on the service lives of turbine components.

Dennis Horazak

2010-12-31T23:59:59.000Z

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341

Is Integrated Gasification Combined Cycle with Carbon Capture-Storage the Solution for Conventional Coal Power Plants  

E-Print Network [OSTI]

? Nuclear Power Plants ? Solar Power Plants ? Wind Power Plants ? Geothermal Power Plants 1.2.2 Based on the Function Performed Three main types of power plants are categorized according to the functions they perform. These are called “base load..., Temperature and Efficiency for PC Technologies. Reprinted from Hermine Nalbandian 2009. Energia – Center for Applied Energy Research With the extensive favorable experience in Europe, Japan and Korea using supercritical (SC) steam cycles over the past...

Kundi, Manish

2011-12-16T23:59:59.000Z

342

AVESTAR Center for Operational Excellence of Electricity Generation Plants  

SciTech Connect (OSTI)

To address industry challenges in attaining operational excellence for electricity generation plants, the U.S. Department of Energy’s (DOE) National Energy Technology Laboratory (NETL) has launched a world-class facility for Advanced Virtual Energy Simulation Training and Research (AVESTARTM). This presentation will highlight the AVESTARTM Center simulators, facilities, and comprehensive training, education, and research programs focused on the operation and control of high-efficiency, near-zero-emission electricity generation plants. The AVESTAR Center brings together state-of-the-art, real-time, high-fidelity dynamic simulators with full-scope operator training systems (OTSs) and 3D virtual immersive training systems (ITSs) into an integrated energy plant and control room environment. AVESTAR’s initial offering combines--for the first time--a “gasification with CO2 capture” process simulator with a “combined-cycle” power simulator together in a single OTS/ITS solution for an integrated gasification combined cycle (IGCC) power plant with carbon dioxide (CO2) capture. IGCC systems are an attractive technology option for power generation, especially when capturing and storing CO2 is necessary to satisfy emission targets. The AVESTAR training program offers a variety of courses that merge classroom learning, simulator-based OTS learning in a control-room operations environment, and immersive learning in the interactive 3D virtual plant environment or ITS. All of the courses introduce trainees to base-load plant operation, control, startups, and shutdowns. Advanced courses require participants to become familiar with coordinated control, fuel switching, power-demand load shedding, and load following, as well as to problem solve equipment and process malfunctions. Designed to ensure work force development, training is offered for control room and plant field operators, as well as engineers and managers. Such comprehensive simulator-based instruction allows for realistic training without compromising worker, equipment, and environmental safety. It also better prepares operators and engineers to manage the plant closer to economic constraints while minimizing or avoiding the impact of any potentially harmful, wasteful, or inefficient events. The AVESTAR Center is also used to augment graduate and undergraduate engineering education in the areas of process simulation, dynamics, control, and safety. Students and researchers gain hands-on simulator-based training experience and learn how the commercial-scale power plants respond dynamically to changes in manipulated inputs, such as coal feed flow rate and power demand. Students also analyze how the regulatory control system impacts power plant performance and stability. In addition, students practice start-up, shutdown, and malfunction scenarios. The 3D virtual ITSs are used for plant familiarization, walk-through, equipment animations, and safety scenarios. To further leverage the AVESTAR facilities and simulators, NETL and its university partners are pursuing an innovative and collaborative R&D program. In the area of process control, AVESTAR researchers are developing enhanced strategies for regulatory control and coordinated plant-wide control, including gasifier and gas turbine lead, as well as advanced process control using model predictive control (MPC) techniques. Other AVESTAR R&D focus areas include high-fidelity equipment modeling using partial differential equations, dynamic reduced order modeling, optimal sensor placement, 3D virtual plant simulation, and modern grid. NETL and its partners plan to continue building the AVESTAR portfolio of dynamic simulators, immersive training systems, and advanced research capabilities to satisfy industry’s growing need for training and experience with the operation and control of clean energy plants. Future dynamic simulators under development include natural gas combined cycle (NGCC) and supercritical pulverized coal (SCPC) plants with post-combustion CO2 capture. These dynamic simulators are targeted for us

Zitney, Stephen

2012-08-29T23:59:59.000Z

343

Energy Center Center for Coal Technology Research  

E-Print Network [OSTI]

Energy Center Center for Coal Technology Research http://www.purdue.edu/dp/energy/CCTR/ Consumption Production Gasification Power Plants Coking Liquid Fuels Environment Oxyfuels Byproducts Legislation, 500 Central Drive West Lafayette, IN 47907-2022 #12;INDIANA COAL REPORT 2009 Center for Coal

Fernández-Juricic, Esteban

344

Coal mine directory: United States and Canada  

SciTech Connect (OSTI)

The directory gives a state-by-state listing of all US and Canadian coal producers. It contains contact information as well as the type of mine, production statistics, coal composition, transportation methods etc. A statistical section provides general information about the US coal industry, preparation plants, and longwall mining operations.

NONE

2004-07-01T23:59:59.000Z

345

Conventional coal preparation in the United States  

SciTech Connect (OSTI)

Processing of bituminous and anthracite coal is widely practiced in the United States and, as mentioned earlier, about 80 percent of the production of these coals is processed as clean coal in preparation plants. Subbituminous coal is not widely processed, primarily because these low rank raw coals are low in sulfur (0.5 to 1.0 percent) and relatively low in ash (8 to 15 percent). They are also relatively low in heat content due to their high inherent moisture. Lignite coals, to the best of the authors{close_quote} knowledge, are not presently being processed in Conventional Coal Preparation plants. This is due to their unstable nature and putting them in water in a coal preparation plant is likely to cause severe degradation in particle size and add to their already high inherent moisture content. The following are the benefits of clean coal processing: produces a uniform product which can be utilized more efficiently; produces a higher quality product which results in higher efficiency at the power station or the steel mill; reduces sulfur dioxide and other adverse stack emissions during coal firing which is a very important environmental consideration; reduces ash or slag handling costs by the user; reduces shipping costs; and reduces handling and storage costs. Processing any stable raw coal in a coal preparation plant will always produce a higher grade product which is a more efficient and a more environmentally acceptable fuel for use at power stations, steel mills, home heating or industrial boilers.

Beck, M.K.; Taylor, B.

1993-12-31T23:59:59.000Z

346

A COMPUTATIONAL WORKBENCH ENVIRONMENT FOR VIRTUAL POWER PLANT SIMULATION  

SciTech Connect (OSTI)

In this report is described the work effort to develop and demonstrate a software framework to support advanced process simulations to evaluate the performance of advanced power systems. Integrated into the framework are a broad range of models, analysis tools, and visualization methods that can be used for the plant evaluation. The framework provides a tightly integrated problem-solving environment, with plug-and-play functionality, and includes a hierarchy of models, ranging from fast running process models to detailed reacting CFD models. The framework places no inherent limitations on the type of physics that can be modeled, numerical techniques, or programming languages used to implement the equipment models, or the type or amount of data that can be exchanged between models. Tools are provided to analyze simulation results at multiple levels of detail, ranging from simple tabular outputs to advanced solution visualization methods. All models and tools communicate in a seamless manner. The framework can be coupled to other software frameworks that provide different modeling capabilities. Three software frameworks were developed during the course of the project. The first framework focused on simulating the performance of the DOE Low Emissions Boiler System Proof of Concept facility, an advanced pulverized-coal combustion-based power plant. The second framework targeted simulating the performance of an Integrated coal Gasification Combined Cycle - Fuel Cell Turbine (IGCC-FCT) plant configuration. The coal gasifier models included both CFD and process models for the commercially dominant systems. Interfacing models to the framework was performed using VES-Open, and tests were performed to demonstrate interfacing CAPE-Open compliant models to the framework. The IGCC-FCT framework was subsequently extended to support Virtual Engineering concepts in which plant configurations can be constructed and interrogated in a three-dimensional, user-centered, interactive, immersive environment. The Virtual Engineering Framework (VEF), in effect a prototype framework, was developed through close collaboration with NETL supported research teams from Iowa State University Virtual Reality Applications Center (ISU-VRAC) and Carnegie Mellon University (CMU). The VEF is open source, compatible across systems ranging from inexpensive desktop PCs to large-scale, immersive facilities and provides support for heterogeneous distributed computing of plant simulations. The ability to compute plant economics through an interface that coupled the CMU IECM tool to the VEF was demonstrated, and the ability to couple the VEF to Aspen Plus, a commercial flowsheet modeling tool, was demonstrated. Models were interfaced to the framework using VES-Open. Tests were performed for interfacing CAPE-Open-compliant models to the framework. Where available, the developed models and plant simulations have been benchmarked against data from the open literature. The VEF has been installed at NETL. The VEF provides simulation capabilities not available in commercial simulation tools. It provides DOE engineers, scientists, and decision makers with a flexible and extensible simulation system that can be used to reduce the time, technical risk, and cost to develop the next generation of advanced, coal-fired power systems that will have low emissions and high efficiency. Furthermore, the VEF provides a common simulation system that NETL can use to help manage Advanced Power Systems Research projects, including both combustion- and gasification-based technologies.

Mike Bockelie; Dave Swensen; Martin Denison; Adel Sarofim; Connie Senior

2004-12-22T23:59:59.000Z

347

Coal pump  

DOE Patents [OSTI]

A device for pressurizing pulverized coal and circulating a carrier gas is disclosed. This device has utility in a coal gasification process and eliminates the need for a separate collection hopper and eliminates the separate compressor.

Bonin, John H. (Sunnyvale, CA); Meyer, John W. (Palo Alto, CA); Daniel, Jr., Arnold D. (Alameda County, CA)

1983-01-01T23:59:59.000Z

348

Wabash River Integrated Methanol and Power Production from Clean Coal Technologies (IMPPCCT)  

SciTech Connect (OSTI)

The Wabash River Integrated Methanol and Power Production from Clean Coal Technologies (IMPPCCT) project was established to evaluate integrated electrical power generation and methanol production through clean coal technologies. The project was under the leadership of ConocoPhillips Company (COP), after it acquired Gasification Engineering Corporation (GEC) and the E-Gas gasification technology from Global Energy Inc. in July 2003. The project has completed both Phase 1 and Phase 2 of development. The two project phases include the following: (1) Feasibility study and conceptual design for an integrated demonstration facility at SG Solutions LLC (SGS), previously the Wabash River Energy Limited, Gasification Facility located in West Terre Haute, Indiana, and for a fence-line commercial embodiment plant (CEP) operated at the Dow Chemical Company or Dow Corning Corporation chemical plant locations. (2) Research, development, and testing (RD&T) to define any technology gaps or critical design and integration issues. Phase 1 of this project was supported by a multi-industry team consisting of Air Products and Chemicals, Inc., The Dow Chemical Company, Dow Corning Corporation, Methanex Corporation, and Siemens Westinghouse Power Corporation, while Phase 2 was supported by Gas Technology Institute, TDA Research Inc., and Nucon International, Inc. The SGS integrated gasification combined cycle (IGCC) facility was designed, constructed, and operated under a project selected and co-funded under the Round IV of the United States Department of Energy's (DOE's) Clean Coal Technology Program. In this project, coal and/or other carbonaceous fuel feedstocks are gasified in an oxygen-blown, entrained-flow gasifier with continuous slag removal and a dry particulate removal system. The resulting product synthesis gas (syngas) is used to fuel a combustion turbine generator whose exhaust is integrated with a heat recovery steam generator to drive a refurbished steam turbine generator. The gasifier uses technology initially developed by The Dow Chemical Company (the Destec Gasification Process), and now acquired and offered commercially by COP as the E-Gas technology. In a joint effort with the DOE, a Cooperative Agreement was awarded under the Early Entrance Coproduction Plant (EECP) solicitation. GEC, and later COP and the industrial partners investigated the use of syngas produced by the E-Gas technology in a coproduction environment to enhance the efficiency and productivity of solid fuel gasification combined cycle power plants. The objectives of this effort were to determine the feasibility of an EECP located at a specific site which produces some combination of electric power (or heat), fuels, and/or chemicals from syngas derived from coal, or, coal in combination with some other carbonaceous feedstock. The intended result of the project was to provide the necessary technical, economic, and environmental information that would be needed to move the EECP forward to detailed design, construction, and operation by industry. The EECP study conducted in Phase 1 of the IMPPCCT Project confirmed that the concept for the integration of gasification-based (E-Gas) electricity generation from coal and/or petroleum coke and methanol production (Liquid Phase Methanol or LPMEOH{trademark}) processes was feasible for the coproduction of power and chemicals. The results indicated that while there were minimal integration issues that impact the deployment of an IMPPCCT CEP, the major concern was the removal of sulfur and other trace contaminants, which are known methanol catalyst poisons, from the syngas. However, economic concerns in the domestic methanol market which is driven by periodic low natural gas prices and cheap offshore supplies limit the commercial viability of this more capital intensive concept. The objective of Phase 2 was to conduct RD&T as outlined in the Phase 1 RD&T Plan to enhance the development and commercial acceptance of coproduction technology. Studies were designed to address the technical concerns that would mak

Conocophillips

2007-09-30T23:59:59.000Z

349

Potential applications of microscopy for steam coal  

SciTech Connect (OSTI)

Optical microscopy has been an extremely useful tool for many industrial sectors in the past. This paper introduces some of the potential applications of using coal and fly ash carbon microscopy for the combustion process and steam coal industry. Coal and fly ash carbon microscopic classification criteria are described. Plant sample data are presented which demonstrate that these techniques can be useful for coal selection and for problem solving in the coal-fired power plant environment. Practical recommendations for further study are proposed.

DeVanney, K.F.; Clarkson, R.J.

1995-08-01T23:59:59.000Z

350

Hg and Se capture and fly ash carbons from combustion of complex pulverized feed blends mainly of anthracitic coal rank in Spanish power plants  

SciTech Connect (OSTI)

In this work, the petrology and chemistry of fly ashes produced in a Spanish power plant from the combustion of complex pulverized feed blends made up of anthracitic/meta-anthracitic coals, petroleum, and natural coke are investigated. It was found that the behavior of fly ash carbons derived from anthracitic coals follows relatively similar patterns to those established for the carbons from the combustion of bituminous coals. Fly ashes were sampled in eight hoppers from two electrostatic precipitator (ESP) rows. The characterization of the raw ashes and their five sieved fractions (from {gt}150 to {lt}25 {mu}m) showed that glassy material, quartz, oxides, and spinels in different proportions are the main inorganic components. As for the organic fraction, the dominant fly ash carbons are anisotropic carbons, mainly unburned carbons derived from anthracitic vitrinite. The concentration of Se and Hg increased in ashes of the second ESP row, this increase being related to the higher proportion of anisotropic unburned carbons, particularly those largely derived from anthracitic vitrinite in the cooler ashes of the ESP (second row) and also related to the decrease in the flue gas temperature. This suggests that the flue gas temperature plays a major role in the concentration of mercury for similar ratios of unburned carbons. It was also found that Hg is highly concentrated in the medium-coarser fractions of the fly ashes ({gt} 45 {mu}m), there being a positive relationship between the amount of these carbons, which are apparently little modified during the combustion process, in the medium-coarse fractions of the ashes and the Hg retention. According to the results obtained, further research on this type of fly ash could be highly productive. 28 refs., 10 figs., 8 tabs.

I. Surez-Ruiz; J.C. Hower; G.A. Thomas [Instituto Nacional del Carbon (INCAR-CSIC), Oviedo (Spain)

2007-01-15T23:59:59.000Z

351

Studies on the reduction kinetics of hematite iron ore pellets with noncoking coals for sponge iron plants  

SciTech Connect (OSTI)

In the present investigation, fired pellets were made by mixing hematite iron ore fines of -100, -16+18, and -8+10 mesh size in different ratios and studies on their reduction kinetics in Lakhanpur, Orient OC-2 and Belpahar coals were carried out at temperatures ranging from 850{sup o}C to 1000{sup o}C with a view toward promoting the massive utilization of fines in ironmaking. The rate of reduction in all the fired iron ore pellets increased markedly with an increase in temperature up to 1000{sup o}C, and it was more intense in the first 30min. The values of activation energy, calculated from integral and differential approaches, for the reduction of fired pellets (prepared from iron ore fines of -100 mesh size) in coals were found to be in the range 131-148 and 130-181 kJ mol{sup -1} (for =0.2 to 0.8), indicating the process is controlled by a carbon gasification reaction. The addition of selected larger size particles in the matrix of -100 mesh size fines up to the extent studied decreased the activation energy and slightly increased the reduction rates of resultant fired pellets. In comparison to coal, the reduction of fired pellets in char was characterized by significantly lower reduction rates and higher activation energy.

Kumar, M.; Mohapatra, P.; Patel, S.K. [National Institute of Technology, Rourkela (India). Dept. of Mechanical Engineering

2009-07-01T23:59:59.000Z

352

Air pollution: Coal based power plants major culprit : HindustanTimes.com http://www.hindustantimes.com/news/5922_1646830,001500250000000... 1 of 2 3/10/2006 7:45 AM  

E-Print Network [OSTI]

Air pollution: Coal based power plants major culprit : HindustanTimes.com http://www.hindustantimes.com/news/5922_1646830,001500250000000... 1 of 2 3/10/2006 7:45 AM Advertisement Friday, March 10, 2006 | 02 Archives » About Us Advertise Investors Register HindustanTimes.com » Print Editions » Lucknow » Metro » Pg

Singh, Ramesh P.

353

Remedial investigation report on Chestnut Ridge Operable Unit 2 (filled coal ash pond/Upper McCoy Branch) at the Oak Ridge Y-12 Plant, Oak Ridge, Tennessee. Volume 2: Appendixes  

SciTech Connect (OSTI)

This report comprises appendices A--J which support the Y-12 Plant`s remedial action report involving Chestnut Ridge Operable Unit 2 (filled coal ash pond/Upper McCoy Branch). The appendices cover the following: Sampling fish from McCoy Branch; well and piezometer logs; ecological effects of contaminants in McCoy Branch 1989-1990; heavy metal bioaccumulation data; microbes in polluted sediments; and baseline human health risk assessment data.

Not Available

1994-08-01T23:59:59.000Z

354

PNW Coal Closure Study Resource Adequacy Advisory Committee  

E-Print Network [OSTI]

PNW Coal Closure Study 1 y Resource Adequacy Advisory Committee Steering Committee Meeting outage calculations)100 MW (for forced outage calculations) #12;Coal Replacement Plans 4 Coal Replacement Plans · Boardman ­ 601 MW · The 2016 PGE IRP process will include the Boardman coal plant replacement

355

Demonstration of a Piston Plug feed System for Feeding Coal/Biomass Mixtures across a Pressure Gradient for Application to a Commercial CBTL System  

SciTech Connect (OSTI)

Producing liquid transportation fuels and power via coal and biomass to liquids (CBTL) and integrated gasification combined cycle (IGCC) processes can significantly improve the nation's energy security. The Energy Independence and Security Act of 2007 mandates increasing renewable fuels nearly 10-fold to >2.3 million barrels per day by 2022. Coal is abundantly available and coal to liquids (CTL) plants can be deployed today, but they will not become sustainable without large scale CO{sub 2} capture and storage. Co-processing of coal and biomass in CBTL processes in a 60 to 40 ratio is an attractive option that has the potential to produce 4 million barrels of transportation fuels per day by 2020 at the same level of CO{sub 2} emission as petroleum. In this work, Southern Research Institute (Southern) has made an attempt to address one of the major barriers to the development of large scale CBTL processes - cost effective/reliable dry-feeding of coal-biomass mixtures into a high pressure vessel representative of commercial entrained-flow gasifiers. Present method for dry coal feeding involves the use of pressurized lock-hopper arrangements that are not only very expensive with large space requirements but also have not been proven for reliably feeding coal-biomass mixtures without the potential problems of segregation and bridging. The project involved the development of a pilot-scale 250 lb/h high pressure dry coal-biomass mixture feeder provided by TKEnergi and proven for feeding biomass at a scale up to 6 ton/day. The aim of this project is to demonstrate cost effective feeding of coal-biomass mixtures (50:50 to 70:30) made from a variety of coals (bituminous, lignite) and biomass (wood, corn stover, switch grass). The feeder uses a hydraulic piston-based approach to produce a series of plugs of the mixture that act as a seal against high back-pressure of the gasification vessel in to which the mixture is being fed. The plugs are then fed one by one via a plug breaker into the high pressure gasification vessel. A number of runs involving the feeding of coal and biomass mixtures containing 50 to 70 weight % coal into a high pressure gasification vessel simulator have shown that plugs of sufficient density can be formed to provide a seal against pressures up to 450 psig if homogeneity of the mixture can be maintained. However, the in-homogeneity of coal-biomass mixtures can occur during the mixing process because of density, particle size and moisture differences. Also, the much lower compressibility of coal as opposed to biomass can contribute to non-uniform plug formation which can result in weak plugs. Based on present information, the piston plug feeder offered marginal economic advantages over lock-hoppers. The results suggest a modification to the piston feeder that can potentially seal against pressure without the need for forming plugs. This modified design could result in lower power requirements and potentially better economics.

Santosh Gangwal

2011-06-30T23:59:59.000Z

356

On the structurization of coal dust precipitations and their influence on aerodynamic resistance by granulated mediums in air filters at nuclear power plants  

E-Print Network [OSTI]

The processes of structurization of dust precipitations in granulated filtering mediums, formed by the monolithic glass spherical granules with the diameters of 2mm and 3mm, are re-searched. The distinctions between the distributions of filtered coal dust masses in the air filters with cylindrical granules and the air filters with spherical granules, are found. The influences by the filtered dust masses on the air resistance of both the air filters with the cylindrical granules and the air filters with the spherical granules are described. The conclusions on a possibility of the use of various chemical adsorbents with different geometric forms and volumetric dimensions to improve the filtering properties of granulated filtering mediums in air filters at nuclear power plants are formulated.

Neklyudov, I M; Fedorova, L I; Poltinin, P Ya

2012-01-01T23:59:59.000Z

357

On the structurization of coal dust precipitations and their influence on aerodynamic resistance by granulated mediums in air filters at nuclear power plants  

E-Print Network [OSTI]

The processes of structurization of dust precipitations in granulated filtering mediums, formed by the monolithic glass spherical granules with the diameters of 2mm and 3mm, are re-searched. The distinctions between the distributions of filtered coal dust masses in the air filters with cylindrical granules and the air filters with spherical granules, are found. The influences by the filtered dust masses on the air resistance of both the air filters with the cylindrical granules and the air filters with the spherical granules are described. The conclusions on a possibility of the use of various chemical adsorbents with different geometric forms and volumetric dimensions to improve the filtering properties of granulated filtering mediums in air filters at nuclear power plants are formulated.

I. M. Neklyudov; O. P. Ledenyov; L. I. Fedorova; P. Ya. Poltinin

2012-07-02T23:59:59.000Z

358

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

SciTech Connect (OSTI)

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

None

2010-07-01T23:59:59.000Z

359

Experience curves for power plant emission control technologies  

E-Print Network [OSTI]

reduction in NO x emissions from coal-fired power plants tocombustion of coal, emissions from coal-fired power plantsemission control technologies now required on all new coal-fired power

Rubin, Edward S.; Yeh, Sonia; Hounshell, David A

2007-01-01T23:59:59.000Z

360

Environmental trends in Asia are accelerating the introduction of clean coal technologies and natural gas  

SciTech Connect (OSTI)

This paper examines the changing energy mix for Asia to 2020, and impacts of increased coal consumption on Asia`s share of world SO{sub 2} and CO{sub 2} emissions. Stricter SO{sub 2} emissions laws are summarized for eight Asian economies along with implications for fuel and technology choices. The paper compares the economics of different technologies for coal and natural gas in 1997 and in 2007. Trends toward introducing clean coal technologies and the use of natural gas will accelerate in response to tighter environmental standards by 2000. The most important coal conversion technology for Asia, particularly China, in the long term is likely to be integrated gasification combined-cycle (IGCC), but only under the assumption of multiple products.

Johnson, C.J.

1997-09-01T23:59:59.000Z

Note: This page contains sample records for the topic "igcc coal plants" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


361

Tri-State Synfuels Project Review: Volume 8. Commercial status of licensed process units. [Proposed Henderson, Kentucky coal to gasoline plant; licensed commercial processes  

SciTech Connect (OSTI)

This document demonstrates the commercial status of the process units to be used in the Tri-State Synfuels Project at Henderson, Kentucky. The basic design philosophy as established in October, 1979, was to use the commercial SASOL II/III plants as a basis. This was changed in January 1982 to a plant configuration to produce gasoline via a methanol and methanol to gasoline process. To accomplish this change the Synthol, Oil workup and Chemical Workup Units were eliminated and replaced by Methanol Synthesis and Methanol to Gasoline Units. Certain other changes to optimize the Lurgi liquids processing eliminated the Tar Distillation and Naphtha Hydrotreater Units which were replaced by the Partial Oxidation Unit. The coals to be gasified are moderately caking which necessitates the installation of stirring mechanism in the Lurgi Dry Bottom gasifier. This work is in the demonstration phase. Process licenses either have been obtained or must be obtained for a number of processes to be used in the plant. The commercial nature of these processes is discussed in detail in the tabbed sections of this document. In many cases there is a list of commercial installations at which the licensed equipment is used.

Not Available

1982-06-01T23:59:59.000Z

362

Coal-CO[subscript 2] Slurry Feed for Pressurized Gasifiers: Slurry Preparation System Characterization and Economics  

E-Print Network [OSTI]

Gasification-based plants with coal-CO[subscript 2] slurry feed are predicted to be more efficient than those with coal-water slurry feed. This is particularly true for high moisture, low rank coal such as lignite. ...

Botero, Cristina

363

Assessment of the Flue Gas Recycle Strategies on Oxy-Coal Power Plants using an Exergy-based Methodology  

E-Print Network [OSTI]

to the highest net plant efficiency. This option not only allows the minimal exergy losses in the boiler but also and solvents formulation. Thus, significant efficiency improvement is needed for the oxy- combustion route minimizes the flowrate going through the downstream depollution devices. The net plant efficiency obtained

Paris-Sud XI, Université de

364

Conversion of Hydrogen Sulfide in Coal Gases to Liquid Elemental Sulfur with Monolithic Catalysts  

SciTech Connect (OSTI)

Removal of hydrogen sulfide (H{sub 2}S) from coal gasifier gas and sulfur recovery are key steps in the development of Department of Energy's (DOE's) advanced power plants that produce electric power and clean transportation fuels with coal and natural gas. These plants will require highly clean coal gas with H{sub 2}S below 1 ppmv and negligible amounts of trace contaminants such as hydrogen chloride, ammonia, alkali, heavy metals, and particulate. The conventional method of sulfur removal and recovery employing amine, Claus, and tail-gas treatment is very expensive. A second generation approach developed under DOE's sponsorship employs hot-gas desulfurization (HGD) using regenerable metal oxide sorbents followed by Direct Sulfur Recovery Process (DSRP). However, this process sequence does not remove trace contaminants and is targeted primarily towards the development of advanced integrated gasification combined cycle (IGCC) plants that produce electricity (not both electricity and transportation fuels). There is an immediate as well as long-term need for the development of cleanup processes that produce highly clean coal gas for next generation power plants. To this end, a novel process is now under development at several research organizations in which the H{sub 2}S in coal gas is directly oxidized to elemental sulfur over a selective catalyst. Such a process is ideally suited for coal gas from commercial gasifiers with a quench system to remove essentially all the trace contaminants except H{sub 2}S In the Single-Step Sulfur Recovery Process (SSRP), the direct oxidation of H{sub 2}S to elemental sulfur in the presence of SO{sub 2} is ideally suited for coal gas from commercial gasifiers with a quench system to remove essentially all the trace contaminants except H{sub 2}S. This direct oxidation process has the potential to produce a super clean coal gas more economically than both conventional amine-based processes and HGD/DSRP. The H{sub 2} and CO components of syngas appear to behave as inert with respect to sulfur formed at the SSRP conditions. One problem in the SSRP process that needs to be eliminated or minimized is COS formation that may occur due to reaction of CO with sulfur formed from the Claus reaction. The objectives of this research are to formulate monolithic catalysts for removal of H{sub 2}S from coal gases and minimum formation of COS with monolithic catalyst supports, {gamma}-alumina wash coat, and catalytic metals, to develop a regeneration method for a deactivated monolithic catalyst, to measure kinetics of both direct oxidation of H{sub 2}S to elemental sulfur with SO{sub 2} as an oxidizer and formation of COS in the presence of a simulated coal gas mixture containing H{sub 2}, CO, CO{sub 2}, and moisture, using a monolithic catalyst reactor. The task of developing kinetic rate equations and modeling the direct oxidation process to assist in the design of large-scale plants will be abandoned since formulation of catalysts suitable for the removal of H{sub 2}S and COS is being in progress. This heterogeneous catalytic reaction has gaseous reactants such as H{sub 2}S and SO{sub 2}. However, this heterogeneous catalytic reaction has heterogeneous products such as liquid elemental sulfur and steam. Experiments on conversion of hydrogen sulfide into elemental sulfur and formation of COS were carried out for the space time range of 46-570 seconds under reaction conditions to formulate catalysts suitable for the removal of H{sub 2}S and COS from coal gases and evaluate their capabilities in reducing hydrogen sulfide and COS in coal gases. Simulated coal gas mixtures consist of 3,200-4,000-ppmv hydrogen sulfide, 1,600-20,000-ppmv sulfur dioxide, 18-27 v% hydrogen, 29-41 v% CO, 8-12 v% CO{sub 2}, 0-10 vol % moisture, and nitrogen as remainder. Volumetric feed rates of simulated coal gas mixtures to the reactor are 30 - 180 cm{sup 3}/min at 1 atm and 25 C (SCCM). The temperature of the reactor is controlled in an oven at 120-155 C. The pressure of the reactor is maintained at 40-210 psia. The molar ratio

K.C. Kwon

2009-09-30T23:59:59.000Z

365

Conversion of Hydrogen Sulfide in Coal Gases to Liquid Elemental Sulfur with Monolithic Catalysts  

SciTech Connect (OSTI)

Removal of hydrogen sulfide (H{sub 2}S) from coal gasifier gas and sulfur recovery are key steps in the development of Department of Energy's (DOE's) advanced power plants that produce electric power and clean transportation fuels with coal and natural gas. These plants will require highly clean coal gas with H{sub 2}S below 1 ppmv and negligible amounts of trace contaminants such as hydrogen chloride, ammonia, alkali, heavy metals, and particulate. The conventional method of sulfur removal and recovery employing amine, Claus, and tail-gas treatment is very expensive. A second generation approach developed under DOE's sponsorship employs hot-gas desulfurization (HGD) using regenerable metal oxide sorbents followed by Direct Sulfur Recovery Process (DSRP). However, this process sequence does not remove trace contaminants and is targeted primarily towards the development of advanced integrated gasification combined cycle (IGCC) plants that produce electricity (not both electricity and transportation fuels). There is an immediate as well as long-term need for the development of cleanup processes that produce highly clean coal gas for next generation power plants. To this end, a novel process is now under development at several research organizations in which the H{sub 2}S in coal gas is directly oxidized to elemental sulfur over a selective catalyst. Such a process is ideally suited for coal gas from commercial gasifiers with a quench system to remove essentially all the trace contaminants except H{sub 2}S In the Single-Step Sulfur Recovery Process (SSRP), the direct oxidation of H{sub 2}S to elemental sulfur in the presence of SO{sub 2} is ideally suited for coal gas from commercial gasifiers with a quench system to remove essentially all the trace contaminants except H{sub 2}S. This direct oxidation process has the potential to produce a super clean coal gas more economically than both conventional amine-based processes and HGD/DSRP. The H{sub 2} and CO components of syngas appear to behave as inert with respect to sulfur formed at the SSRP conditions. One problem in the SSRP process that needs to be eliminated or minimized is COS formation that may occur due to reaction of CO with sulfur formed from the Claus reaction. The objectives of this research are to formulate monolithic catalysts for removal of H{sub 2}S from coal gases and minimum formation of COS with monolithic catalyst supports, {gamma}-alumina wash or carbon coats, and catalytic metals, to develop a catalytic regeneration method for a deactivated monolithic catalyst, to measure kinetics of both direct oxidation of H{sub 2}S to elemental sulfur with SO{sub 2} as an oxidizer and formation of COS in the presence of a simulated coal gas mixture containing H{sub 2}, CO, CO{sub 2}, and moisture, using a monolithic catalyst reactor, and to develop kinetic rate equations and model the direct oxidation process to assist in the design of large-scale plants. This heterogeneous catalytic reaction has gaseous reactants such as H{sub 2}S and SO{sub 2}. However, this heterogeneous catalytic reaction has heterogeneous products such as liquid elemental sulfur and steam. Experiments on conversion of hydrogen sulfide into elemental sulfur and formation of COS were carried out for the space time range of 130-156 seconds at 120-140 C to formulate catalysts suitable for the removal of H{sub 2}S and COS from coal gases, evaluate removal capabilities of hydrogen sulfide and COS from coal gases with formulated catalysts, and develop an economic regeneration method of deactivated catalysts. Simulated coal gas mixtures consist of 3,300-3,800-ppmv hydrogen sulfide, 1,600-1,900 ppmv sulfur dioxide, 18-21 v% hydrogen, 29-34 v% CO, 8-10 v% CO{sub 2}, 5-18 vol % moisture, and nitrogen as remainder. Volumetric feed rates of a simulated coal gas mixture to the reactor are 114-132 SCCM. The temperature of the reactor is controlled in an oven at 120-140 C. The pressure of the reactor is maintained at 116-129 psia. The molar ratio of H{sub 2}S to SO{sub 2} in the monolithic catalyst reactor is

K. C. Kwon

2007-09-30T23:59:59.000Z

366

A study of toxic emissions from a coal-fired power plant: Niles Station Boiler No. 2. Volume 1, Sampling/results/special topics: Final report  

SciTech Connect (OSTI)

This study was one of a group of assessments of toxic emissions from coal-fired power plants, conducted for US Department of Energy, Pittsburgh Energy Technology Center (DOE-PETC) during 1993. The motivation for those assessments was the mandate in the 1990 Clean Air Act Amendments that a study be made of emissions of hazardous air pollutants (HAPs) from electrical utilities. The results of this study will be used by the US Environmental Protection Agency to evaluate whether regulation of HAPs emissions from utilities is warranted. This report is organized in two volumes. Volume 1: Sampling/Results/Special Topics describes the sampling effort conducted as the basis for this study, presents the concentration data on toxic chemicals in the several power plant streams, and reports the results of evaluations and calculations conducted with those data. The Special Topics section of Volume 1 reports on issues such as comparison of sampling methods and vapor/particle distributions of toxic chemicals. Volume 2: Appendices include field sampling data sheets, quality assurance results, and uncertainty calculations. The chemicals measured at Niles Boiler No. 2 were the following: five major and 16 trace elements, including mercury, chromium, cadmium, lead, selenium, arsenic, beryllium, and nickel; acids and corresponding anions (HCl, HF, chloride, fluoride, phosphate, sulfate); ammonia and cyanide; elemental carbon; radionuclides; volatile organic compounds (VOC); semivolatile compounds (SVOC) including polynuclear aromatic hydrocarbons (PAH), and polychlorinated dioxins and furans; and aldehydes.

Not Available

1994-06-01T23:59:59.000Z

367

Incorporating Both Undesirable Outputs and Uncontrollable Variables into DEA: the Performance of Chinese Coal-Fired Power Plants  

E-Print Network [OSTI]

generated by the steam turbine, and the net heat rate is based on the amount of electricity sent to the grid from a power plant. The difference between these two accounts for the electricity consumed within the power plant itself to run auxiliary... or an exponential function model, is preferable. This model is easy to use and easy to interpret, and is also capable of accommodating both continuous and categorical uncontrollable variables without increasing the number of efficient DMUs. Furthermore, it does...

Yang, Hongliang; Pollitt, Michael G.

368

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

SciTech Connect (OSTI)

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

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

2006-12-20T23:59:59.000Z

369

Healy Clean Coal Project  

SciTech Connect (OSTI)

The Healy Clean Coal Project, selected by the U.S. Department of Energy under Round 111 of the Clean Coal Technology Program, has been constructed and is currently in the Phase 111 Demonstration Testing. The project is owned and financed by the Alaska Industrial Development and Export Authority (AIDEA), and is cofunded by the U.S. Department of Energy. Construction was 100% completed in mid-November of 1997, with coal firing trials starting in early 1998. Demonstration testing and reporting of the results will take place in 1998, followed by commercial operation of the facility. The emission levels of nitrogen oxides (NOx), sulfur dioxide (S02), and particulate from this 50-megawatt plant are expected to be significantly lower than current standards.

None

1997-12-31T23:59:59.000Z

370

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

SciTech Connect (OSTI)

The objective of this research is to explore the feasibility of producing engineered fuels from a combination of renewable and non renewable energy sources. The components are flyash (containing coal fines) and locally available biomass waste. The constraints were such that no other binder additives were to be added. Listed below are the main accomplishments of the project: (1) Determination of the carbon content of the flyash sample from the Aquila plant. It was found to be around 43%. (2) Experiments were carried out using a model which simulates the press process of a wood pellet machine, i.e. a bench press machine with a close chamber, to find out the ideal ratio of wood and fly ash to be mixed to get the desired briquette. The ideal ratio was found to have 60% wood and 40% flyash. (3) The moisture content required to produce the briquettes was found to be anything below 5.8%. (4) The most suitable pressure required to extract the lignin form the wood and cause the binding of the mixture was determined to be 3000psi. At this pressure, the briquettes withstood an average of 150psi on its lateral side. (5) An energy content analysis was performed and the BTU content was determined to be approximately 8912 BTU/lb. (6) The environmental analysis was carried out and no abnormalities were noted. (7) Industrial visits were made to pellet manufacturing plants to investigate the most suitable manufacturing process for the briquettes. (8) A simulation model of extrusion process was developed to explore the possibility of using a cattle feed plant operating on extrusion process to produce briquettes. (9) Attempt to produce 2 tons of briquettes was not successful. The research team conducted a trial production run at a Feed Mill in La Junta, CO to produce two (2) tons of briquettes using the extrusion process in place. The goal was to, immediately after producing the briquettes; send them through Aquila's current system to test the ability of the briquettes to flow through the system without requiring any equipment or process changes. (10) Although the above attempt failed, the plant is still interested in producing briquettes. (11) An economic analysis of investing in a production facility manufacturing such briquettes was conducted to determine the economic viability of the project. Such a project is estimated to have an internal rate of return of 14% and net present value of about $400,000. (12) An engineering independent study class (4 students) is now working on selecting a site near the power plant and determining the layout of the future plant that will produce briquettes.

H. Carrasco; H. Sarper

2006-06-30T23:59:59.000Z

371

Evaluation of gasification and gas cleanup processes for use in molten carbonate fuel cell power plants. Final report. [Contains lists and evaluations of coal gasification and fuel gas desulfurization processes  

SciTech Connect (OSTI)

This report satisfies the requirements for DOE Contract AC21-81MC16220 to: List coal gasifiers and gas cleanup systems suitable for supplying fuel to molten carbonate fuel cells (MCFC) in industrial and utility power plants; extensively characterize those coal gas cleanup systems rejected by DOE's MCFC contractors for their power plant systems by virtue of the resources required for those systems to be commercially developed; develop an analytical model to predict MCFC tolerance for particulates on the anode (fuel gas) side of the MCFC; develop an analytical model to predict MCFC anode side tolerance for chemical species, including sulfides, halogens, and trace heavy metals; choose from the candidate gasifier/cleanup systems those most suitable for MCFC-based power plants; choose a reference wet cleanup system; provide parametric analyses of the coal gasifiers and gas cleanup systems when integrated into a power plant incorporating MCFC units with suitable gas expansion turbines, steam turbines, heat exchangers, and heat recovery steam generators, using the Westinghouse proprietary AHEAD computer model; provide efficiency, investment, cost of electricity, operability, and environmental effect rankings of the system; and provide a final report incorporating the results of all of the above tasks. Section 7 of this final report provides general conclusions.

Jablonski, G.; Hamm, J.R.; Alvin, M.A.; Wenglarz, R.A.; Patel, P.

1982-01-01T23:59:59.000Z

372

Clean coal technology. Coal utilisation by-products  

SciTech Connect (OSTI)

The need to remove the bulk of ash contained in flue gas from coal-fired power plants coupled with increasingly strict environmental regulations in the USA result in increased generation of solid materials referred to as coal utilisation by-products, or CUBs. More than 40% of CUBs were sold or reused in the USA in 2004 compared to less than 25% in 1996. A goal of 50% utilization has been established for 2010. The American Coal Ash Association (ACCA) together with the US Department of Energy's Power Plant Improvement Initiative (PPPI) and Clean Coal Power Initiative (CCPI) sponsor a number of projects that promote CUB utilization. Several are mentioned in this report. Report sections are: Executive summary; Introduction; Where do CUBs come from?; Market analysis; DOE-sponsored CUB demonstrations; Examples of best-practice utilization of CUB materials; Factors limiting the use of CUBs; and Conclusions. 14 refs., 1 fig., 5 tabs., 14 photos.

NONE

2006-08-15T23:59:59.000Z

373

Coal extraction  

SciTech Connect (OSTI)

Coal is extracted using a mixed solvent which includes a substantially aromatic component and a substantially naphthenic component, at a temperature of 400/sup 0/ to 500/sup 0/C. Although neither component is an especially good solvent for coal by itself, the use of mixed solvent gives greater flexibility to the process and offers efficiency gains.

Clarke, J.W.; Kimber, G.M.; Rantell, T.D.; Snape, C.E.

1985-06-04T23:59:59.000Z

374

COAL SLAGGING AND REACTIVITY TESTING  

SciTech Connect (OSTI)

Union Fenosa's La Robla I Power Station is a 270-MW Foster Wheeler arch-fired system. The unit is located at the mine that provides a portion of the semianthracitic coal. The remaining coals used are from South Africa, Russia, Australia, and China. The challenges at the La Robla I Station stem from the various fuels used, the characteristics of which differ from the design coal. The University of North Dakota Energy & Environmental Research Center (EERC) and the Lehigh University Energy Research Center (LUERC) undertook a program to assess problematic slagging and unburned carbon issues occurring at the plant. Full-scale combustion tests were performed under baseline conditions, with elevated oxygen level and with redistribution of air during a site visit at the plant. During these tests, operating information, observations and temperature measurements, and coal, slag deposit, and fly ash samples were obtained to assess slagging and unburned carbon. The slagging in almost all cases appeared due to elevated temperatures rather than fuel chemistry. The most severe slagging occurred when the temperature at the sampling port was in excess of 1500 C, with problematic slagging where first-observed temperatures exceeded 1350 C. The presence of anorthite crystals in the bulk of the deposits analyzed indicates that the temperatures were in excess of 1350 C, consistent with temperature measurements during the sampling period. Elevated temperatures and ''hot spots'' are probably the result of poor mill performance, and a poor distribution of the coal from the mills to the specific burners causes elevated temperatures in the regions where the slag samples were extracted. A contributing cause appeared to be poor combustion air mixing and heating, resulting in oxygen stratification and increased temperatures in certain areas. Air preheater plugging was observed and reduces the temperature of the air in the windbox, which leads to poor combustion conditions, resulting in unburned carbon as well as slagging. A second phase of the project involved advanced analysis of the baseline coal along with an Australian coal fired at the plant. These analysis results were used in equilibrium thermodynamic modeling along with a coal quality model developed by the EERC to assess slagging, fouling, and opacity for the coals. Bench-scale carbon conversion testing was performed in a drop-tube furnace to assess the reactivity of the coals. The Australian coal had a higher mineral content with significantly more clay minerals present than the baseline coal. The presence of these clay minerals, which tend to melt at relatively low temperatures, indicated a higher potential for problematic slagging than the baseline coal. However, the pyritic minerals, comprising over 25% of the baseline mineral content, may form sticky iron sulfides, leading to severe slagging in the burner region if local areas with reducing conditions exist. Modeling results indicated that neither would present significant fouling problems. The Australian coal was expected to show slagging behavior much more severe than the baseline coal except at very high furnace temperatures. However, the baseline coal was predicted to exhibit opacity problems, as well as have a higher potential for problematic calcium sulfate-based low-temperature fouling. The baseline coal had a somewhat higher reactivity than the Australian coal, which was consistent with both the lower average activation energy for the baseline coal and the greater carbon conversion at a given temperature and residence time. The activation energy of the baseline coal showed some effect of oxygen on the activation energy, with E{sub a} increasing at the lower oxygen concentration, but may be due to the scatter in the baseline coal kinetic values at the higher oxygen level tested.

Donald P. McCollor; Kurt E. Eylands; Jason D. Laumb

2003-10-01T23:59:59.000Z

375

Evaluation of the Emission, Transport, and Deposition of Mercury, Fine Particulate Matter, and Arsenic from Coal-Based Power Plants in the Ohio River Valley Region  

SciTech Connect (OSTI)

Ohio University, in collaboration with CONSOL Energy, Advanced Technology Systems, Inc (ATS) and Atmospheric and Environmental Research, Inc. (AER) as subcontractors, is evaluating the impact of emissions from coal-fired power plants in the Ohio River Valley region as they relate to the transport and deposition of mercury, arsenic, and associated fine particulate matter. This evaluation will involve two interrelated areas of effort: ambient air monitoring and regional-scale modeling analysis. The scope of work for the ambient air monitoring will include the deployment of a surface air monitoring (SAM) station in southeastern Ohio. The SAM station will contain sampling equipment to collect and measure mercury (including speciated forms of mercury and wet and dry deposited mercury), arsenic, particulate matter (PM) mass, PM composition, and gaseous criteria pollutants (CO, NOx, SO{sub 2}, O{sub 3}, etc.). Laboratory analysis of time-integrated samples will be used to obtain chemical speciation of ambient PM composition and mercury in precipitation. Near-real-time measurements will be used to measure the ambient concentrations of PM mass and all gaseous species including Hg{sup 0} and RGM. Approximately of 18 months of field data will be collected at the SAM site to validate the proposed regional model simulations for episodic and seasonal model runs. The ambient air quality data will also provide mercury, arsenic, and fine particulate matter data that can be used by Ohio Valley industries to assess performance on multi-pollutant control systems. The scope of work for the modeling analysis will include (1) development of updated inventories of mercury and arsenic emissions from coal plants and other important sources in the modeled domain; (2) adapting an existing 3-D atmospheric chemical transport model to incorporate recent advancements in the understanding of mercury transformations in the atmosphere; (3) analyses of the flux of Hg0, RGM, arsenic, and fine particulate matter in the different sectors of the study region to identify key transport mechanisms; (4) comparison of cross correlations between species from the model results to observations in order to evaluate characteristics of specific air masses associated with long-range transport from a specified source region; and (5) evaluation of the sensitivity of these correlations to emissions from regions along the transport path. This will be accomplished by multiple model runs with emissions simulations switched on and off from the various source regions. To the greatest extent possible, model results will also be compared to field data collected at other air monitoring sites in the Ohio Valley region, operated independently of this project. These sites may include (1) the DOE National Energy Technologies Laboratory's monitoring site at its suburban Pittsburgh, PA facility; (2) sites in Pittsburgh (Lawrenceville) PA and Holbrook, PA operated by ATS; (3) sites in Steubenville, OH and Pittsburgh, PA operated by U.S. EPA and/or its contractors; and (4) sites operated by State or local air regulatory agencies. Field verification of model results and predictions will provide critical information for the development of cost effective air pollution control strategies by the coal-fired power plants in the Ohio River Valley region.

Kevin Crist

2005-10-02T23:59:59.000Z

376

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

SciTech Connect (OSTI)

The overall goal of this project, as originally proposed, was to optimize the formulation of a novel solvent as a critical enabler for the cost-effective, energy-efficient, environmentally-friendly capture of CO{sub 2} at coal-fired utility plants. Aqueous blends of concentrated piperazine (PZ) with other compounds had been shown to exhibit high rates of CO{sub 2} absorption, low regeneration energy, and other desirable performance characteristics during an earlier 5-year development program conducted by B&W. The specific objective of this project was to identify PZ-based solvent formulations that globally optimize the performance of coal-fired power plants equipped with CO{sub 2} scrubbing systems. While previous solvent development studies have tended to focus on energy consumption and absorber size, important issues to be sure, the current work seeks to explore, understand, and optimize solvent formulation across the full gamut of issues related to commercial application of the technology: capital and operating costs, operability, reliability, environmental, health and safety (EH&S), etc. Work on the project was intended to be performed under four budget periods. The objective of the work in the first budget period has been to identify several candidate formulations of a concentrated PZ-based solvent for detailed characterization and evaluation. Work in the second budget period would generate reliable and comprehensive property and performance data for the identified formulations. Work in the third budget period would quantify the expected performance of the selected formulations in a commercial CO{sub 2} scrubbing process. Finally, work in the fourth budget period would provide a final technology feasibility study and a preliminary technology EH&S assessment. Due to other business priorities, however, B&W has requested that this project be terminated at the end of the first budget period. This document therefore serves as the final report for this project. It is the first volume of the two-volume final report and summarizes Budget Period 1 accomplishments under Tasks 1-5 of the project, including the selection of four solvent formulations for further study.

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

2014-04-30T23:59:59.000Z

377

Quarterly Coal Report, July--September 1994  

SciTech Connect (OSTI)

The Quarterly Coal Report (QCR) provides comprehensive information about US coal production, distribution, exports, imports, receipts, prices, consumption, and stocks to a wide audience, including Congress, Federal and State agencies, the coal industry, and the general public. Coke production, consumption, distribution, imports, and exports data are also provided. This report presents detailed quarterly data for July through September 1994 and aggregated quarterly historical data for 1986 through the second quarter of 1994. Appendix A displays, from 1986 on, detailed quarterly historical coal imports data, as specified in Section 202 of the Energy Policy and Conservation Amendments Act of 1985 (Public Law 99-58). Appendix B gives selected quarterly tables converted to metric tons. To provide a complete picture of coal supply and demand in the United States, historical information has been integrated in this report. Additional historical data can also be found in the following EIA publications : Annual Energy Review 1993 (DOE/EIA-0384(93)), Monthly Energy Review (DOE/EIA-0035), and Coal Data: A Reference (DOE/EIA-0064(90)). The historical data in this report are collected by the EIA in three quarterly coal surveys (coal consumption at manufacturing plants, coal distribution, and coal consumption at coke plants), one annual coal production survey, and two monthly surveys of electric utilities. All data shown for 1993 and previous years are final. Data for 1994 are preliminary.

Not Available

1995-02-01T23:59:59.000Z

378

Implications of near-term coal power plant retirement for SO2 and NOX, and life cycle GHG emissions  

E-Print Network [OSTI]

prices of electricity production Plant type Unit Price Nuclear ($/MWh) 16.51 Wind ($/MWh) 201 Hydro Top SO2 100 430 95 440 100 430 Top NOX 105 350 100 380 105 345 Small, inefficient 125 410 125 405 125) Manitoba Hydro Manitoba Hydro Undertaking # 57 http://www.pub.gov.mb.ca/exhibits/mh-83.pdf. (5) Sotkiewicz

Jaramillo, Paulina

379

Wabash River Coal Gasification Repowering Project: A DOE Assessment  

SciTech Connect (OSTI)

The goal of the U.S. Department of Energy (DOE) Clean Coal Technology Program (CCT) 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 (PPA) of a project selected in CCT Round IV, the Wabash River Coal Gasification Repowering (WRCGR) Project, as described in a Report to Congress (U.S. Department of Energy 1992). Repowering consists of replacing an existing coal-fired boiler with one or more clean coal technologies to achieve significantly improved environmental performance. The desire to demonstrate utility repowering with a two-stage, pressurized, oxygen-blown, entrained-flow, integrated gasification combined-cycle (IGCC) system prompted Destec Energy, Inc., and PSI Energy, Inc., to form a joint venture and submit a proposal for this project. In July 1992, the Wabash River Coal Gasification Repowering Project Joint Venture (WRCGRPJV, the Participant) entered into a cooperative agreement with DOE to conduct this project. The project was sited at PSI Energy's Wabash River Generating Station, located in West Terre Haute, Indiana. The purpose of this CCT project was to demonstrate IGCC repowering using a Destec gasifier and to assess long-term reliability, availability, and maintainability of the system at a fully commercial scale. DOE provided 50 percent of the total project funding (for capital and operating costs during the demonstration period) of $438 million. Construction for the demonstration project was started in July 1993. Pre-operational tests were initiated in August 1995, and construction was completed in November 1995. Commercial operation began in November 1995, and the demonstration period was completed in December 1999. The independent evaluation contained herein is based primarily on information provided in Wabash's Final Report (Dowd 2000), as well as other references and bibliographic sources.

National Energy Technology Laboratory

2002-01-15T23:59:59.000Z

380

Mortality and cancer experience of Quebec aluminum reduction plant workers. Part I: The reduction plants and coal tar pitch volatile (CTPV) exposure assessment  

SciTech Connect (OSTI)

This paper presents the exposure assessment and job-exposure matrix (JEM) used to estimate coal tar pitch volatile (CTPV) exposure for a study of mortality and cancer incidence in aluminum smelter workers in Quebec, Canada. Historical CTPV exposure was assessed by estimating benzene-soluble material (BSM) and benzo(a)pyrene (B(a)P) levels for combinations of job and time period. Estimates were derived by using several procedures including averaging measurement data, a deterministic mathematical model using process-related correction factors, and expert-based extrapolation. The JEM comprised 28,910 jobs, covering 7 facilities from 1916 to 1999. Estimated exposures ranged from 0.01 {mu} g/m{sup 3} to 68.08 {mu} g/m{sup 3} (B(a)P) and 0.01 mg/m{sup 3} to 3.64 mg/m{sup 3} (BSW) and were lowest before 1940 and after 1980. This methodology constitutes an improvement compared with methods used for previous studies of the Quebec cohort.

Lavoue, J.; Gerin, M.; Cote, J.; Lapointe, R. [University of Montreal, Montreal, PQ (Canada)

2007-09-15T23:59:59.000Z

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