Powered by Deep Web Technologies
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.


1

CoalFleet RD&D Augmentation Plan for Integrated Gasification Combined Cycle (IGCC) Power Plants  

Science Conference Proceedings (OSTI)

Advanced, clean coal technologies such as integrated gasification combined cycle (IGCC) offer societies around the world the promise of efficient, affordable power generation at markedly reduced levels of emissions8212including "greenhouse gases" linked to global climate change8212relative to today's current fleet of coal-fired power plants. To help accelerate the development, demonstration, and market introduction of IGCC and other clean coal technologies, EPRI formed the CoalFleet for Tomorrow initiati...

2007-01-24T23:59:59.000Z

2

CoalFleet IGCC Permitting Guidelines  

Science Conference Proceedings (OSTI)

This report provides guidance to owners of planned Integrated Gasification Combined Cycle (IGCC) power plants in order to assist them in permitting these advanced coal power generation facilities. The CoalFleet IGCC Permitting Guidelines summarize U.S. federal requirements for obtaining air, water, and solid waste permits for a generic IGCC facility, as described in EPRI report 1012227, the CoalFleet User Design Basis Specification (UDBS). The Guidelines present characteristics of IGCC emissions that mus...

2006-11-16T23:59:59.000Z

3

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

SciTech Connect

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.

2007-01-15T23:59:59.000Z

4

CoalFleet User Design Basis Specification for Coal-Based Integrated Gasification Combined Cycle (IGCC) Power Plants  

Science Conference Proceedings (OSTI)

The Duke Edwardsport integrated gasification combined-cycle (IGCC) power plant started up in 2012, and Mississippi Power’s Kemper County IGCC plant is in construction. The capital cost of these initial commercial scale IGCC plants is high. The industry needs specifications that encourage greater standardization in IGCC design in order to bring down the investment cost for the next generation of plants. Standardization also supports repeatable, reliable performance and reduces the time and cost ...

2012-12-12T23:59:59.000Z

5

Coal Fleet Integrated Gasification Combined Cycle (IGCC Permitting) Guidelines  

Science Conference Proceedings (OSTI)

This report provides guidance to owners of planned Integrated Gasification Combined Cycle (IGCC) power plants in order to assist them in permitting these advanced coal power generation facilities. The CoalFleet IGCC Permitting Guidelines summarize U.S. federal requirements for obtaining air, water, and solid waste permits for a generic IGCC facility, as described in the CoalFleet User Design Basis Specification (UDBS). The report presents characteristics of IGCC emissions that must be considered in the p...

2006-03-14T23:59:59.000Z

6

Mercury Fate in IGCC Power Plants  

Science Conference Proceedings (OSTI)

Integrated Gasification Combined Cycle (IGCC) power plants are an alternative to conventional pulverized coal boilers. In an IGCC facility, coal or other feedstocks are converted to synthetic gas (syngas) at high temperature and pressure. The syngas can be used to produce electrical power in a combined cycle combustion turbine. One of the advantages of IGCC technology is that contaminants can be removed from the syngas prior to combustion, reducing the volume of gas that must be treated and leading to lo...

2006-12-21T23:59:59.000Z

7

Impact of coal quality and gasifier technology on IGCC performance  

E-Print Network (OSTI)

1 Impact of coal quality and gasifier technology on IGCC performance Ola Maurstad1 *, Howard Herzog 02139, USA Abstract Integrated coal gasification combined cycle (IGCC) plants withpre different coals were used and alternatives with and without CO2 capture calculated. It was found

8

Design optimization of IGCC power plants  

SciTech Connect

Integrated gasification-combined-cycle (IGCC) power plants have the potential for providing performance and cost improvements over conventional coal-fired steam power plants with flue-gas desulfurization. The major design options for IGCC power plants include the following: oxygen-blown versus air-blown gasification processes; entrained-flow, fluidized-bed, or fixed-bed gasifier; coal-slurry feed versus coal-dry feed; hot versus cold fuel-gas cleanup; gas turbine alternatives; and, design alternatives for the Heat Recovery Steam Generator (HRSG). This paper summarizes some results from these studies. The advanced thermoelectric techniques used at Tennessee Technological University (TTU) are very powerful tools for evaluating and optimizing IGCC power plants.

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

1992-01-01T23:59:59.000Z

9

CoalFleet Advanced Combustion IGCC Permits Database  

Science Conference Proceedings (OSTI)

The CoalFleet Advanced Combustion IGCC Permits Database presents comprehensive information on permitting requirements and permit conditions for Integrated Gasification Combined Cycle (IGCC) power plants in an online database format. This Technical Update is a compilation of the Database contents as of March 31, 2008.

2008-04-11T23:59:59.000Z

10

Program on Technology Innovation: Drying of Low-Rank Coal with Supercritical Carbon Dioxide (CO2) in Integrated Gasification Combined Cycle (IGCC) Plants  

Science Conference Proceedings (OSTI)

This study is part of the Electric Power Research Institute (EPRI) Technology Innovation Program to assess the potential to achieve increased process efficiency and reduced capital cost by drying low-rank coal with supercritical carbon dioxide (SCCO2). This study follows the EPRI report Program on Technology Innovation: Assessment of the Applicability of Drying Low-Rank Coal With Supercritical Carbon Dioxide in IGCC Plants (1016216), which concluded that this system has potential benefits with respect to...

2010-07-30T23:59:59.000Z

11

COST OF MERCURY REMOVAL IN IGCC PLANTS  

NLE Websites -- All DOE Office Websites (Extended Search)

Cost of Mercury Removal Cost of Mercury Removal in an IGCC Plant Final Report September 2002 Prepared for: The United States Department of Energy National Energy Technology Laboratory By: Parsons Infrastructure and Technology Group Inc. Reading, Pennsylvania Pittsburgh, Pennsylvania DOE Product Manager: Gary J. Stiegel DOE Task Manager: James R. Longanbach Principal Investigators: Michael G. Klett Russell C. Maxwell Michael D. Rutkowski PARSONS The Cost of Mercury Removal in an IGCC Plant Final Report i September 2002 TABLE OF CONTENTS Section Title Page 1 Summary 1 2 Introduction 3 3 Background 4 3.1 Regulatory Initiatives 4 3.2 Mercury Removal for Conventional Coal-Fired Plants 4 3.3 Mercury Removal Experience in Gasification 5 3.4 Variability of Mercury Content in Coal 6 4 Design Considerations 7 4.1 Carbon Bed Location

12

Dynamic Simulation and Training for IGCC Power Plants  

SciTech Connect

Integrated Gasification Combined Cycle (IGCC) is emerging as the technology of choice for providing clean, low-cost electricity for the next generation of coal-fired power plants and will play a central role in the development of high-efficiency, zero-emissions power plants such as FutureGen. Several major utilities and developers recently announced plans to build IGCC plants and other major utilities are evaluating IGCC’s suitability for base-load capacity additions. This recent surge of attention to IGCC power generation is creating a growing demand for experience with the analysis, operation, and control of commercial-scale IGCC plants. To meet this need, the National Energy Technology Laboratory (NETL) has launched a project to develop a generic, full-scope, IGCC dynamic plant simulator for use in establishing a state-of-the-art simulator training center at West Virginia University’s (WVU) National Research Center for Coal and Energy (NRCCE). The IGCC Dynamic Simulator & Training (DS&T) Center will be established under the auspices of the Collaboratory for Process & Dynamic Systems Modeling (“Collaboratory”) organized between NETL, WVU, the University of Pittsburgh, and Carnegie Mellon University.

Erbes, M.R. (Enginomix, LLC); Zitney, S.E

2006-09-01T23:59:59.000Z

13

IGCC demonstration plant at Nakoso Power Station, Japan  

Science Conference Proceedings (OSTI)

The 250 MW IGCC demonstration plant at Nakoso Power Station is based on technology form Mitsubishi Heavy Industries (MHI) Ltd that uses a pressurized, air blown, two-stage, entrained-bed coal gasifier with a dry coal feed system. 5 figs., 1 tab.

Peltier, R.

2007-10-15T23:59:59.000Z

14

Mesaba next-generation IGCC plant  

Science Conference Proceedings (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

15

Refinery IGCC plants are exceeding 90% capacity factor after 3 years  

SciTech Connect

Steep learning curves for commercial IGCC plants in Italy show annual capacity factors of 55-60% in the first year of service and improvement to over 90% after the third year. The article reviews the success of three IGCC projects in Italy - those of ISAB Energy, Sarlux Saras and Api Energy. EniPower is commissioning a 250 MW IGCC plant that will burn syngas produced by gasification of residues at an adjacent Eni Sannazzaro refinery in north central Italy. The article lists 14 commercially operating IGCC plants worldwide that together provide close to 3900 MW of generating capacity. These use a variety of feedstock-coals, petroleum coke and refinery residues and biomass. Experience with commercial scale plants in Europe demonstrates that IGCC plants can operate at capacity factors comparable to if not better than conventional coal plants. 2 figs., 1 photo.

Jaeger, H.

2006-01-15T23:59:59.000Z

16

Air permitting of IGCC plants  

SciTech Connect

The IGCC process is, currently, the preferred choice over conventional thermal power production in regard to cleanup of fuel and significantly reduced contaminant emissions. The air permitting requirements include the review of: feed preparation and PM emissions; feed gasification and contaminant emissions; elemental sulfur recovery and SO{sub 2} emissions; options for carbon-dioxide recovery; syngas characteristics for combustion; CT design and combustion mechanisms; air contaminant emissions of CT; controlled CT emissions of nitrogen-oxides and carbon-monoxide gases using the SCR and oxidation catalysts, respectively; and, emission of volatile organic compounds (VOCs), and hazardous air pollutants (HAPs). However, the IGCC processes are being rigorously reviewed for the system integration and reliability, and significant reduction of air contaminant emissions (including the greenhouse gases). This paper included a review of IGCC air contaminant emission rates, and various applicable regulatory requirements, such as NSR (New Source Review), NSPS (New Source Performance Standards), and MACT (Maximum Achievable Control Technology). The IGCC facility's NOX, CO, SO{sub 2}, PM, VOCs, and HAPs emission rates would be significantly low. Thus, effective, construction and installation, and operation air permits would be necessary for IGCC facilities.

Chitikela, S.R.

2007-07-01T23:59:59.000Z

17

Demonstration plant for IGCC using the U-GAS process  

SciTech Connect

Tampella, Ltd., in cooperation with the Institute of Gas Technology (IGT), is developing the gasification technology for U-GAS{reg_sign} to produce electricity from coal using the integrated gasification combined-cycle (IGCC). The concept of IGCC is to join the clean burning gasification island with a more efficient gas and stream turbine island to produce electric power with minimal environmental impact. IGT has developed the U-GAS process to produce a low- or medium-Btu gas from different types of coal feedstocks. The process uses a combination of fluidized=bed gasification and ash agglomeration in a single-stage reactor. A 30-tons/day-capacity pilot plant located in Chicago has been used to develop the process. Feedstocks ranging from relatively unreactive metallurgical coke to highly reactive peat have been gasified successfully in the this pilot plant, indicating its ability to handle a feedstock with widely varying properties. A new 10 megawatt pilot plant has been designed and is under construction in Tampere, Finland, as the first step toward the commercialization of this technology. Tampella is planning to design and deliver a commercial-scale IGCC demonstration plant by 1994. 7 refs., 5 figs.

Lau, F.S. [Institute of Gas Technology, Chicago, IL (United States); Salo, K. [Tampella Power, Tampere (Finland)

1991-12-01T23:59:59.000Z

18

Hydrogen Production from Hydrogen Sulfide in IGCC Power Plants  

SciTech Connect

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

19

Evaluation of Alternative IGCC Plant Designs for High Availability and Near Zero Emissions  

Science Conference Proceedings (OSTI)

This report examines the historical reliability and availability data of solids-fed integrated gasification combined cycle (IGCC) power plants and describes how these data can be used to analyze design options meant to improve the availability of new IGCCs. It also looks at the technical and economic impacts of adding a Selective Catalytical Reduction (SCR) system to an IGCC. Adding an SCR will result in a coal-based power plant with an emissions profile that is very close to a natural gas fired combined...

2005-12-20T23:59:59.000Z

20

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

SciTech Connect

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

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

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

DOE Green Energy (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

22

Technology qualification for IGCC power plant with CO2 Capture.  

E-Print Network (OSTI)

?? Summary:This thesis presents the technology qualification plan for the integrated gasification combined cycle power plant (IGCC) with carbon dioxide capture based on DNV recommendations.… (more)

Baig, Yasir

2011-01-01T23:59:59.000Z

23

DOE, RTI to Design and Build Gas Cleanup System for IGCC Power Plants |  

Energy.gov (U.S. Department of Energy (DOE)) Indexed Site

DOE, RTI to Design and Build Gas Cleanup System for IGCC Power DOE, RTI to Design and Build Gas Cleanup System for IGCC Power Plants DOE, RTI to Design and Build Gas Cleanup System for IGCC Power Plants July 13, 2009 - 1:00pm Addthis Washington, DC - The U.S. Department of Energy (DOE) announces a collaborative project with Research Triangle Institute (RTI) International to design, build, and test a warm gas cleanup system to remove multiple contaminants from coal-derived syngas. The 50-MWe system will include technologies to remove trace elements such as mercury and arsenic, capture the greenhouse gas carbon dioxide (CO2), and extract more than 99.9 percent of the sulfur from the syngas. A novel process to convert the extracted sulfur to a pure elemental sulfur product will also be tested. This project supports DOE's vision of coal power plants with near-zero

24

DOE, RTI to Design and Build Gas Cleanup System for IGCC Power Plants |  

Energy.gov (U.S. Department of Energy (DOE)) Indexed Site

DOE, RTI to Design and Build Gas Cleanup System for IGCC Power DOE, RTI to Design and Build Gas Cleanup System for IGCC Power Plants DOE, RTI to Design and Build Gas Cleanup System for IGCC Power Plants July 13, 2009 - 1:00pm Addthis Washington, DC - The U.S. Department of Energy (DOE) announces a collaborative project with Research Triangle Institute (RTI) International to design, build, and test a warm gas cleanup system to remove multiple contaminants from coal-derived syngas. The 50-MWe system will include technologies to remove trace elements such as mercury and arsenic, capture the greenhouse gas carbon dioxide (CO2), and extract more than 99.9 percent of the sulfur from the syngas. A novel process to convert the extracted sulfur to a pure elemental sulfur product will also be tested. This project supports DOE's vision of coal power plants with near-zero

25

IGCC vision  

SciTech Connect

In an Integrated Gasification Combined Cycle (IGCC), fuel gas, which is composed of hydrogen and carbon oxides, is generated in a gasifier by coal reacting with steam and air or oxygen. The pressurized fuel gas is then cleaned and fed to a high-efficiency combustion gas turbine to generate power. The hot exhaust gas from the gas turbine produces steam to drive a steam turbine to make additional power. Integration of the inherent advantages of coal gasification and combined cycles results in an ultra high-efficiency, super-clean, low-cost power plant. IGCC plants being demonstrated can achieve efficiencies of 42% (HHV) and with continuous improvements over the next 15 to 20 years, 52% efficiency is achievable. When compared to existing coal plants with flue gas desulfurization, which have efficiencies of about 34%, IGCC reduces by 35% the CO{sub 2} emission because less coal is required to generate an equivalent power. Commercialization of IGCC will result in low-cost power from coal without environmental compromise. These features are crucial to US competitiveness in the world.marketplace. Preservation and creation of jobs will depend on a strong mining and manufacturing sector enhanced by export markets for coal and power generation equipment.

1993-05-01T23:59:59.000Z

26

Could IGCC swing  

SciTech Connect

A few big-name utilities are looking to make big-time power from gasified coal. AEP has utility-scale integrated gasification combined cycle (IGCC) plants in the works for Ohio and West Virginia. Duke Energy Indiana plans to build a 630 MW IGCC plant at Edwardsport to replace the existing 160 MW coal-fired unit there. NRG hopes to build utility-scale IGCC plants in New York and Delaware. Tampa Electric has announced plans to build a 630 MW IGCC at its Polk site, already the location of a 260 MW IGCC. In Taylorville, IL, another power-oriented IGCC is under development, owned by individuals from original developer ERORA and Omaha-based Tenaska. And yet another power producing IGCC is being proposed by Tondu Corporation at Corpus Christi, Texas to be fired by petroleum coke, also known as petcoke. The article gives an overview of these developments and moves on to discuss the popular question of the economic viability of IGCC making marketable byproducts in addition to power. Several projects are under way to make synthetic natural gas for coal. These are reported. Although the versatility of gasification may well give the ability to swing from various levels of power production to various levels of co-producing one or more products, for the time being it appears the IGCCs being built will produce power only, along with elemental sulphur and slag.

Blankinship, S.

2007-06-15T23:59:59.000Z

27

Coalfleet IGCC Permits Database  

Science Conference Proceedings (OSTI)

The CoalFleet IGCC Permits Database presents comprehensive information on permitting requirements and permit conditions for Integrated Gasification Combined Cycle (IGCC) power plants in an online database format. This Technical Update is a compilation of the Database contents as of April 1, 2009.

2009-05-01T23:59:59.000Z

28

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

Science Conference Proceedings (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

29

Advanced CO2 Capture Technology for Low Rank Coal Integrated Gasification Combined Cycle (IGCC) Systems  

NLE Websites -- All DOE Office Websites (Extended Search)

CO CO 2 Capture Technology for Low Rank Coal Integrated Gasification Combined Cycle (IGCC) Systems Background Gasification of coal or other solid feedstocks (wood waste, petroleum coke, etc.) is a clean way to produce electricity and produce or co-produce a variety of commercial products. The major challenge is cost reduction; current integrated gasification combined cycle (IGCC) technology is estimated to produce power at a cost higher than that of pulverized coal combustion. However, the Gasification

30

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

NLE Websites -- All DOE Office Websites (Extended Search)

Optimal Sensor Network Optimal Sensor Network Design for Condition Monitoring in an IGCC Plant Background The U.S. Department of Energy's National Energy Technology Laboratory (NETL) develops affordable and clean energy from coal and other fossil fuels to secure a sustainable energy economy. To further this mission, NETL funds research and development of advanced sensor and control technologies that can function under the extreme operating conditions often found in advanced power systems,

31

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

32

Optimal control system design for IGCC power plants with CO2 capture  

Science Conference Proceedings (OSTI)

Designing an optimal control system for an integrated gasification combined cycle (IGCC) power plant with CO2 capture addresses the challenge of efficiently operating and controlling a coal-fed IGCC plant with the desired extent of CO2 capture in the face of disturbances without violating operational and environmental constraints. The control system design needs to optimize a desired scalar objective function while satisfying all the operational and environmental constraints in the presence of measured and unmeasured disturbances. Various objective functions can be considered for the control system design such as maximization of profit, maximization of the power produced, or minimization of the auxiliary power. The design of such a control system makes the plant suitable to play an active role in the smart grid era as the plant will have the required agility. In addition, other penalty function(s) such as emission penalties for CO2 or other criteria pollutants can be considered in the framework as well as losses associated with any hydrogen or carbon monoxide loses. The proposed control system design is performed in two stages. In the first stage, a top-down analysis is performed to generate a list of controlled, manipulated, and disturbance variables considering a scalar operational objective and other process constraints. In the second stage, a bottom-up approach for simultaneous design of the control structure and the controllers is used. In this paper, the first stage of the two-stage approach is applied to the IGCC’s acid gas removal (AGR) process which removes both H2S and CO2 from the shifted synthesis gas. While these results are still preliminary, they demonstrate the application of the proposed approach for a commercial-scale plant and show some interesting results related to controlled variable selection. Such an approach can be followed not only to design control systems for new power plants, but also to retrofit control systems for existing plants with suitable modifications.

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

2012-01-01T23:59:59.000Z

33

The role of IGCC in USDOE clean coal research, development and demonstration  

SciTech Connect

For many years, the US Department of Energy (DOE) has been funding research, development, and demonstration (RD&D) projects to develop advanced power generation technologies. The goal of this RD&D is private sector commercialization of technologies that will provide reasonably priced electricity and still meet stringent environmental standards. Integrated Gasification Combined-Cycle (IGCC) systems are emerging as one of the more attractive candidate technologies to meet this goal. The Morgantown Energy Technology Center (METC) has been assigned the responsibility for implementing IGCC projects in DOE`s Clean Coal RD&D program. Projects related to IGCC are briefly described.

Schmidt, D.K.; Rath, L.K.

1993-09-01T23:59:59.000Z

34

Development of a plant-wide dynamic model of an integrated gasification combined cycle (IGCC) plant  

Science Conference Proceedings (OSTI)

In this presentation, development of a plant-wide dynamic model of an advanced Integrated Gasification Combined Cycle (IGCC) plant with CO2 capture will be discussed. The IGCC reference plant generates 640 MWe of net power using Illinois No.6 coal as the feed. The plant includes an entrained, downflow, General Electric Energy (GEE) gasifier with a radiant syngas cooler (RSC), a two-stage water gas shift (WGS) conversion process, and two advanced 'F' class combustion turbines partially integrated with an elevated-pressure air separation unit (ASU). A subcritical steam cycle is considered for heat recovery steam generation. Syngas is selectively cleaned by a SELEXOL acid gas removal (AGR) process. Sulfur is recovered using a two-train Claus unit with tail gas recycle to the AGR. A multistage intercooled compressor is used for compressing CO2 to the pressure required for sequestration. Using Illinois No.6 coal, the reference plant generates 640 MWe of net power. The plant-wide steady-state and dynamic IGCC simulations have been generated using the Aspen Plus{reg_sign} and Aspen Plus Dynamics{reg_sign} process simulators, respectively. The model is generated based on the Case 2 IGCC configuration detailed in the study available in the NETL website1. The GEE gasifier is represented with a restricted equilibrium reactor model where the temperature approach to equilibrium for individual reactions can be modified based on the experimental data. In this radiant-only configuration, the syngas from the Radiant Syngas Cooler (RSC) is quenched in a scrubber. The blackwater from the scrubber bottom is further cleaned in the blackwater treatment plant. The cleaned water is returned back to the scrubber and also used for slurry preparation. The acid gas from the sour water stripper (SWS) is sent to the Claus plant. The syngas from the scrubber passes through a sour shift process. The WGS reactors are modeled as adiabatic plug flow reactors with rigorous kinetics based on the mid-life activity of the shift-catalyst. The SELEXOL unit consists of the H2S and CO2 absorbers that are designed to meet the stringent environmental limits and requirements of other associated units. The model also considers the stripper for recovering H2S that is sent as a feed to a split-flow Claus unit. The tail gas from the Claus unit is recycled to the SELEXOL unit. The cleaned syngas is sent to the GE 7FB gas turbine. This turbine is modeled as per published data in the literature. Diluent N2 is used from the elevated-pressure ASU for reducing the NOx formation. The heat recovery steam generator (HRSG) is modeled by considering generation of high-pressure, intermediate-pressure, and low-pressure steam. All of the vessels, reactors, heat exchangers, and the columns have been sized. The basic IGCC process control structure has been synthesized by standard guidelines and existing practices. The steady-state simulation is solved in sequential-modular mode in Aspen Plus{reg_sign} and consists of more than 300 unit operations, 33 design specs, and 16 calculator blocks. The equation-oriented dynamic simulation consists of more than 100,000 equations solved using a multi-step Gear's integrator in Aspen Plus Dynamics{reg_sign}. The challenges faced in solving the dynamic model and key transient results from this dynamic model will also be discussed.

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

2009-01-01T23:59:59.000Z

35

A High Pressure Carbon Dioxide Separation Process for IGCC Plants  

NLE Websites -- All DOE Office Websites (Extended Search)

High Pressure Carbon Dioxide Separation Process for IGCC Plants High Pressure Carbon Dioxide Separation Process for IGCC Plants 1 A High Pressure Carbon Dioxide Separation Process for IGCC Plants S.S. Tam 1 , M.E. Stanton 1 , S. Ghose 1 , G. Deppe 1 , D.F. Spencer 2 , R.P. Currier 3 , J.S. Young 3 , G.K. Anderson 3 , L.A. Le 3 , and D.J. Devlin 3 1 Nexant, Inc. (A Bechtel Technology & Consulting Company) 45 Fremont St., 7 th Fl., San Francisco, CA 94506 2 SIMTECHE 13474 Tierra Heights Road, Redding, CA 96003 3 Los Alamos National Laboratory P.O. Box 1663 (MS J567), Los Alamos, NM 87545 1.0 INTRODUCTION Under separate contracts from the U.S. Department of Energy, Office of Fossil Energy (DOE- FE), Los Alamos National Laboratory, and a team of SIMTECHE and Nexant (a Bechtel Technology and Consulting Company) are jointly working to develop the proprietary process for

36

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

SciTech Connect

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

37

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

SciTech Connect

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

38

Thermoeconomic design optimization of a KRW-based IGCC power plant  

SciTech Connect

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

39

Transient studies of an Integrated Gasification Combined Cycle (IGCC) plant with CO2 capture  

SciTech Connect

Next-generation coal-fired power plants need to consider the option for CO2 capture as stringent governmental mandates are expected to be issued in near future. Integrated gasification combined cycle (IGCC) plants are more efficient than the conventional coal combustion processes when the option for CO2 capture is considered. However, no IGCC plant with CO2 capture currently exists in the world. Therefore, it is important to consider the operability and controllability issues of such a plant before it is commercially built. To facilitate this objective, a detailed plant-wide dynamic simulation of an IGCC plant with 90% CO2 capture has been developed in Aspen Plus Dynamics{reg_sign}. The plant considers a General Electric Energy (GEE)-type downflow radiant-only gasifier followed by a quench section. A two-stage water gas shift (WGS) reaction is considered for conversion of CO to CO2. A two-stage acid gas removal (AGR) process based on a physical solvent is simulated for selective capture of H2S and CO2. Compression of the captured CO2 for sequestration, an oxy-Claus process for removal of H2S and NH3, black water treatment, and the sour water treatment are also modeled. The tail gas from the Claus unit is recycled to the SELEXOL unit. The clean syngas from the AGR process is sent to a gas turbine followed by a heat recovery steam generator. This turbine is modeled as per published data in the literature. Diluent N2 is used from the elevated-pressure ASU for reducing the NOx formation. The heat recovery steam generator (HRSG) is modeled by considering generation of high-pressure, intermediate-pressure, and low-pressure steam. All of the vessels, reactors, heat exchangers, and the columns have been sized. The basic IGCC process control structure has been synthesized by standard guidelines and existing practices. The steady state results are validated with data from a commercial gasifier. In the future grid-connected system, the plant should satisfy the environmental targets and quality of the feed to other sections, wherever applicable, without violating the operating constraints, and without sacrificing the efficiency. However, it was found that the emission of acid gases may far exceed the environmental targets and the overshoot of some of the key variables may be unacceptable under transient operation while following the load. A number of operational strategies and control configurations is explored for achieving these stringent requirements. The transient response of the plant is also studied by perturbing a number of key inputs.

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

2010-01-01T23:59:59.000Z

40

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

SciTech Connect

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

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

Plant-Wide Performance and Cost Analysis of ITM-Based IGCC Power Generation Systems  

Science Conference Proceedings (OSTI)

The Electric Power Research Institute (EPRI), in conjunction with Air Products and Chemicals, Inc. (AP), and WorleyParsons, Inc. (WP), has reviewed and modeled integrated gasification combined cycle (IGCC) systems. IGCC is a method of burning coal in which the coal is gasified, creating a synthetic gas, or “syngas.” After being cleaned¾including potentially of carbon dioxide (CO2)¾this syngas can be used in a traditional combined cycle to produce power. This ...

2013-12-09T23:59:59.000Z

42

Avestar® - Integrated Gasification Combined Cycle (IGCC) Dynamic Simulator  

NLE Websites -- All DOE Office Websites (Extended Search)

Integrated Gasification Combined Cycle (IGCC) Dynamic Simulator Integrated Gasification Combined Cycle (IGCC) Dynamic Simulator The AVESTAR® center offers courses using the Integrated Gasification Combined Cycle (IGCC) Dynamic Simulator. The IGCC simulator builds on and reaches beyond existing combined-cycle and conventional-coal power plant simulators to combine--for the first time--a Gasification with CO2 Capture process simulator with a Combined-Cycle power simulator together in a single dynamic simulation framework. The AVESTAR® center IGCC courses provide unique, comprehensive training on all aspects of an IGCC plant, illustrating the high-efficiency aspects of the gasifier, gas turbine, and steam turbine integration. IGCC Operator training station HMI display for overview of IGCC Plant - Train A Reference:

43

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

SciTech Connect

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

44

Worldwide activity in IGCC  

SciTech Connect

EPRI has pursued the development of integrated gasification-combined-cycle technology because it is the cleanest method available for making electricity from coal. Now, a decade after the establishment of the first IGCC demonstration plant, environmental regulations are encouraging the adoption of this technology in a number of countries. An unexpected innovation is the use of residual oil as an IGCC feedstock, a practice that evolved naturally as a result of market forces. Experts are hopeful that the current momentum in IGCC will trigger the introduction of the technology in developing countries, many of which rely heavily on coal and oil for power generation. Environmental regulations and a market glut of low-grade fossil fuels are spurring an unprecedented number of integrated gasification combined-cycle projects worldwide. These projects are described.

Lamarre, L.

1994-07-01T23:59:59.000Z

45

IGCC offers diversity for competitive generation  

SciTech Connect

Over the last couple of years, integrated gasification combined-cycle (IGCC) power plants have begun penetrating competitive markets, Japan and Taiwan are applying IGCC technology in their first round of independent power producer bidding. The versatility of this technology is adding to its cachet, as it finds its niche in a variety of market segments and applications. In the US, the hottest niche for IGCC is seen in repowering of existing facilities. Increased use in the coal-powered portion of the market is projected in the next decade, as gas turbine technology advances are expected to drive the spread of IGCC beyond industrial applications.

Chambers, A.

1997-11-01T23:59:59.000Z

46

Life Cycle Analysis: Integrated Gasification Combined Cycle (IGCC) Power Plant  

NLE Websites -- All DOE Office Websites (Extended Search)

Life Cycle Analysis: Integrated Life Cycle Analysis: Integrated Gasification Combined Cycle (IGCC) Power Plant Revision 2, March 2012 DOE/NETL-2012/1551 Disclaimer This report was prepared as an account of work sponsored by an agency of the United States Government. Neither the United States Government nor any agency thereof, nor any of their employees, makes any warranty, express or implied, or assumes any legal liability or responsibility for the accuracy, completeness, or usefulness of any information, apparatus, product, or process disclosed, or represents that its use would not infringe privately owned rights. Reference therein to any specific commercial product, process, or service by trade name, trademark, manufacturer, or otherwise does not necessarily constitute or

47

Phased Construction of IGCC Plants for CO2 Capture - Effect of Pre-Investment  

Science Conference Proceedings (OSTI)

Currently, conceptual plant designs for integrated gasification-combined cycle (IGCC) have taken two approaches regarding the capture of CO2. Baseline plants have placed emphasis on producing power with a minimum cost and maximum efficiency without CO2 capture. The primary rationale for designing these plants without CO2 capture is that there have yet to be regulations promulgated that require the capture and sequestration of CO2. Conversely, grass roots IGCC designs with provisions for CO2 capture and c...

2003-12-31T23:59:59.000Z

48

IGCC Dynamic Simulator and Training Center  

SciTech Connect

Integrated Gasification Combined Cycle (IGCC) is emerging as the technology of choice for providing clean, low-cost electricity for the next generation of coal-fired power plants and will play a central role in the development of high-efficiency, zero-emissions power plants such as FutureGen. Several major utilities and developers recently announced plans to build IGCC plants and other major utilities are evaluating IGCC’s suitability for base-load capacity additions. This recent surge of attention to IGCC power generation is creating a growing demand for experience with the analysis, operation, and control of commercial-scale IGCC plants. To meet this need, the National Energy Technology Laboratory (NETL) has launched a project to develop a generic, full-scope, IGCC dynamic plant simulator for use in establishing a state-of-the-art simulator training center at West Virginia University’s (WVU) National Research Center for Coal and Energy (NRCCE). The IGCC Dynamic Simulator & Training (DS&T) Center will be established under the auspices of the Collaboratory for Process & Dynamic Systems Modeling (“Collaboratory”) organized between NETL, WVU, the University of Pittsburgh, and Carnegie Mellon University.

Zitney, S.E.; Erbes, M.R. (Enginomix, LLC)

2006-10-01T23:59:59.000Z

49

Utilities split on readiness of IGCC  

SciTech Connect

For some generating companies, the dearth of operating experience for integrated gasification combined-cycle plants adds too much uncertainty to the risk/reward equation for new-capacity technology options. For others, the possibility of being able to comply with air pollution limits as far out as 2018, as well as to meet all-but-certain CO{sub 2} caps, makes IGCC well worth investing in now. The article compares the highest-level technical and economic characteristics of IGCC with those of pulverised coal combustion and other generating technologies. It then discusses the availability histories of six successful IGCC demonstration plants, presenting that for the Wabash River plant in some detail. The issue of financing IGCC is addressed. An insert on page 58 summarises a paper by Dave Stopek of Sangent and Lundy presented at Electric Power 2006. This discussed IGCC plant cost and factors to consider in selecting a technology supplier. 1 fig., 4 tabs.

Javetski, J.

2006-10-15T23:59:59.000Z

50

Excelsior Energy Mesaba IGCC Project Preliminary Design Specification  

Science Conference Proceedings (OSTI)

With Integrated Gasification Combined Cycle (IGCC) technology now entering commercial service, the industry needs specifications that encourage greater standardization in IGCC design. Standardization lowers initial capital cost; supports repeatable, reliable performance; and reduces the time and cost to develop decision-quality economics for potential IGCC plant owners. This CoalFleet Preliminary Design Specification (PDS) defines technical information provided in the permit application submitted by Exce...

2006-12-11T23:59:59.000Z

51

Integrated Gasification Combined Cycle (IGCC) Design Considerations for High Availability  

Science Conference Proceedings (OSTI)

This report analyses public domain availability data from Integrated Gasification Combined Cycles (IGCC) and other significant coal gasification facilities, backed up with additional data gained from interviews and discussions with plant operators. Predictions for the availability of future IGCCs are made based on the experience of the existing fleet and anticipated improvements from the implementation of lessons learned.

2007-03-26T23:59:59.000Z

52

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

SciTech Connect

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

53

IGCC Design and RAM Analysis for Near Zero Emissions  

Science Conference Proceedings (OSTI)

Concern over the continued availability of natural gas at competitive prices has led many power companies to initiate studies and projects on clean coal technologies as a strategic hedge against over-reliance on natural gas alone to provide future power needs. Integrated gasification combined cycle (IGCC) plants can meet very stringent emissions targets including those for mercury and carbon dioxide. Several years of commercial operation have been accumulated on coal-based IGCC plants in the United State...

2004-12-13T23:59:59.000Z

54

Advanced Coal Wind Hybrid: Economic Analysis  

E-Print Network (OSTI)

IGCC PC advanced coal-wind hybrid combined cycle power plantnatural gas combined cycle gas turbine power plant carboncrude gasification combined cycle power plant with carbon

Phadke, Amol

2008-01-01T23:59:59.000Z

55

2012 Integrated Gasification Combined Cycle (IGCC) Research and Development Roadmap  

Science Conference Proceedings (OSTI)

BackgroundThe second generation of integrated gasification combined cycle (IGCC) power plants is now being built or planned following nearly two decades of commercial demonstration at multiple units. State-of-the-art IGCC plants have efficiencies equivalent to that of pulverized coal power plants while exhibiting equal or superior environmental performance and lower water usage. Precombustion CO2 capture technology is commercially available and has been ...

2012-10-30T23:59:59.000Z

56

Integrated Gasification Combined Cycle (IGCC) Design Considerations for CO2 Capture and Storage (CCS)  

Science Conference Proceedings (OSTI)

The objectives of this research were to assess the performance and costs of coal-fired integrated gasification combined cycle (IGCC) power plants with Greenfield and retrofitted carbon dioxide (CO2) capture. The study is part of the CoalFleet Program, a collaborative research and development program that promotes deployment of advanced coal technologies, including IGCC, ultrasupercritical pulverized, oxy-fuel combustion, and supercritical circulating fluidized bed technologies. Two types of coalPittsburg...

2010-10-01T23:59:59.000Z

57

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

SciTech Connect

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

58

SCHUMACHER HOT GAS FILTER LONG-TERM OPERATING EXPERIENCE in the NUON POWER BUGGENUM IGCC POWER PLANT  

SciTech Connect

Coal is a main source of primary energy for power generation and it will remain indispensable in the future. In order to increase the efficiency and to meet environmental challenges new advanced coal-fired power systems were developed starting in the beginning of the 1990s. One of these efficient and clean technologies is the Integrated Gasification Combined Cycle (IGCC) process.

Scheibner, B.; Wolters, C.

2002-09-18T23:59:59.000Z

59

CoalFleet Integrated-Gasification-Combined-Cycle (IGCC) Permitting Guidelines  

Science Conference Proceedings (OSTI)

EPRIs CoalFleet for Tomorrow Program was formed to accelerate the deployment and commercialization of clean, efficient, advanced coal-fired power systems. During the planning and construction of these power systems, facility owners must obtain permits for plant construction and operation, discharge of pollutants to air and water, land and water use, and other areas of regulatory control. Such permits must be negotiated with regulators who are often not familiar with advanced coal technologies. These Coal...

2007-12-20T23:59:59.000Z

60

The First Coal Plants  

NLE Websites -- All DOE Office Websites (Extended Search)

Coal Plants Coal Plants Nature Bulletin No. 329-A January 25, 1969 Forest Preserve District of Cook County George W. Dunne, President Roland F. Eisenbeis, Supt. of Conservation THE FIRST COAL PLANTS Coal has been called "the mainspring" of our civilization. You are probably familiar, in a general way, with the story of how it originated ages ago from beds of peat which were very slowly changed to coal; and how it became lignite or brown coal, sub-bituminous, bituminous, or anthracite coal, depending on bacterial and chemical changes in the peat, how much it was compressed under terrific pressure, and the amount of heat involved in the process. You also know that peat is formed by decaying vegetation in shallow clear fresh-water swamps or bogs, but it is difficult to find a simple description of the kinds of plants that, living and dying during different periods of the earth's history, created beds of peat which eventually became coal.

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

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)

Integrated Gasification Combined Cycle Technology: IGCC.integrated gasification combined cycle (IGCC) power plants (output. Integrated gas combined cycle (IGCC) plants are

Apps, J.A.

2006-01-01T23:59:59.000Z

62

Enhancement of IGCC through clean by-product fuel coproduction  

SciTech Connect

The major objective of this paper is to first design a base case IGCC plant that is representative of a base-loaded power plant, and then to identify and to quantify the potential benefits of a spare gasifier and fuel-grade methanol coproduction as additions to the base case plant. This is significantly different than previous methanol coproduction IGCC studies which have assumed cyclic operation with undersized coal gasification capacity. The proposed IGCC plant will be at FPL's Martin Site, located near the eastern shore of Lake Okeechobee, Florida. The major components of the proposed IGCC plant are: dry-feed (Shell) or slurry-feed (Dow) gasifiers, GE advanced gas turbine (Model MS7001F), methanol plant based on liquid Phase Methanol (LPMeOH*) process.

Schmoe, L.A. (Bechtel Power Corp., Gaithersburg, MD (United States)); Tam, S.S. (Bechtel Group, Inc., San Francisco, CA (United States)); Walters, A.B. (Florida Power and Light Co., West Palm Beach, FL (US)); Weber, W. (Electric Power Research Inst., Palo Alto, CA (United States))

1991-01-01T23:59:59.000Z

63

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

64

Market potential of IGCC for domestic power production  

SciTech Connect

Mitretek Systems and CONSOL Inc. have completed the first phase of a market potential study for Integrated Coal Gasification Combined Cycle (IGCC) domestic power production. The U. S. Department of Energy (DOE) funded this study. The objective of this study is to provide DOE with data to estimate the future domestic market potential of IGCC for electricity generation. Major drivers in this study are the state of technology development, feedstock costs, environmental control costs, demand growth, and dispatchability. This study examines IGCC potential for baseload power production in the Northeast U. S., an important market area by virtue of existing coal infrastructure and proximity to coal producing regions. IGCC market potential was examined for two levels of technology development as a function of natural gas price and carbon tax. This paper discusses the results of this study, including the levels of performance and cost necessary to insure competitiveness with natural gas combined cycle plants.

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

1999-07-01T23:59:59.000Z

65

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

SciTech Connect

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

66

Microsoft Word - 42651_UCI_ IGCC System Studies_rev060701.doc  

NLE Websites -- All DOE Office Websites (Extended Search)

FY 2006 and will represent a reference case consisting of an "H technology" steam cooled gas turbine based near zero emission IGCC plant. Pittsburgh No. 8 coal will be gasified in...

67

Advanced IGCC power systems for the United States  

SciTech Connect

Integrated coal gasification combined-cycle (IGCC) power systems offer the potential of superior efficiency and environmental performance over power plants using pulverized coal-fired boilers with scrubbers to generate electricity in the United States. The Cool Water plant is demonstrating the feasibility of an IGCC system using an entrained-bed gasifier and ''cold'' gas cleanup technology. Technology is now being developed to simplify the IGCC system, increase its efficiency and reduce its capital costs. Hot gas sulfur and particulate cleanup is the most promising technology option for the gas supply block. Improved performance is also available from the power island by use of high-efficiency aircraft derivative turbines. Progress in these technologies and the exceptional match of these IGCC systems to the projected needs of the utility industry is presented.

Wieber, P.R.; Halow, J.S.

1986-01-01T23:59:59.000Z

68

Integrated gasification combined cycle -- A review of IGCC technology  

SciTech Connect

Over the past three decades, significant efforts have been made toward the development of cleaner and more efficient technology for power generation. Coal gasification technology received a big thrust with the concept of combined cycle power generation. The integration of coal gasification with combined cycle for power generation (IGCC) had the inherent characteristic of gas cleanup and waste minimization, which made this system environmentally preferable. Commercial-scale demonstration of a cool water plant and other studies have shown that the greenhouse gas and particulates emission from an IGCC plant is drastically lower than the recommended federal New Source Performance Standard levels. IGCC also offers a phased construction and repowering option, which allows multiple-fuel flexibility and the necessary economic viability. IGCC technology advances continue to improve efficiency and further reduce the emissions, making it the technology of the 21st century.

Joshi, M.M.; Lee, S. [Univ. of Akron, OH (United States)

1996-07-01T23:59:59.000Z

69

CE IGCC Repowering plant sulfuric acid plant. Topical report, June 1993  

SciTech Connect

A goal of the CE IGCC Repowering project is to demonstrate a hot gas clean-up system (HGCU), for the removal of sulfur from the product gas stream exiting the gasifier island. Combustion Engineering, Inc. (ABB CE) intends to use a HGCU developed by General Electric Environmental Services (GEESI). The original design of this system called for the installation of the HGCU, with a conventional cold gas clean-up system included as a full-load operational back-up. Each of these systems removes sulfur compounds and converts them into an acid off-gas. This report deals with the investigation of equipment to treat this off-gas, recovering these sulfur compounds as elemental sulfur, sulfuric acid or some other form. ABB CE contracted ABB Lummus Crest Inc. (ABB LCI) to perform an engineering evaluation to compare several such process options. This study concluded that the installation of a sulfuric acid plant represented the best option from both a technical and economic point of view. Based on this evaluation, ABB CE specified that a sulfuric acid plant be installed to remove sulfur from off-gas exiling the gas clean-up system. ABB LCI prepared a request for quotation (RFQ) for the construction of a sulfuric acid production plant. Monsanto Enviro-Chem Inc. presented the only proposal, and was eventually selected as the EPC contractor for this system.

Chester, A.M.

1993-12-01T23:59:59.000Z

70

New low cost IGCC designs for competitive power generation  

SciTech Connect

Design studies of coal based 450 MW new IGCC power plants reveal their ability to compete in today's power generation market. Single train unit designs coupled with significant improvements in IGCC net output and efficiency have brought down the installed costs to the range of 850--1,000 $/kW and net thermal efficiency up to 43--47%. These improvements are shown to result from IGCC design configurations integrating new generation gas turbine combined cycles with High Pressure Texaco Gasification Technology and Elevated Pressure Air Separation Units.

Brdar, D.R.; Depuy, R.A.; Gulko, G.; Jandrisevits, M.; Paolino, J.

1999-07-01T23:59:59.000Z

71

Advanced Coal Power Plant Model (ACCPM) Version 1.1  

Science Conference Proceedings (OSTI)

With the purchase of a license for the appropriate SimTech IPSEpro modules and library, users can quickly generate performance and capital cost estimates of new, advanced coal power plants. The application allows users to screen integrated gasification combined cycle (IGCC) technologies prior to engaging in more extensive studies of their preferred choice. Such screening activities generally require sophisticated software and qualified staff to run the models, which takes time and significant investment....

2011-03-08T23:59:59.000Z

72

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

Science Conference Proceedings (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

73

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

74

2012 Integrated Gasification Combined Cycle (IGCC) Research and Development Roadmap - PUBLIC  

Science Conference Proceedings (OSTI)

The second generation of integrated-gasification combined-cycle (IGCC) power plants is now being built or planned following nearly two decades of commercial demonstration at multiple units. State-of-the-art IGCC plants have efficiencies equivalent to that of pulverized coal power plants while exhibiting equal or superior environmental performance and lower water usage. Pre-combustion CO2 capture technology is commercially available and has been demonstrated in several gasification plants, ...

2012-12-20T23:59:59.000Z

75

Amid all the IGCC talk, PC remains the go-to-guy  

SciTech Connect

Globally, more than 100 sites have integrated gasification combined cycle (IGCC) installations, including more than a dozen locations that produce power. IGCC 'buzz' has now reached a crescendo, as evidenced by attendance of over 700 at the recent Gasification Technologies conference. However, coal plants currently being developed in the United States are mostly subcritical or supercritical pulverized coal plants, with a handful of CFBs. The article describes some recent developments in IGCC and goes on to address the debate between IGCC and PC. IGCC has the inherent ability to capture CO{sub 2} before combustion, but PC may well be able to capture just as well CO{sub 2} post combustion. More work is needed on a sequestering carbon in the ground, according to Nancy Mohn and others whose opinions are reported. 1 photo.

Blankinship, S.

2006-04-15T23:59:59.000Z

76

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

Science Conference Proceedings (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

77

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

Science Conference Proceedings (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

78

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

Science Conference Proceedings (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

79

Ultra Low NOx Catalytic Combustion for IGCC Power Plants  

DOE Green Energy (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

80

IGCC+S Financing  

NLE Websites -- All DOE Office Websites (Extended Search)

II II William G. Rosenberg, Dwight C. Alpern, Michael R. Walker Energy Technology Innovation Project a joint project of the Science, Technology and Public Policy Program and the Environment and Natural Resources Program Belfer Center for Science and International Affairs 2 0 0 4 - 0 8 J U LY 2 0 0 4 Deploying IGCC in this Decade with 3Party Covenant Financing VOLUME II William G. Rosenberg, Dwight C. Alpern, and Michael R. Walker Energy Technology Innovation Project a joint project of the Science, Technology and Public Policy Program and the Environment and Natural Resources Program Belfer Center for Science and International Affairs and Center for Business and Government John F. Kennedy School of Government Harvard University July 2004 Financing IGCC - 3Party Covenant ii

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

Combustion Engineering Integrated Gasification Combined Cycle (IGCC) Repowering Project -- Clean Coal II Project. Annual report, November 20, 1990--December 31, 1991  

SciTech Connect

The IGCC system will consist of CE`s air-blown, entrained-flow, two-stage, pressurized coal gasifier; an advanced hot gas cleanup process; a combustion turbine adapted to use low-Btu coal gas; and all necessary coal handling equipment. The IGCC will include CE`s slogging, entrained-flow, gasifier operating in a pressurized mode and using air as the oxidant. The hot gas will be cleaned of particulate matter (char) which is recycled back to the gasifier. After particulate removal, the product gas will be cleaned of sulfur prior to burning in a gas turbine. The proposed project includes design and demonstration of two advanced hot gas cleanup processes for removal of sulfur from the product gas of the gasifier. The primary sulfur removal method features a newly developed moving-bed zinc ferrite system downstream of the gasifier. The process data from these pilot tests is expected to be sufficient for the design of a full-scale system to be used in the proposed demonstration. A second complementary process is in situ desulfurization achieved by adding limestone or dolomite directly to the coal feed. The benefit, should such an approach prove viable, is that the downstream cleanup system could be reduced in size. In this plant, the gasifier will be producing a low-Btu gas (LBG). The LBG will be used as fuel in a standard GE gas turbine to produce power. This gas turbine will have the capability to fire LBG and natural gas (for start-up). Since firing LBG uses less air than natural gas, the gas turbine air compressor will have extra capacity. This extra compressed air will be used to pressurize the gasifier and supply the air needed in the gasification process. The plant is made of three major blocks of equipment as shown in Figure 2. They are the fuel gas island which includes the gasifier and gas cleanup, gas turbine power block, and the steam turbine block which includes the steam turbine and the HRSG.

1993-03-01T23:59:59.000Z

82

DOE Science Showcase - Energy Plants of the Future | OSTI, US...  

Office of Scientific and Technical Information (OSTI)

DOE Press Release DOE-Sponsored IGCC Project in Texas Takes Important Step Forward, Fossil Energy Techline Gasification Technology R&D How Coal Gasification Power Plants Work...

83

Toms Creek IGCC Demonstration Project  

SciTech Connect

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

84

Toms Creek IGCC Demonstration Project  

SciTech Connect

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

85

Nuon Magnum Integrated-Gasification -Combined-Cycle (IGCC) Project Preliminary Design Specification  

Science Conference Proceedings (OSTI)

This is the second pre-design specification (PDS) in a projected series for integrated-gasificationcombined-cycle (IGCC) plants, sponsored by EPRIs CoalFleet for Tomorrow program and involving more than 50 power industry companies. A PDS represents the level of nonproprietary information available at the feasibility study stage in the development of an IGCC project. This PDS is based on the design of the 1200-MWe Magnum IGCC plant, which Nuon Power Generation B.V. has proposed to build on the northern co...

2008-03-31T23:59:59.000Z

86

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

SciTech Connect

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

87

An evaluaton of integrated-gasification-combined-cycle and pulverized-coal-fired steam plants: Volume 2, Sensitivity studies and appendixes: Final report  

SciTech Connect

The Electric Power Research Institute contracted with Bechtel Group, Inc., to provide 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). 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 study confirms that 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. In addition, 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.

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

1988-09-01T23:59:59.000Z

88

NETL: Coal-Fired Power Plants (CFPPs)  

NLE Websites -- All DOE Office Websites (Extended Search)

Coal Sources Coal-Fired Power Plants (CFPPs) Where is the coal in the United States? Coal Across the U.S. The U.S. contains coal resources in various places. The coal occurs...

89

Filter system cost comparison for IGCC and PFBC power systems  

SciTech Connect

A cost comparison was conducted between the filter systems for two advanced coal-based power plants. The results from this study are presented. The filter system is based on a Westinghouse advanced particulate filter concept, which is designed to operate with ceramic candle filters. The Foster Wheeler second-generation 453 MWe (net) pressurized fluidized-bed combustor (PFBC) and the KRW 458 MWe (net) integrated gasification combined cycle (IGCC) power plants are used for the comparison. The comparison presents the general differences of the two power plants and the process-related filtration conditions for PFBC and IGCC systems. The results present the conceptual designs for the PFBC and IGCC filter systems as well as a cost summary comparison. The cost summary comparison includes the total plant cost, the fixed operating and maintenance cost, the variable operating and maintenance cost, and the effect on the cost of electricity (COE) for the two filter systems.

Dennis, R.A.; McDaniel, H.M.; Buchanan, T. [and others

1995-12-01T23:59:59.000Z

90

New technology trends for improved IGCC system performance  

SciTech Connect

The application of gas turbine technology to IGCC systems requires careful consideration of the degree and type of integration used during the system design phase. Although gas turbines provide the primary output and efficiency gains for IGCC systems, as compared with conventional coal-fired power generation systems, they are commercially available only in specific size ranges. Therefore, it is up to the IGCC system designer to optimize the IGCC power plant within the required output, efficiency, and site conditions by selecting the system configuration carefully, particularly for air separation unit (ASU) integration incorporated with oxygen blown gasification systems. An IGCC system, based on a generic, entrained flow, oxygen blown gasification system and a GE STAG 109FA combined cycle has been evaluated with varying degrees of ASU integration, two fuel equivalent heating values and two gas turbine firing temperatures to provide net plant output and efficiency results. The data presented illustrate the system flexibility afforded by variation of ASU integration and the potential performance gains available through the continued use of gas turbine advances. Emphasis is placed on system design choices that favor either low initial investment cost or low operating cost for a given IGCC system output.

Anand, A.K.; Cook, C.S.; Corman, J.C. [GE Power Generation, Schenectady, NY (United States); Smith, A.R. [Air Products and Chemicals, Inc., Allentown, PA (United States)

1996-10-01T23:59:59.000Z

91

DOE-Sponsored IGCC Project in Texas Takes Important Step Forward |  

Energy.gov (U.S. Department of Energy (DOE)) Indexed Site

DOE-Sponsored IGCC Project in Texas Takes Important Step Forward DOE-Sponsored IGCC Project in Texas Takes Important Step Forward DOE-Sponsored IGCC Project in Texas Takes Important Step Forward June 20, 2011 - 1:00pm Addthis Washington, DC - A newly signed memorandum of understanding (MOU) for the purchase of electricity produced by the Texas Clean Energy Project (TCEP) is an important step forward for what will be one of the world's most advanced and cleanest coal-based power plants, funded in part by the U.S. Department of Energy (DOE). Under the MOU, CPS Energy - a municipally owned utility serving San Antonio, Texas - will purchase electricity generated by the first-of-a-kind commercial clean coal power plant, starting in mid 2014. TCEP, a 400-megawatt integrated gasification combined cycle (IGCC) facility located

92

CE IGCC repowering project: Materials for coal gasification environment. Topical report, June 1993  

Science Conference Proceedings (OSTI)

A task to develop material requirements and a materials testing strategy was established with the Materials and Water Chemistry Department of the ABB Power plant Laboratories. This involved examining the requirements for each system under ABB CE scope. The basis for the material recommendations was largely based on in-house test programs under DOE contract and ABB CE experience. Consultants were utilized in a parallel task to assist in the design and material specification for the solids handling systems. ABB CE experience includes operating data from a former process development unit (PDU) located in Windsor, Connecticut. The unit gasified Pittsburgh seam coal at a nominal firing rate of 120 tons per day. The objectives of the program were to produce clean, low-Btu gas from coal, and to provide the design information for scale-up to commercial-size plants. The results of the task were used to specify and, depending on scope, design the equipment used in the plant. A detailed document was developed and used to generate a Metallurgical Flow Diagram. Specifications were developed from this diagram. For the equipment designed, these selections were provided to representatives of cognizant design and manufacturing departments. In addition, where appropriate, recommendations were made for operating procedures and for design changes. Specified materials will be again evaluated during detailed engineering. In some areas the results of the task were not conclusive. Additional investigation will be required. These areas are the types of approaches which can be taken to accommodate product gas sulfidation resistance and solids transport erosion.

Gibbons, T.B.; O`Neill, J.K.; Plumley, A.L.; Thibeault, P.R.; Waryasz, R.W.

1993-10-01T23:59:59.000Z

93

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

Science Conference Proceedings (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

94

Microsoft Word - 41889_GE_IGCC System Study_Factsheet_Rev01_07-20-04.doc  

NLE Websites -- All DOE Office Websites (Extended Search)

Fact Sheet: Fact Sheet: "System Study For Improved Gas Turbine Performance For Coal IGCC Application" DOE Contract No: DE-FC26-03NT41889 I Project Description: A. Objective: This study will identify improvements in gas turbine performance for coal Integrated Gasification Combined Cycle (IGCC) application. The study will identify vital gas turbine parameters and quantify their influence in meeting the DOE Turbine Program overall IGCC plant goals of 50% net HHV efficiency, $1000/kW capital cost, and low emissions. Focus will be on air-cooled gas turbines for near-term operation in coal fed oxygen blown IGCC power plants with commercially demonstrated gasification, gas cleaning, & air separation technologies. A roadmap towards achieving DOE's goals for

95

Load-following control of an IGCC plant with CO2 capture  

SciTech Connect

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

96

Plants of the Coal Age  

NLE Websites -- All DOE Office Websites (Extended Search)

Coal Age Nature Bulletin No. 330-A February 1, 1969 Forest Preserve District of Cook County George W. Dunne, President Roland F. Eisenbeis, Supt. of Conservation PLANTS OF THE COAL...

97

Use of experience curves to estimate the future cost of power plants with CO2 capture  

E-Print Network (OSTI)

boiler; Pittsburgh #8 coal; price = 1.0 $/GJ. f IGCC plant =7FA gas turbines; Pgh #8 coal; price = 1.0 $/GJ. g Oxyfuelboiler; Pittsburgh #8 coal; price = 1.0 $/GJ. Other

Rubin, Edward S.; Yeh, Sonia; Antes, Matt; Berkenpas, Michael; Davison, John

2007-01-01T23:59:59.000Z

98

Life Cycle Results from the IGCC LCI&C Study  

NLE Websites -- All DOE Office Websites (Extended Search)

Results from the IGCC LCI&C Study Results from the IGCC LCI&C Study Robert E. James III, Timothy J. Skone Office of Systems, Analyses and Planning National Energy Technology Laboratory (NETL), U.S. DOE Revision 2, June 2013 DOE/NETL-2012/1551 ‹#› Conceptual Study Boundary Integrated Gasification Combined Cycle (IGCC) ‹#› LCA's Expanded Boundary for IGCC Mine Construction Train & Rail Manufacturing Plant Construction/ Installation Coal Extraction/ Operation Train Operation Mine Decommissioning Stage #1 Raw Material Acquisition Stage #2 Raw Material Transport Plant Operation Carbon Capture (CC), Operation CO 2 Pipeline, Operation CO 2 Sequestration, Operation Plant Decommissioning Construction & Installation Deinstallation Transmission & Distribution, Operation

99

Shell-based gasification-combined-cycle power plant evaluations. Final report  

SciTech Connect

This report presents the results of a detailed engineering and economic evaluation of shell-based integrated gasification - combined-cycle (IGCC) power plants. Two complete nominal 1000 MW capacity Shell-based grass roots IGCC plant designs and cost estimates were prepared. The following conclusions were made: Shell-based IGCC plants firing Illinois coal and employing current technology gas turbines (2000/sup 0/F firing temperature) have the potential to be cost competitive with conventional coal-fired steam plants with FGD. Shell-based IGCC plants firing Texas lignite have the potential to generate power at costs that are competitive with those based on firing high rank coal. Shell-based IGCC plants firing Illinois No. 6 coal have equivalent performance and costs similar to Texaco-based IGCC systems.

Hartman, J.J.

1983-06-01T23:59:59.000Z

100

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

SciTech Connect

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

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

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

DOE Green Energy (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

102

Rigorous Kinetic Modeling, Optimization, and Operability Studies of a Modified Claus Unit for an Integrated Gasification Combined Cycle (IGCC) Power Plant with CO{sub 2} Capture  

Science Conference Proceedings (OSTI)

The modified Claus process is one of the most common technologies for sulfur recovery from acid gas streams. Important design criteria for the Claus unit, when part of an Integrated Gasification Combined Cycle (IGCC) power plant, are the ability to destroy ammonia completely and the ability to recover sulfur thoroughly from a relatively low purity acid gas stream without sacrificing flame stability. Because of these criteria, modifications to the conventional process are often required, resulting in a modified Claus process. For the studies discussed here, these modifications include the use of a 95% pure oxygen stream as the oxidant, a split flow configuration, and the preheating of the feeds with the intermediate pressure steam generated in the waste heat boiler (WHB). In the future, for IGCC plants with CO{sub 2} capture, the Claus unit must satisfy emission standards without sacrificing the plant efficiency in the face of typical disturbances of an IGCC plant, such as rapid change in the feed flow rates due to load-following and wide changes in the feed composition because of changes in the coal feed to the gasifier. The Claus unit should be adequately designed and efficiently operated to satisfy these objectives. Even though the Claus process has been commercialized for decades, most papers concerned with the modeling of the Claus process treat the key reactions as equilibrium reactions. Such models are validated by manipulating the temperature approach to equilibrium for a set of steady-state operating data, but they are of limited use for dynamic studies. One of the objectives of this study is to develop a model that can be used for dynamic studies. In a Claus process, especially in the furnace and the WHB, many reactions may take place. In this work, a set of linearly independent reactions has been identified, and kinetic models of the furnace flame and anoxic zones, WHB, and catalytic reactors have been developed. To facilitate the modeling of the Claus furnace, a four-stage method was devised so as to determine which set of linearly independent reactions would best describe the product distributions from available plant data. Various approaches are taken to derive the kinetic rate expressions, which are either missing in the open literature or found to be inconsistent. A set of plant data is used for optimal estimation of the kinetic parameters. The final model agrees well with the published plant data. Using the developed kinetics models of the Claus reaction furnace, WHB, and catalytic stages, two optimization studies are carried out. The first study shows that there exists an optimal steam pressure generated in the WHB that balances hydrogen yield, oxygen demand, and power generation. In the second study, it is shown that an optimal H{sub 2}S/SO{sub 2} ratio exists that balances single-pass conversion, hydrogen yield, oxygen demand, and power generation. In addition, an operability study has been carried out to examine the operating envelope in which both the H{sub 2}S/SO{sub 2} ratio and the adiabatic flame temperature can be controlled in the face of disturbances typical for the operation of an IGCC power plant with CO{sub 2} capture. Impact of CO{sub 2} capture on the Claus process has also been discussed.

Jones, Dustin; Bhattacharyya, Debangsu; Turton, Richard; Zitney, Stephen E

2011-12-15T23:59:59.000Z

103

Rigorous Kinetic Modeling and Optimization Study of a Modified Claus Unit for an Integrated Gasification Combined Cycle (IGCC) Power Plant with CO{sub 2} Capture  

SciTech Connect

The modified Claus process is one of the most common technologies for sulfur recovery from acid gas streams. Important design criteria for the Claus unit, when part of an Integrated Gasification Combined Cycle (IGCC) power plant, are the ability to destroy ammonia completely and the ability to recover sulfur thoroughly from a relatively low purity acid gas stream without sacrificing flame stability. Because of these criteria, modifications to the conventional process are often required, resulting in a modified Claus process. For the studies discussed here, these modifications include the use of a 95% pure oxygen stream as the oxidant, a split flow configuration, and the preheating of the feeds with the intermediate pressure steam generated in the waste heat boiler (WHB). In the future, for IGCC plants with CO{sub 2} capture, the Claus unit must satisfy emission standards without sacrificing the plant efficiency in the face of typical disturbances of an IGCC plant, such as rapid change in the feed flow rates due to load-following and wide changes in the feed composition because of changes in the coal feed to the gasifier. The Claus unit should be adequately designed and efficiently operated to satisfy these objectives. Even though the Claus process has been commercialized for decades, most papers concerned with the modeling of the Claus process treat the key reactions as equilibrium reactions. Such models are validated by manipulating the temperature approach to equilibrium for a set of steady-state operating data, but they are of limited use for dynamic studies. One of the objectives of this study is to develop a model that can be used for dynamic studies. In a Claus process, especially in the furnace and the WHB, many reactions may take place. In this work, a set of linearly independent reactions has been identified, and kinetic models of the furnace flame and anoxic zones, WHB, and catalytic reactors have been developed. To facilitate the modeling of the Claus furnace, a four-stage method was devised so as to determine which set of linearly independent reactions would best describe the product distributions from available plant data. Various approaches are taken to derive the kinetic rate expressions, which are either missing in the open literature or found to be inconsistent. A set of plant data is used for optimal estimation of the kinetic parameters. The final model agrees well with the published plant data. Using the developed kinetics models of the Claus reaction furnace, WHB, and catalytic stages, two optimization studies are carried out. The first study shows that there exists an optimal steam pressure generated in the WHB that balances hydrogen yield, oxygen demand, and power generation. In the second study, it is shown that an optimal H{sub 2}S/SO{sub 2} ratio exists that balances single-pass conversion, hydrogen yield, oxygen demand, and power generation. In addition, an operability study has been carried out to examine the operating envelope in which both the H{sub 2}S/SO{sub 2} ratio and the adiabatic flame temperature can be controlled in the face of disturbances typical for the operation of an IGCC power plant with CO{sub 2} capture. Impact of CO{sub 2} capture on the Claus process has also been discussed.

Jones, Dustin; Bhattacharyya, Debangsu; Turton, Richard; Zitney, Stephen E.

2012-02-08T23:59:59.000Z

104

Modeling and optimization of a modified claus process as part of an integrted gasification combined cycle (IGCC) power plant with CO2 capture  

DOE Green Energy (OSTI)

The modified Claus process is one of the most common technologies for sulfur recovery from acid gas streams. Important design criteria for the Claus unit, when part of an Integrated Gasification Combined Cycle (IGCC) power plant, are the ability to destroy ammonia completely and recover sulfur thoroughly from a relatively low purity acid gas stream without sacrificing flame stability. Due to these criteria, modifications are often required to the conventional process, resulting in a modified Claus process. For the studies discussed here, these modifications include the use of a 95% pure oxygen stream as the oxidant, a split flow configuration, and the preheating of the feeds with the intermediate pressure steam generated in the waste heat boiler (WHB). In the future, for IGCC plants with CO2 capture, the Claus unit must satisfy emission standards without sacrificing the plant efficiency in the face of typical disturbances of an IGCC plant such as rapid change in the feed flowrates due to load-following and wide changes in the feed composition because of changes in the coal feed to the gasifier. The Claus unit should be adequately designed and efficiently operated to satisfy these objectives. Even though the Claus process has been commercialized for decades, most papers concerned with the modeling of the Claus process treat the key reactions as equilibrium reactions. Such models are validated by manipulating the temperature approach to equilibrium for a set of steady-state operating data, but are of limited use for dynamic studies. One of the objectives of this study is to develop a model that can be used for dynamic studies. In a Claus process, especially in the furnace and the WHB, many reactions may take place. In this work, a set of linearly independent reactions has been identified and kinetic models of the furnace flame and anoxic zones, WHB, and catalytic reactors have been developed. To facilitate the modeling of the Claus furnace, a four-stage method was devised so as to determine which set of linearly independent reactions would best describe the product distributions from available plant data. Various approaches are taken to derive the kinetic rate expressions which are either missing in the open literature or found to be inconsistent. A set of plant data is used for optimal estimation of the kinetic parameters. The final model agrees well with the published plant data. Using the developed kinetics models of the Claus reaction furnace, WHB, and catalytic stages, two optimization studies are carried out. The first study shows that there exists an optimal steam pressure generated in the WHB that balances hydrogen yield, oxygen demand, and power generation. In the second study, it is shown that an optimal H2S/SO2 ratio exists that balances single-pass conversion, hydrogen yield, oxygen demand, and power generation. In addition, an operability study has been carried out to examine the operating envelope in which both H2S/SO2 ratio and adiabatic flame temperature can be controlled in the face of disturbances typical for the operation of an IGCC power plant with CO2 capture. Impact of CO2 capture on the Claus process has also been discussed.

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

2011-01-01T23:59:59.000Z

105

Secretary Chu Announces $14 Million for Six New Projects to Advance IGCC  

Energy.gov (U.S. Department of Energy (DOE)) Indexed Site

14 Million for Six New Projects to Advance 14 Million for Six New Projects to Advance IGCC Technology Secretary Chu Announces $14 Million for Six New Projects to Advance IGCC Technology September 9, 2011 - 1:00pm Addthis Washington, DC - U.S. Department of Energy Secretary Steven Chu announced today the selection of six projects aimed at developing technologies to lower the cost of producing electricity in integrated gasification combined cycle (IGCC) power plants using carbon capture, while maintaining the highest environmental standards. Supported with up to $14 million in total funding, the selected projects will improve the economics of IGCC plants and promote the use of the Nation's abundant coal resources to produce clean, secure, and affordable energy. The successful development of advanced technologies and innovative concepts

106

Secretary Chu Announces $14 Million for Six New Projects to Advance IGCC  

Energy.gov (U.S. Department of Energy (DOE)) Indexed Site

4 Million for Six New Projects to Advance 4 Million for Six New Projects to Advance IGCC Technology Secretary Chu Announces $14 Million for Six New Projects to Advance IGCC Technology September 9, 2011 - 6:16pm Addthis Washington, D.C. -U.S. Department of Energy Secretary Steven Chu announced today the selection of six projects aimed at developing technologies to lower the cost of producing electricity in integrated gasification combined cycle (IGCC) power plants using carbon capture, while maintaining the highest environmental standards. Supported with up to $14 million in total funding, the selected projects will improve the economics of IGCC plants and promote the use of the Nation's abundant coal resources to produce clean, secure, and affordable energy. The successful development of advanced technologies and innovative concepts

107

Future Impacts of Coal Distribution Constraints on Coal Cost  

E-Print Network (OSTI)

integrated gasification combined cycle ( IGCC) power plantsintegrated gasification combined cycle (IGCC) power plants,be integrated gasification combined cycle (IGCC) (Same power

McCollum, David L

2007-01-01T23:59:59.000Z

108

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

109

Mechanical and Transport Characteristics of Coal-Biomass Mixtures for Advanced IGCC Systems.  

E-Print Network (OSTI)

??Co-firing of coal-biomass is one effective means of reducing CO2 emissions as biomass is a carbon neutral supplementary fuel. Co-feeding of biomass is technically challenging… (more)

Chandra, Divya

2012-01-01T23:59:59.000Z

110

Petcoke and Low-Rank Coal/Lignite Supply Outlook for IGCC Evaluations  

Science Conference Proceedings (OSTI)

Petroleum coke, a by-product of petroleum refining, is used in many industries, with the highest-sulfur forms of petcoke disposed of as fuel for power generation. Because of its high heat content and low moisture, petcoke holds benefits in a fuel blend with lower grade fuels such as lignite for integrated coal gasification. This report reviews the characteristics of petroleum coke, presents its supply and demand outlook, and estimates the relative costs of various coals and petroleum coke at locations in...

2006-02-22T23:59:59.000Z

111

Upgrading coal plant damper drives  

Science Conference Proceedings (OSTI)

The replacement of damper drives on two coal-fired units at the James H. Miller Jr. electric generating plant by Intelligent Contrac electric rotary actuators is discussed. 2 figs.

Hood, N.R.; Simmons, K. [Alamaba Power (United States)

2009-11-15T23:59:59.000Z

112

Cost of New Integrated Gasification Combined Cycle (IGCC) Coal Electricity Generation...................... 17  

E-Print Network (OSTI)

Abstract: Future demand for electricity can be met with a range of technologies, with fuels including coal, nuclear, natural gas, biomass and other renewables, as well as with energy efficiency and demand management approaches. Choices among options will depend on factors including capital cost, fuel cost, market and regulatory uncertainty, greenhouse gas emissions, and other environmental impacts. This paper estimates the costs of new electricity generation. The approach taken here is to provide a transparent and verifiable analysis based mainly on recent data provided

Seth Borin; Todd Levin; Valerie M. Thomas; Seth Borin; Todd Levin; Valerie M. Thomas

2010-01-01T23:59:59.000Z

113

DOE Awards $235 Million to Southern Company to Build Clean Coal Plant |  

Energy.gov (U.S. Department of Energy (DOE)) Indexed Site

235 Million to Southern Company to Build Clean Coal 235 Million to Southern Company to Build Clean Coal Plant DOE Awards $235 Million to Southern Company to Build Clean Coal Plant February 22, 2006 - 12:13pm Addthis WASHINGTON , DC - The U.S. Department of Energy awarded $235 million to Southern Company, in partnership with the Orlando Utilities Commission and Kellogg, Brown and Root, to develop one of the cleanest coal-fired power plants in the world. Representatives of the Energy Department and Southern Company signed a cooperative agreement that launches the design, construction, and demonstration of an integrated gasification combined cycle (IGCC) power generation system at the Orlando Utilities Commission's Stanton Energy Center. The system will produce 285 megawatts of electricity for the Orlando area - which will power approximately 285,000 households - and is

114

Exelon Power IGCC Executive Briefing  

Science Conference Proceedings (OSTI)

... All rights reserved. Advanced Coal Plants with CCS ... Advanced Coal Plants with CCS Pulverized Coal w/CCS Process Flow Diagram ...

2013-04-21T23:59:59.000Z

115

Improved sulfur removal processes evaluated for IGCC  

SciTech Connect

An inherent advantage of Integrated Coal Gasification Combined Cycle (IGCC) electric power generation is the ability to easily remove and recover sulfur. During the last several years, a number of new, improved sulfur removal and recovery processes have been commercialized. An assessment is given of alternative sulfur removal processes for IGCC based on the Texaco coal gasifier. The Selexol acid gas removal system, Claus sulfur recovery, and SCOT tail gas treating are currently used in Texaco-based IGCC. Other processes considered are: Purisol, Sulfinol-M, Selefning, 50% MDEA, Sulften, and LO-CAT. 2 tables.

1986-12-01T23:59:59.000Z

116

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

Science Conference Proceedings (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

117

State estimation of an acid gas removal (AGR) plant as part of an integrated gasification combined cycle (IGCC) plant with CO2 capture  

Science Conference Proceedings (OSTI)

An accurate estimation of process state variables not only can increase the effectiveness and reliability of process measurement technology, but can also enhance plant efficiency, improve control system performance, and increase plant availability. Future integrated gasification combined cycle (IGCC) power plants with CO2 capture will have to satisfy stricter operational and environmental constraints. To operate the IGCC plant without violating stringent environmental emission standards requires accurate estimation of the relevant process state variables, outputs, and disturbances. Unfortunately, a number of these process variables cannot be measured at all, while some of them can be measured, but with low precision, low reliability, or low signal-to-noise ratio. As a result, accurate estimation of the process variables is of great importance to avoid the inherent difficulties associated with the inaccuracy of the data. Motivated by this, the current paper focuses on the state estimation of an acid gas removal (AGR) process as part of an IGCC plant with CO2 capture. This process has extensive heat and mass integration and therefore is very suitable for testing the efficiency of the designed estimators in the presence of complex interactions between process variables. The traditional Kalman filter (KF) (Kalman, 1960) algorithm has been used as a state estimator which resembles that of a predictor-corrector algorithm for solving numerical problems. In traditional KF implementation, good guesses for the process noise covariance matrix (Q) and the measurement noise covariance matrix (R) are required to obtain satisfactory filter performance. However, in the real world, these matrices are unknown and it is difficult to generate good guesses for them. In this paper, use of an adaptive KF will be presented that adapts Q and R at every time step of the algorithm. Results show that very accurate estimations of the desired process states, outputs or disturbances can be achieved by using the adaptive KF.

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

2012-01-01T23:59:59.000Z

118

Integrated Coal Gasification Power Plant Credit (Kansas)  

Energy.gov (U.S. Department of Energy (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...

119

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

120

Coproduction of peaking fuels in IGCC power plants: a process-screening study. Final report  

SciTech Connect

This study evaluated and compared various options for processing a portion of the medium BTU gas (MBG) produced in a coal gasification combined cycle (GCC) power plant to produce a fuel which might be suitable for peaking or intermediate load use. Two alternate objectives were investigated in separate phases of the study. The first phase examined options for processing and storing a fuel which could be withdrawn and used in absorbing daily load swings in power generation demand. The second phase investigated options for meeting the seasonal peaks in gas demand of a joint gas/electric utility by converting a portion of the MBG to substitute natural gas (SNG) during the months of peak gas demand. For each phase, process designs and cost estimates were completed for several cases, based on both Texaco and BGC-Lurgi Slagging Gasification Technology. For the purposes of this screening study, it was assumed that the peaking fuel production facilities are incremental to the base GCC plant. The costs to produce and store the peaking fuel, excluding the cost of the MBG feed, were calculated by the revenue requirement method. Various sensitivities were evaluated on case assumptions, including a sensitivity to MBG feed value. For daily peaking use, the co-production of methanol and electricity by the ''once-through'' scheme (as studied in EPRI Report AP-2212) proved the most attractive option. Other options which produced gaseous fuels (hydrogen or SNG) for on-site storage were at least 30% more costly. Storage of SNG in an existing natural gas pipeline system was at least 10% higher, excluding pipeline charges. For seasonal SNG production there was little difference between the options studied, within the accuracy of the estimates. 13 refs., 72 tabs.

Shenoy, T.A.; Solomon, J.; O'Brien, V.J.

1986-07-01T23:59:59.000Z

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.


121

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

SciTech Connect

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

122

Design Options for Enhancing IGCC Flexible Operations Performance and Economics  

Science Conference Proceedings (OSTI)

This report describes the cycling experience of integrated gasification combined cycle (IGCC) plants, and the characteristics of IGCC and its component technologies that can make it particularly responsive to renewables-driven, flexible operation and cycling requirements. It also identifies a number of design options for optimizing IGCC cycling performance, and economics for such requirements to nearly meet natural gas combined cycle (NGCC) ramping ...

2013-12-13T23:59:59.000Z

123

Tracking New Coal-Fired Power Plants  

NLE Websites -- All DOE Office Websites (Extended Search)

New Coal-Fired Power Plants New Coal-Fired Power Plants (data update 1/13/2012) January 13, 2012 National Energy Technology Laboratory Office of Strategic Energy Analysis & Planning Erik Shuster 2 Tracking New Coal-Fired Power Plants This report is intended to provide an overview of proposed new coal-fired power plants that are under development. This report may not represent all possible plants under consideration but is intended to illustrate the potential that exists for installation of new coal-fired power plants. Additional perspective has been added for non-coal-fired generation additions in the U.S. and coal-fired power plant activity in China. Experience has shown that public announcements of power plant developments do not provide an accurate representation of eventually

124

The role of Integrated Gasification Combined Cycle in the USDOE`s Clean Coal Research, Development and Demonstration Program  

SciTech Connect

For many years, the US Department of Energy (DOE) has been funding research, development, and demonstration (RD&D) projects to develop advanced power generation technologies. The goal of this activity is to catalyze the private sector to commercialize technologies that will provide reasonably priced electricity and still meet stringent environmental standards. Integrated Gasification Combined Cycle (IGCC) systems are emerging as one of the more attractive candidate technologies to meet this goal. The Morgantown Energy Technology Center (METC) has been assigned the responsibility for implementing IGCC projects in DOE`s Clean Coal RD&D program. The IGCC technology offers the potential for significant Improvements in environmental performance, compared to today`s coal-fired power plants. Sulfur dioxide and nitrogen oxide emissions from IGCC systems will be less than one-tenth of existing environmental standards. Thus, the IGCC technology will make coal-based plants as clean as plants that bum natural gas.

Bajura, R.A.; Schmidt, D.K.

1993-06-01T23:59:59.000Z

125

Kemper County IGCC (tm) Project Preliminary Public Design Report  

SciTech Connect

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

126

CoalFleet Guideline for Advanced Pulverized Coal Power Plants  

Science Conference Proceedings (OSTI)

The CoalFleet Guideline for Advanced Pulverized Coal Power Plants provides an overview of state-of-the art and emerging technologies for pulverized coal-fired generating units along with lessons learned for current plants worldwide. The Guideline aims to facilitate the timely deployment of reliable, next-generation generating units that incorporate: Higher steam conditions for higher efficiency and reduced generation of pollutants Advanced environmental controls for reduced emissions and environmental im...

2007-03-30T23:59:59.000Z

127

IGCC rides a regulatory seesaw  

SciTech Connect

The Mesaba Energy Project to build a 603 MW IGCC power plant in Minnesota's Iron Range may or may not go ahead. Developers have proposed incorporating carbon capture and sequestration (CCS), including a pipeline. Opponents insist Mesaba should not go ahead unless it uses CCS immediately. Until November the project looked on the road to recovery but then the regulators came close to derailing the project citing recent delays and cancellations of IGCC projects in Florida, Colorado and Arizona. The next step is to work with the US DOE to structure the loan guarantee and to work with regulators in Minnesota to structure an off-take plan. 1 photo.

Blankinship, S.

2007-11-15T23:59:59.000Z

128

Coal Power Plant Database | Open Energy Information  

Open Energy Info (EERE)

Power Plant Database Power Plant Database Jump to: navigation, search Name Coal Power Plant Database Data Format Excel Spreadsheet, Excel Pivot Table, Access Database Geographic Scope United States TODO: Import actual dataset contents into OpenEI The Coal Power Plant Database (CPPDB) is a dataset which "consolidates large quantities of information on coal-fired power plants in a single location."[1] It is produced by the National Energy Technology Laboratory (NETL). External links 2007 Edition Excel Spreadsheet Excel Pivot Table Access Database User's Manual (PDF) References ↑ "User's Manual: Coal Power Plant Database" Retrieved from "http://en.openei.org/w/index.php?title=Coal_Power_Plant_Database&oldid=273301" Categories: Datasets Articles with outstanding TODO tasks

129

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

SciTech Connect

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.

1996-12-01T23:59:59.000Z

130

Integrated gasification-combined-cycle power plants - Performance and cost estimates  

SciTech Connect

Several studies of Integrated Gasification-combined-cycle (IGCC) power plants have indicated that these plants have the potential for providing performance and cost improvements over conventional coal-fired steam power plants with flue gas desulfurization. Generally, IGCC power plants have a higher energy-conversion efficiency, require less water, conform with existing environmental standards at lower cost, and are expected to convert coal to electricity at lower costs than coal-fired steam plants. This study compares estimated costs and performance of various IGCC plant design configurations. A second-law analysis identifies the real energy waste in each design configuration. In addition, a thermoeconomic analysis reveals the potential for reducing the cost of electricity generated by an IGCC power plant.

Tsatsaronis, G.; Tawfik, T.; Lin, L. (Tennessee State Univ., Nashville (USA))

1990-04-01T23:59:59.000Z

131

Pages that link to "Coal Power Plant Database" | Open Energy...  

Open Energy Info (EERE)

Edit History Share this page on Facebook icon Twitter icon Pages that link to "Coal Power Plant Database" Coal Power Plant Database Jump to: navigation, search What...

132

Changes related to "Coal Power Plant Database" | Open Energy...  

Open Energy Info (EERE)

Special page Share this page on Facebook icon Twitter icon Changes related to "Coal Power Plant Database" Coal Power Plant Database Jump to: navigation, search This is...

133

Microsoft Word - CurrentFutureIGCC2Revisionfinal.doc  

NLE Websites -- All DOE Office Websites (Extended Search)

M T R - 2 0 0 4 - 0 5 Mitretek Technical Report Current and Future IGCC Technologies: Bituminous Coal to Power AUGUST 2004 David Gray Salvatore Salerno Glen Tomlinson Customer:...

134

PinonPine IGCC Power Project: A DOE Assesment  

NLE Websites -- All DOE Office Websites (Extended Search)

turbine, the IGCC process can also be modified to produce value-added chemicals or transportation fuels from coal by chemical processing of the CO and H 2 in the fuel gas...

135

Coal-Fired Power Plants  

NLE Websites -- All DOE Office Websites (Extended Search)

Impacts of TMDLs on Impacts of TMDLs on Coal-Fired Power Plants April 2010 DOE/NETL-2010/1408 Disclaimer This report was prepared as an account of work sponsored by an agency of the United States Government. Neither the United States Government nor any agency thereof, nor any of their employees, makes any warranty, express or implied, or assumes any legal liability or responsibility for the accuracy, completeness, or usefulness of any information, apparatus, product, or process disclosed, or represents that its use would not infringe privately owned rights. Reference therein to any specific commercial product, process, or service by trade name, trademark, manufacturer, or otherwise does not necessarily constitute or imply its endorsement, recommendation, or favoring by the United States Government or any agency thereof. The

136

Designing and upgrading plants to blend coal  

SciTech Connect

Fuel flexibility isn't free. Whether you are equipping a new power plant to burn more than one type of coal or retrofitting an existing plant to handle coal blends, you will have to spend time and money to ensure that all three functions performed by its coal-handling system, unloading, stockout, and reclaim, are up to the task. The first half of this article lays out the available options for configuring each subsystem to support blending. The second half describes, in words and pictures, how 12 power plants in the USA, both new and old, address the issue. 9 figs., 1 tab.

McCartney, R.H. [Roberts and Schaefer Co. (United States)

2006-10-15T23:59:59.000Z

137

PINON PINE: An advanced IGCC demonstration  

SciTech Connect

The Pinon Pine Power Project is a second generation integrated gasification combined cycle (IGCC) power plant, located at Sierra Pacific Power Company`s (SPPC) Tracy Station, 17 miles east of Reno, Nevada. The project is being partially funded under the Department of Energy`s (DOE`s) Clean Coal Technology Program (CCT). SPPC intends to operate the plant in base-load mode to supply approximately 100 megawatts electric (MWe) to the transmission grid. This plant will be the first full-scale integration of several advanced technologies: an air-blown KRW gasifier; full-stream hot gas desulfurization using a transport reactor system with a zinc-based sorbent; full-stream, high-temperature ceramic filters for particulate removal; the General Electric Model MS6001FA (617A) Gas Turbine Engine/generator, and a 950 pound per square inch absolute (psia), 950{degrees}F steam turbine generator. This paper reviews the overall configuration and integration of the gasification and power islands components, which yield the plant`s high efficiency. Current status of the project is addressed.

Freier, M.D.; Jewell, D.M. [Morgantown Energy Technology Center, WV (United States); Motter, J.W. [Sierra Pacific Power Co., Reno, NV (United States)

1996-04-01T23:59:59.000Z

138

NETL: News Release - DOE-Sponsored IGCC Project in Texas Takes Important  

NLE Websites -- All DOE Office Websites (Extended Search)

1, 2011 1, 2011 DOE-Sponsored IGCC Project in Texas Takes Important Step Forward MOU Provides for Electricity Purchase from First-of-a-Kind Commercial IGCC Power Plant Washington, DC - A newly signed memorandum of understanding (MOU) for the purchase of electricity produced by the Texas Clean Energy Project (TCEP) is an important step forward for what will be one of the world's most advanced and cleanest coal-based power plants, funded in part by the U.S. Department of Energy (DOE). Under the MOU, CPS Energy - a municipally owned utility serving San Antonio, Texas - will purchase electricity generated by the first-of-a-kind commercial clean coal power plant, starting in mid 2014. TCEP, a 400-megawatt integrated gasification combined cycle (IGCC) facility located about 15 miles west of Odessa, will capture 90 percent of its carbon dioxide (CO2) - approximately 3 million tons annually - more than any power plant of commercial scale operating anywhere in the world.

139

Design Options for Enhancing IGCC Flexible Operations Performance and Economics  

Science Conference Proceedings (OSTI)

This report describes the cycling experience of integrated-gasification combined-cycle (IGCC) plants and the characteristics of IGCC and its component technologies that can make it particularly responsive to renewables-driven, flexible operation and cycling requirements. It also identifies a number of design options for optimizing IGCC cycling performance and economics for such requirements.BackgroundIntermittent renewable sources, such as wind and solar ...

2012-12-31T23:59:59.000Z

140

A utility`s perspective of the market for IGCC  

SciTech Connect

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

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.


141

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

142

Existing Coal-fired Power Plants  

NLE Websites -- All DOE Office Websites (Extended Search)

Water Vulnerabilities for Existing Coal-fired Power Plants August 2010 DOENETL-20101429 Disclaimer This report was prepared as an account of work sponsored by an agency of the...

143

IGCC update: are we there yet?  

Science Conference Proceedings (OSTI)

If a number of technical, financial and regulatory hurdles can be overcome, power generated by integrated gasification combined-cycle technology could become an important source for US utilities. Our overview presents diverse perspectives from three industry experts about what it will take to move this technology off the design table and into the field. Well-known advantages are IGCC uses less water, creates a usable slag by-product and the technology required for pre-combustion CO{sub 2} capture has already been used successfully on coal gasification technology. These points, together with roadblocks to the deployment of IGCC technology in the USA, are discussed. 3 figs., 1 tab.

Neville, A.

2009-08-15T23:59:59.000Z

144

Decommissioning Handbook for Coal-Fired Power Plants  

Science Conference Proceedings (OSTI)

This handbook lays out the steps necessary to fully decommission a coal-fired power plant. The handbook includes ways to handle permitting, environmental cleanup, site dismantlement, and site remediation, and discusses overall decommissioning costs. It is based on three actual case studies of coal plants recently decommissioned: the Arkwright coal-fired plant of Georgia Power, the Watts Bar coal-fired plant of TVA, and the Port Washington coal-fired plant of Wisconsin Electric Power.

2004-11-04T23:59:59.000Z

145

Uncertainty analysis of an IGCC system with single-stage entrained-flow gasifier  

Science Conference Proceedings (OSTI)

Integrated Gasification Combined Cycle (IGCC) systems using coal gasification is an attractive option for future energy plants. Consequenty, understanding the system operation and optimizing gasifier performance in the presence of uncertain operating conditions is essential to extract the maximum benefits from the system. This work focuses on conducting such a study using an IGCC process simulation and a high-fidelity gasifier simulation coupled with stochastic simulation and multi-objective optimization capabilities. Coal gasifiers are the necessary basis of IGCC systems, and hence effective modeling and uncertainty analysis of the gasification process constitutes an important element of overall IGCC process design and operation. In this work, an Aspen Plus{reg_sign} steady-state process model of an IGCC system with carbon capture enables us to conduct simulation studies so that the effect of gasification variability on the whole process can be understood. The IGCC plant design consists of an single-stage entrained-flow gasifier, a physical solvent-based acid gas removal process for carbon capture, two model-7FB combustion turbine generators, two heat recovery steam generators, and one steam turbine generator in a multi-shaft 2x2x1 configuration. In the Aspen Plus process simulation, the gasifier is represented as a simplified lumped-parameter, restricted-equilibrium reactor model. In this work, we also make use of a distributed-parameter FLUENT{reg_sign} computational fluid dynamics (CFD) model to characterize the uncertainty for the entrained-flow gasifier. The CFD-based gasifer model is much more comprehensive, predictive, and hence better suited to understand the effects of uncertainty. The possible uncertain parameters of the gasifier model are identified. This includes input coal composition as well as mass flow rates of coal, slurry water, and oxidant. Using a selected number of random (Monte Carlo) samples for the different parameters, the CFD model is simulated to observe the variations in the output variables (such as syngas composition, gas and ash flow rates etc.). The same samples are then used to conduct simulations using the Aspen Plus IGCC model. The simulation results for the high-fidelity CFD-based gasifier model and the Aspen Plus equilibrium reactor model for selected uncertain parameters are then used to perform the estimation. Defining the ratio of CFD based results to the Aspen Plus result as the uncertainty factor (UF), the work quantifies the extent of uncertainty and then uses uniform* distribution to characterize the uncertainty factor distribution. The characterization and quantification of uncertainty is then used to conduct stochastic simulation of the IGCC system in Aspen Plus. The CAPE-OPEN compliant stochastic simulation capability allows one to conduct a rigorous analysis and generate the feasible space for the operation of the IGCC system. The stochastic simulation results can later be used to conduct multi-objective optimization of the gasifier using a set of identified decision variables. The CAPE-OPEN compliant multi-objective capability in Aspen Plus can be used to conduct the analysis. Since the analysis is based on the uncertainty modeling studies of the gasifier, the optimization accounts for possible uncertainties in the operation of the system. The results for the optimized IGCC system and the gasifier, obtained from the stochastic simulation results, are expected to be more rigorous and hence closer to those obtained from CFD-based rigorous modeling.

Shastri, Y.; Diwekar, U.; Zitney, S.

2008-01-01T23:59:59.000Z

146

Clean Coal Technology Demonstration Projects -- Operating Experience and Risk Assessment Through September 1998  

Science Conference Proceedings (OSTI)

Clean coal technologies such as Integrated Gasification Combined Cycle (IGCC) and Pressurized Fluidized Bed Combustion (PFBC) can meet stringent emission standards and achieve high efficiencies. Commercial and near-commercial sized plants using these technologies have accumulated several years of operational experience and are serious candidates for new coal-based power plants.

1998-12-18T23:59:59.000Z

147

Technical Status, Operating Experience, and Risk Assessment of Clean Coal Technologies - 2002  

Science Conference Proceedings (OSTI)

Conventional pulverized coal (PC) plants provide the base line competition for the newer clean coal technologies (CCTs) such as ultra supercritical (USC) PC, atmospheric and pressurized fluidized bed combustion (AFBC and PFBC), and integrated gasification combined cycle (IGCC) plants that are now accumulating commercial experience. This topical report describes recent experience with the various CCTs and discusses prospects for their further deployment.

2002-11-06T23:59:59.000Z

148

Technical Status, Operating Experience and Risk Assessment of Clean Coal Technologies - 2001  

Science Conference Proceedings (OSTI)

Conventional pulverized coal (PC) plants provide the baseline competition for newer clean coal technologies (CCTs) such as ultra supercritical (USC) PC, atmospheric and pressurized fluidized bed combustion (AFBC and PFBC), and integrated gasification combined-cycle (IGCC) plants that are now accumulating commercial experience.

2001-12-06T23:59:59.000Z

149

Operating Experience and Risk Assessment of Clean Coal Technologies 1999  

Science Conference Proceedings (OSTI)

Recent advances in ultra super-critical (USC) pulverized coal (PC) and atmospheric fluidized bed combustion (AFBC) plants provide the base line competition for the newer clean coal technologies (CCTs). Integrated gasification combined cycle (IGCC) and pressurized fluidized bed combustion (PFBC) are examples of CCTs now accumulating commercial experience.

1999-12-06T23:59:59.000Z

150

Operating Experience and Risk Assessment of Clean Coal Technologies -- 2000  

Science Conference Proceedings (OSTI)

Recent advances in ultra-supercritical (USC) pulverized coal (PC) and atmospheric fluidized bed combustion (AFBC) plants provide the baseline competition for the newer clean coal technologies (CCTs). Integrated gasification combined cycle (IGCC) and pressurized fluidized bed combustion (PFBC) are examples of CCTs now accumulating commercial experience.

2000-12-04T23:59:59.000Z

151

CoalFleet Integrated Gasification Combined Cycle Research and Development Roadmap  

Science Conference Proceedings (OSTI)

This report is an update of EPRI technical report 1013219, “CoalFleet RD&D Augmentation Plan for Integrated Gasification Combined Cycle (IGCC) Power Plants” that was published in January 2007. The purpose of the current study is to evaluate the state of IGCC technology, gauge technology development progress made since 2007, and discuss updated estimates on the potential for advanced technologies to improve power plant performance and economics. The report consists of the following four parts: establishme...

2011-10-31T23:59:59.000Z

152

NETL: News Release - Advanced Coal Dryer Boosts Power Plant Performanc...  

NLE Websites -- All DOE Office Websites (Extended Search)

Release Date: May 24, 2006 Advanced Coal Dryer Boosts Power Plant Performance Latest Project in President's Clean Coal Power Initiative Begins Operations in North Dakota...

153

Steam Plant Replaces Outdated Coal-Fired System | Department...  

Energy.gov (U.S. Department of Energy (DOE)) Indexed Site

Steam Plant Replaces Outdated Coal-Fired System Steam Plant Replaces Outdated Coal-Fired System September 1, 2012 - 12:00pm Addthis A new natural gas-fired steam plant will replace...

154

Byproducts can make coal plants green  

Science Conference Proceedings (OSTI)

Co-locating ethanol plants at coal-burning sites, along with the use of biomass gasification to boost coal-fired plant output, can have positive economic and environmental benefits. Adding a biomass gasifier to an older coal-fired plant would inject gas with up to 10% of the fuel value in the coal and increase steam generation by the same amount. Sawdust can be injected as a reburn fuel without the need for gasification. A pre-scrubber would be added before the existing SO{sub 2} scrubber and waste heat from the boiler in the form of low-pressure steam would be sent to a co-located ethanol plant. This would lead to a decrease in emissions of NOx, mercury and SO{sub 2}, less mercury in the gypsum, a large greenhouse gas reduction, reduced net fuel cost, and revenue from hydrochloric acid by- product and from selling low-pressure steam to the ethanol plant. The Blue Flint Ethanol facility uses waste heat from Grand River Energy's 1,100 MW Coal Creek Station in South Jordan, Utah. The new generation of US ethanol plants is likely to use switchgrass and other cellulosic materials as feedstock. Straw and other forms of biomass have high chlorine content. PVC waste can be added to optimise the chlorine content of the scrubber. A chlorine pre-scrubber before the SO{sub 2} scrubber would capture HCl. 1 fig., 1 photo.

McIlvaine, B. [McIlvaine Co. (United States)

2007-07-15T23:59:59.000Z

155

"Modern" Coal Plants  

NLE Websites -- All DOE Office Websites (Extended Search)

"Modern" Coal Plants "Modern" Coal Plants Nature Bulletin No. 331-A February 7, 1969 Forest Preserve District of Cook County George W. Dunne, President Roland F. Eisenbeis, Supt. of Conservation "MODERN" COAL PLANTS The Age of Cycads, when those strange tree-like plants predominated, began during the Triassic Period of the earth's geological history, reached its peak during the 60 million years of the Jurassic Period which followed, and ended during the first part of the Cretaceous Period that began about 95 million years ago. During the Jurassic, in addition to Cycades, there were also many species of ginkgos, and conifers which were the ancestors of our modern sequoias and pines. The ginkgo or "Maidenhair Tree", which we have imported from China and Japan, is the only one remaining of that tribe -- "a living fossil".

156

Boiler Materials for Ultrasupercritical Coal Power Plants  

Science Conference Proceedings (OSTI)

The U.S. Department of Energy (DOE) and the Ohio Coal Development Office (OCDO) have undertaken 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 the current generation of supercritical plants. This increased efficiency is expected to be achieved principally through the use of advanced ultrasupercritical (A-USC) steam conditions. Ultrasupercritical (USC...

2011-12-23T23:59:59.000Z

157

BOILER MATERIALS FOR ULTRASUPERCRITICAL COAL POWER PLANTS  

SciTech Connect

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

158

BOILER MATERIALS FOR ULTRASUPERCRITICAL COAL POWER PLANTS  

Science Conference Proceedings (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. 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 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

2003-01-20T23:59:59.000Z

159

BOILER MATERIALS FOR ULTRASUPERCRITICAL COAL POWER PLANTS  

Science Conference Proceedings (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. 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 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

2002-07-15T23:59:59.000Z

160

BOILER MATERIALS FOR ULTRASUPERCRITICAL COAL POWER PLANTS  

Science Conference Proceedings (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. 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 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

2002-10-15T23:59:59.000Z

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.


161

Making IGCC slag valuable  

SciTech Connect

All indications are that integrated gasification combined-cycle (IGCC) technology will play a major role in tomorrow's generation industry. But before it does, some by-products of the process must be dealt with, for example unburned carbon that can make IGCC slag worthless. Charah Inc.'s processing system, used at Tampa Electric's Polk Station for years, segregates the slag's constituents by size, producing fuel and building materials. 3 figs.

Wicker, K.

2005-12-01T23:59:59.000Z

162

Microsoft Word - 42651_UCI_ IGCC System Studies_rev060701.doc  

NLE Websites -- All DOE Office Websites (Extended Search)

1_UCI_ IGCC System Studies_rev060701.doc, Revised 7/06 1_UCI_ IGCC System Studies_rev060701.doc, Revised 7/06 Regents of the University of California, DE-FC26-05NT42652 (University of California Irvine, UCI) FACT SHEET I. PROJECT PARTICIPANTS A. Prime Participant: UCI, 300 University Tower, Irvine, CA 92697-7600 B. Sub-Award Participants: None II. PROJECT DESCRIPTION A. Objectives. Characterize advanced Brayton Cycles for coal derived fuels to be candidates for executing conceptual designs (systems studies). Develop conceptual plant designs for near term technologies followed by conceptual designs that integrate advanced technologies. In these studies identify key variables for purpose of sensitivity analysis used in a quest for establishing optimal cycles. Some examples of variables are firing temperature, pressure ratio, combustion

163

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  

Science Conference Proceedings (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

164

Southern Company Services' study of a Kellogg Rust Westinghouse (KRW)-based gasification-combined-cycle (GCC) power plant  

SciTech Connect

A site-specific evaluation of an integrated-gasification-combined- cycle (IGCC) unit was conducted by Southern Company Services, Inc. (SCS) to determine the effect of such a plant would have on electricity cost, load response, and fuel flexibility on the Southern electric system (SES). The design of the Plant Wansley IGCC plant in this study was configured to utilize three oxygen-blown Kellogg Rust Westinghouse (KRW) gasifiers integrated with two General Electric (GE) MS7001F combustion turbines. The nominal 400-MW IGCC plant was based on a nonphased construction schedule, with an operational start date in the year 2007. Illinois No. 6 bituminous coal was the base coal used in the study. Alabama lignite was also investigated as a potential low-cost feedstock for the IGCC plant, but was found to be higher in cost that the Illinois No. 6 coal when shipped to the Wansley site. The performance and cost results for the nominal 400-MW plant were used in an economic assessment that compared the replacement of a 777-MW pulverized-coal-fired unit with 777-MW of IGCC capacity based on the Southern electric system's expansion plans of installing 777-MW of baseload capacity in the year 2007. The economic analysis indicated that the IGCC plant was competitive compared to a baseload pulverized-coal-fired unit. Capital costs of the IGCC unit were approximately the same as a comparably sized pulverized-coal-fired plant, but the IGCC plant had a lower production cost due to its lower heat rate. 10 refs., 34 figs., 18 tabs.

Gallaspy, D.T.; Johnson, T.W.; Sears, R.E. (Southern Co. Services, Inc., Birmingham, AL (USA))

1990-07-01T23:59:59.000Z

165

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

Science Conference Proceedings (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

166

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

SciTech Connect

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

167

Aerosol nucleation in coal-fired power-plant plumes  

Science Conference Proceedings (OSTI)

New-particle nucleation within coal-fired power-plant plumes can have large effects on particle number concentrations

2013-01-01T23:59:59.000Z

168

CoalFleet Guideline for Advanced Pulverized Coal Power Plants  

Science Conference Proceedings (OSTI)

This report provides an overview of state-of-the-art and emerging technologies for pulverized coal (PC) fired generating units along with lessons learned from current plants worldwide. The report also facilitates the timely deployment of reliable, next-generation units that incorporate: Higher steam conditions for improved efficiency and reduced pollutants and CO2 Advanced environmental controls for reduced emissions and environmental impacts Techniques for CO2 capture, or for future retrofit of CO2 capt...

2007-09-30T23:59:59.000Z

169

CoalFleet Guideline for Advanced Pulverized Coal Power Plants  

Science Conference Proceedings (OSTI)

This report provides an overview of state-of-the-art and emerging technologies for pulverized coal (PC) fired generating units along with lessons learned from current plants worldwide. The report is designed to facilitate the timely deployment of reliable, next-generation units that incorporate higher steam conditions that improve efficiency and thereby decrease fuel consumption, CO2 emissions, and other environmental impacts; advanced environmental controls that reduce emissions and discharges of solid ...

2008-03-31T23:59:59.000Z

170

CoalFleet Guideline for Advanced Pulverized Coal Power Plants  

Science Conference Proceedings (OSTI)

This report provides an overview of state-of-the-art and emerging technologies for pulverized coal (PC-) fired generating units along with lessons learned from current plants worldwide. The report is designed to facilitate the timely deployment of reliable, next-generation units that incorporate higher steam conditions that improve efficiency and thereby decrease fuel consumption, CO2 emissions, and other environmental impacts; advanced environmental controls that reduce emissions and discharges of solid...

2010-09-30T23:59:59.000Z

171

Getting IGCC a seat at the table  

SciTech Connect

A dominant theme at the Gasification Technologies Conference in Washington, DC in early October was how all parties need to step up to assure integrated gasification combined cycle (IGCC) technology finds a place at the power generation table. That included a call for utilities and their ratepayers to be willing to accept more risk than they are accustomed to assuming. John Hofmeister, president and CEO of Shell Oil Company chided lawmakers and regulators for hindering progress by not adopting uniform regulations for carbon dioxide emissions. Among Shell's IGCC projects is Australia's equivalent of the United States' FutureGen Project - a 275 MW power production facility in Queensland that is expected to achieve 99.8% CO{sub 2} capture with sequestration and produce hydrogen. Randy Zwirn, president nd CEO of Siemens Power Generation, said OEMs must develop a philosophy for IGCC that he terms RAM - reliability, availability and maintainability. Texas Railroad Commissioner, Mike Williams described how his state has welcomed IGCC plants that can capture carbon and has established the groundwork for using or sequestrating it. Presentations reviewed in this article include status updates of more than a dozen IGCC projects underway. 1 photo.

Blankinship, S.

2006-11-15T23:59:59.000Z

172

Comparison of Pratt and Whitney Rocketdyne IGCC and commercial IGCC performance  

Science Conference Proceedings (OSTI)

This report compares the performance and cost of commercial Integrated Gasification Combined Cycle (IGCC) plants using General Electric Energy (GEE) and Shell gasifiers with conceptual IGCC plant designs using the Pratt and Whitney Rocketdyne (PWR) compact gasifier. the PWR gasifier is also compared with the GEEE gasifier in hydrogen production and carbon capture mode. With the exception of the PWR gasifier, the plants are designed with commercially available equipment to be operational in approximately 2010. All results should be considered preliminary and dictated in large part by the selected design basis. 10 refs., 54 exhibits

Jeffrey Hoffmann; Jenny Tennant; Gary J. Stiegel [Office of Systems Analysis and Planning (United States)

2006-06-15T23:59:59.000Z

173

Value Operating Flexibility in Advanced Coal Plants  

Science Conference Proceedings (OSTI)

This report describes a preliminary study of the potential value of the operating flexibility available from advanced coal plant designs and carbon capture and storage (CCS) systems. Assessing value requires new analytical approaches capable of examining plant outputs (e.g., syngas, air products, electricity, emissions) in the context of varying power market conditions and significant climate policy and fuel price uncertainties. Accounting for flexibility options in capacity planning may create opportuni...

2009-12-22T23:59:59.000Z

174

NREL: Technology Transfer - First Hybrid CSP-Coal Power Plant ...  

First Hybrid CSP-Coal Power Plant is Fired Up in Colorado July 23, 2010. On June 30, Xcel Energy began operating an experimental power plant near ...

175

Comprehensive report to Congress Clean Coal Technology Program  

SciTech Connect

This project will demonstrate Integrated Gasification Combined Cycle (IGCC) technology in a commercial application by the repowering of an existing City Water, Light and Power (CWL P) Plant in Springfield, Illinois. The project duration will be 126 months, including a 63-month demonstration period. The estimated cost of the project is $270,700,000 of which $129,357,204 will be funded by DOE. The IGCC system will consist of CE's air-blown, entrained-flow, two-stage, pressurized coal gasifier; an advanced hot gas cleanup process; a combustion turbine modified to use low Btu coal gas; and all necessary coal handling equipment. An existing 25-MWe steam turbine and associated equipment will also be part of the IGCC system. The result of repowering will be an IGCC power plant with low environmental emissions and high net plant efficiency. The repowering will increase plant output by 40 MWe through addition of the combustion turbine, thus providing a total IGCC capacity of a nominal 65 MWe. 3 figs., 2 tabs.

Not Available

1990-10-01T23:59:59.000Z

176

Development of a hot-gas desulfurization system for IGCC applications  

SciTech Connect

Integrated gasification combined cycle (IGCC) power plants are being advanced worldwide to produce electricity from coal because of their superior environmental performance, economics, and efficiency in comparison to conventional coal-based power plants. One key component of an advanced IGCC power plant is a hot-gas desulfurization system employing regenerable sorbents. To carry out hot-gas desulfurization in a fluidized-bed reactor, it is necessary that the sorbents have high attrition resistance, while still maintaining high chemical reactivity and sulfur absorption capacity. Also, efficient processes are needed for the treatment of SO{sub 2}-containing regeneration off-gas to produce environmentally benign waste or useful byproducts. A series of durable zinc titanate sorbents were formulated and tested in a bench-scale fluidized-bed reactor system. Reactive sorbents were developed with addition resistance comparable to fluid-bed cracking (FCC) catalysts used in petroleum refineries. In addition, progress continues on the development of the Direct Sulfur Recovery Process (DSRP) for converting SO{sub 2} in the regeneration off-gas to elemental sulfur. Plans are under way to test these bench-scale systems at gasifier sites with coal gas. This paper describes the status and future plans for the demonstration of these technologies.

Gupta, R.; McMichael, W.J.; Gangwal, S.K. [Research Triangle Inst., Research Triangle Park, NC (United States); Jain, S.C.; Dorchak, T.P. [USDOE Morgantown Energy Technology Center, WV (United States)

1992-12-31T23:59:59.000Z

177

Improved Refractory Materials for Slagging Gasifiers in IGCC Power Systems  

SciTech Connect

Gasifiers are the heart of Integrated Gasification Combined Cycle (IGCC) power system currently being developed as part of the DOE's Vision 21 Fossil Fuel Power Plant. A gasification chamber is a high pressure/high temperature reaction vessel used to contain a mixture of O2, H2O, and coal (or other carbon containing materials) while it is converted into thermal energy and chemicals (H2, CO, and CH4). IGCC systems are expected to play a dominant role in meeting the Nation's future energy needs. Gasifiers are also used to produce chemicals that serve as feedstock for other industrial processes, and are considered a potential source of H2 in applications such as fuel cells. A distinct advantage of gasifiers is their ability to meet or exceed current and anticipated future environmental emission regulations. Also, because gasification systems are part of a closed circuit, gasifiers are considered process ready to capture CO2 emissions for reuse or processing should that become necessary or economically feasible in the future. The service life of refractory liners for gasifiers has been identified by users as a critical barrier to IGC

Bennett, James P.; Kwong, Kyei-Sing; Powell, Cynthia A.; Krabbe, Rick; Thomas, Hugh

2005-01-01T23:59:59.000Z

178

Improved Refractory Materials for Slagging Gasifiers in IGCC Power Systems  

DOE Green Energy (OSTI)

Gasifiers are the heart of Integrated Gasification Combined Cycle (IGCC) power system currently being developed as part of the DOE's Vision 21 Fossil Fuel Power Plant. A gasification chamber is a high pressure/high temperature reaction vessel used to contain a mixture of O2, H2O, and coal (or other carbon containing materials) while it is converted into thermal energy and chemicals (H2, CO, and CH4). IGCC systems are expected to play a dominant role in meeting the Nation's future energy needs. Gasifiers are also used to produce chemicals that serve as feedstock for other industrial processes, and are considered a potential source of H2 in applications such as fuel cells. A distinct advantage of gasifiers is their ability to meet or exceed current and anticipated future environmental emission regulations. Also, because gasification systems are part of a closed circuit, gasifiers are considered process ready to capture CO2 emissions for reuse or processing should that become necessary or economically feasible in the future. The service life of refractory liners for gasifiers has been identified by users as a critical barrier to IGC

Bennett, James P.; Kwong, Kyei-Sing; Powell, Cynthia A.; Krabbe, Rick; Thomas, Hugh

2005-01-01T23:59:59.000Z

179

CURRENT AND FUTURE IGCC TECHNOLOGIES:  

NLE Websites -- All DOE Office Websites (Extended Search)

16, 2008 16, 2008 DOE/NETL-2008/1337 A Pathway Study Focused on Non-Carbon Capture Advanced Power Systems R&D Using Bituminous Coal - Volume 1 Current and Future IGCC Technologies Disclaimer This report was prepared as an account of work sponsored by an agency of the United States Government. Neither the United States Government nor any agency thereof, nor any of their employees, makes any warranty, express or implied, or assumes any legal liability or responsibility for the accuracy, completeness, or usefulness of any information, apparatus, product, or process disclosed, or represents that its use would not infringe privately owned rights. Reference therein to any specific commercial product, process, or service by trade name, trademark, manufacturer, or otherwise does not necessarily constitute or

180

IGCC Design Considerations for CO2 Capture  

Science Conference Proceedings (OSTI)

This report contains technical design, plant performance, cost estimates, and economic analysis of IGCC power plants designed with future retrofit for full CO2 capture in mind. The gasification technologies supplied by General Electric, Shell, and Siemens studied in the report were designed to initially produce power without CO2 capture; but their designs included moderate pre-investment to economically accommodate retrofit of full CO2 capture at a later date. The base plant designs include deep sulfur r...

2009-03-31T23:59:59.000Z

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.


181

DOE-Sponsored IGCC Project Could Lead to Lower-Cost Carbon Capture...  

Energy.gov (U.S. Department of Energy (DOE)) Indexed Site

manufactured catalysts can produce both power generation increases and significant cost savings at Integrated Gasification Combined Cycle (IGCC) power plants, according to...

182

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

SciTech Connect

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

Dalia Patino-Echeverri; Benoit Morel; Jay Apt; Chao Chen [Carnegie Mellon University, Pittsburgh, PA (USA)

2007-12-15T23:59:59.000Z

183

Third International Conference on Improved Coal-Fired Power Plants  

Science Conference Proceedings (OSTI)

This international conference reviewed advances in materials, components, and designs for coal-fired power plants. Also showcased were results from the EPRI improved power plant project, similar collaborative European projects, and new power plants in Japan. The proceedings' 54 papers contribute to an improved international understanding of advanced coal-fired power plant technology.

1992-09-01T23:59:59.000Z

184

Comparison of intergrated coal gasification combined cycle power plants with current and advanced gas turbines  

Science Conference Proceedings (OSTI)

Two recent conceptual design studies examined ''grass roots'' integrated gasification-combined cycle (IGCC) plants for the Albany Station site of Niagara Mohawk Power Corporation. One of these studies was based on the Texaco Gasifier and the other was developed around the British Gas Co.-Lurgi slagging gasifier. Both gasifiers were operated in the ''oxygen-blown'' mode, producing medium Btu fuel gas. The studies also evaluated plant performance with both current and advanced gas turbines. Coalto-busbar efficiencies of approximately 35 percent were calculated for Texaco IGCC plants using current technology gas turbines. Efficiencies of approximately 39 percent were obtained for the same plant when using advanced technology gas turbines.

Banda, B.M.; Evans, T.F.; McCone, A.I.; Westisik, J.H.

1984-08-01T23:59:59.000Z

185

Capturing carbon and saving coal  

SciTech Connect

Electric utilities face a tangle of choices when figuring how to pull CO{sub 2} from coal-fired plants. The article explains the three basic approaches to capturing CO{sub 2} - post-combustion, oxyfuel combustion and pre-combustion. Researchers at US DOE labs and utilities are investigating new solvents that capture CO{sub 2} more efficiently than amines and take less energy. Ammonium carbonate has been identified by EPRI as one suitable solvent. Field research projects on this are underway in the USA. Oxyfuel combustion trials are also being planned. Pre-combustion, or gasification is a completely different way of pulling energy from coal and, for electricity generation, this means IGCC systems. AEP, Southern Cinergy and Xcel are considering IGCC plants but none will capture CO{sub 2}. Rio Tinto and BP are planning a 500 MW facility to gasify coke waste from petroleum refining and collect and sequester CO{sub 2}. However, TECO recently dropped a project to build a 789 MW IGCC coal fired plant even though it was to receive a tax credit to encourage advanced coal technologies. The plant would not have captured CO{sub 2}. The company said that 'with uncertainty of carbon capture and sequestration regulations being discussed at the federal and state levels, the timing was not right'. 4 figs.

Johnson, J.

2007-10-15T23:59:59.000Z

186

NETL: Coal-Fired Power Plants (CFPPs)  

NLE Websites -- All DOE Office Websites (Extended Search)

NOx Sources NOx Sources Coal-Fired Power Plants (CFPPs) Causes of greenhouse gases, Including NOx What is NOx? Environmental Impacts NOx Sources Reduction Efforts Several greenhouse gases, including NOx, are increasing due to human activities in the following areas: Burning of fossil fuel (for example, coal-fired power plants), Logging (mainly contributes to carbon monoxide), Agriculture processes, Use of chlorofluorocarbons (CFC) in holon fire suppression and refrigeration The chart below shows the three major gases contributing to greenhouse gas emissions along with their source by sector. Annual Greenhouse Gas Emissions by Sector Note: This figure was created and copyrighted by Robert A. Rohde from published data and is part of the Global Warming Art project. This image is an original work created for Global Warming Art Permission is granted to copy, distribute and/or modify this image under either:

187

Coal gasification power plant and process  

DOE Patents (OSTI)

In an integrated coal gasification power plant, a humidifier is provided for transferring as vapor, from the aqueous blowdown liquid into relatively dry air, both (I) at least a portion of the water contained in the aqueous liquid and (II) at least a portion of the volatile hydrocarbons therein. The resulting humidified air is advantageously employed as at least a portion of the hot air and water vapor included in the blast gas supplied via a boost compressor to the gasifier.

Woodmansee, Donald E. (Schenectady, NY)

1979-01-01T23:59:59.000Z

188

Integrating Coal Gasification into a Rotary Kiln Electric Furnace Plant  

Science Conference Proceedings (OSTI)

Coal gasification is a potential alternative to conventional coal or natural gas- fired power plants ... Fundamentals of Spark-Plasma Sintering: Net-Shaping and Size Effects ... Investigation on a Microwave High-Temperature Air Heat Exchanger.

189

Coal stockpiles at electric power plants were above average ...  

U.S. Energy Information Administration (EIA)

Increased competition between fuels as well as a warm winter 2011-12 led to lower consumption of coal and, thus, higher coal stockpiles at electric power plants in ...

190

Coal stocks at power plants are likely sufficient despite river ...  

U.S. Energy Information Administration (EIA)

As of March 31, 2011, EIA estimates that coal-fired power plants in States identified in the map had an average of a two-to-three month supply of coal on hand.

191

Coal Gasification for Power Generation, 3. edition  

SciTech Connect

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

2007-11-15T23:59:59.000Z

192

Commercial gasifier for IGCC applications study report  

SciTech Connect

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

193

Engineering/Economic Evaluations of Advanced Coal Technologies  

Science Conference Proceedings (OSTI)

The continued escalation of power plant capital costs, legislative uncertainty with regard to CO2 emissions regulation, and widely fluctuating fuel prices make this an extremely challenging time for the power industry as they seek to make decisions on multi-billion dollar investments in needed new power plants. In this report the capital and operating costs, performance, and Costs of Electricity (COE) are estimated for various coals, locations, and coal technologies (PC, CFB and IGCC with and without CO2...

2008-09-25T23:59:59.000Z

194

Extractors manual for Integrated Gasification Combined Cycle Data Base System: Major Plants Data Base  

SciTech Connect

National concern over the depletion of conventional energy sources has prompted industry to evaluate coal gasification as an alternative source of energy. One approach being evaluated is gasifying coal in a gasifier and feeding the fuel gas to a combined-cycle power plant. This system is called an Integrated Gasification Combined-Cycle (IGCC) power plant. The US Department of Energy (DOE) is also encouraging the development of new technologies by sponsoring research and development (R and D) projects in IGCC. In order to make data generated from these projects available to government and private sector personnel, the IGCC Data System has been established. A technology-specific data system consists of data that are stored for that technology in each of the specialized data bases that make up the Morgantown Energy Technology Center (METC) data system. The IGCC Data System consists of data stored in the Major Plants Data Base (MPDB) and the Test Data Data Base (TDDB). To capture the results of government-sponsored IGCC research programs, documents have been written for the MPDB and TDDB to specify the data that contractors need to report and the procedures for reporting them. The IGCC documents identify and define the data that need to be reported for IGCC projects so that the data entered into the TDDB and MPDB will meet the needs of the users of the IGCC Data System. This document addresses what information is needed and how it must be formatted so that it can be entered into the MPDB for IGCC. The data that are most relevant to potential IGCC Data System users have been divided into four categories: project tracking needs; economic/commercialization needs; critical performance needs; and modeling and R and D needs. 4 figs., 28 tabs.

1986-11-01T23:59:59.000Z

195

Microsoft Word - 41889_GE_IGCC System Study_Factsheet_Rev0a_01...  

NLE Websites -- All DOE Office Websites (Extended Search)

System Study for Improved Gas Turbine Performance for Coal IGCC Application FACT SHEET Revision 0a Jan. 14, 2004 Page 1 of 3 I. PROJECT DESCRIPTION A. Objective: This study will...

196

Microsoft Word - 41889_GE_IGCC Syst Study_FactSheet_012405.doc  

NLE Websites -- All DOE Office Websites (Extended Search)

GE Energy 1 December 2004 Project No. DE-FC26-03NT41889 System Study For Improved Gas Turbine Performance For Coal IGCC Application Fact Sheet I Project Participants: A. Prime...

197

Microsoft Word - 41889_GE_IGCC System Study_Factsheet_Rev01_07...  

NLE Websites -- All DOE Office Websites (Extended Search)

Fact Sheet: "System Study For Improved Gas Turbine Performance For Coal IGCC Application" DOE Contract No: DE-FC26-03NT41889 I Project Description: A. Objective: This study will...

198

Bull Run Fossil Plant Online Coal Flow Adjustable Riffler Test  

Science Conference Proceedings (OSTI)

Boiler optimization at fossil-fired power plants would be enhanced if the flow of coal and air in individual pulverizer fuel delivery lines could be balanced. The static splitter devices currently in service do not adequately maintain coal balance, especially when plant conditions change. This report summarizes the results of a test program to demonstrate the feasibility of using a novel riffler to make online adjustments to a stream of pneumatically conveyed pulverized coal at a working plant. The demon...

2008-03-13T23:59:59.000Z

199

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

200

Baseload coal investment decisions under uncertain carbon legislation  

SciTech Connect

More than 50% of electricity in the U.S. is generated by coal. The U.S. has large coal resources, the cheapest fuel in most areas. Coal fired power plants are likely to continue to provide much of U.S. electricity. However, the type of power plant that should be built is unclear. Technology can reduce pollutant discharges and capture and sequester the CO{sub 2} from coal-fired generation. The U.S. Energy Policy Act of 2005 provides incentives for large scale commercial deployment of Integrated Coal Gasification Combined Cycle (IGCC) systems (e.g., loan guarantees and project tax credits). This analysis examines whether a new coal plant should be pulverized coal (PC) or IGCC. Do stricter emissions standards (PM, SO{sub 2}, NOx, Hg) justify the higher costs of IGCC over PC? How does potential future carbon legislation affect the decision to add carbon capture and storage (CCS) technology? Finally, can the impact of uncertain carbon legislation be minimized? We find that SO{sub 2}, NOx, PM, and Hg emission standards would have to be far more stringent than twice current standards to justify the increased costs of the IGCC system. A CO{sub 2} tax less than $29/ton would lead companies to continuing to choose PC, paying the tax for emitted CO{sub 2}. The earlier a decision-maker believes the carbon tax will be imposed and the higher the tax, the more likely companies will choose IGCC with CCS. Having government announce the date and level of a carbon tax would promote more sensible decisions, but government would have to use a tax or subsidy to induce companies to choose the technology that is best for society. 14 refs., 6 figs., 4 tabs.

Joule A. Bergerson; Lester B. Lave [University of Calgary, Calgary, AB (Canada)

2007-05-15T23:59:59.000Z

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.


201

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

NLE Websites -- All DOE Office Websites (Extended Search)

the transformation of power systems Flexible Coal Evolution from Baseload to Peaking Plant The experience cited in this paper is from a generating station with multiple units...

202

Optical Gas Sensors for Advanced Coal-Fired Power Plants  

Science Conference Proceedings (OSTI)

Presentation Title, Optical Gas Sensors for Advanced Coal-Fired Power Plants. Author(s), Paul Ohodnicki, Congjun Wang, Douglas Kauffman, Kristi Kauffman, ...

203

Combustion Engineering IGCC Repowering Project  

SciTech Connect

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

204

Combustion Engineering IGCC Repowering Project  

SciTech Connect

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

205

IGCC system studies  

Science Conference Proceedings (OSTI)

Systems studies are performed on both the currently available, but not fully demonstrated, integrated gasification combined-cycle (IGCC) technologies and the future technologies. The objective of these studies is to support and guide the Morgantown Energy Technology Center`s METC Strategic Product Planning efforts. Through these efforts, the research, development and demonstration needs of various alternative gasification and power island components can be quantified and factored into the overall planning processes.

Rath, L.K.

1994-10-01T23:59:59.000Z

206

Results Summary Investigating the Use of Liquid CO2 Coal Slurry for Feeding Low Rank Coal to the E-Gas™ Gasifier  

Science Conference Proceedings (OSTI)

This report summarizes the results of US Department of Energy (DOE) Award No. DE-FE0007977, Liquid CO2/Coal Slurry for Feeding Low Rank Coal to Gasifiers, which investigates the practicality of using a liquid CO2/coal slurry preparation and feed system for the E-Gas gasifier in an integrated-gasification–combined-cycle (IGCC) electric power generation plant configuration.Liquid CO2 (LCO2) has several property differences from water that ...

2013-12-11T23:59:59.000Z

207

DOE Science Showcase - Energy Plants of the Future | OSTI, US Dept of  

Office of Scientific and Technical Information (OSTI)

DOE Science Showcase - Energy Plants of the Future DOE Science Showcase - Energy Plants of the Future Advanced Integrated Gasification Combined Cycle Power Plants Advanced IGCC is a flexible technology for generating low-cost electricity while meeting all future environment requirements Secretary Chu Announces $14 Million for Six New Projects to Advance IGCC Technology DOE Press Release DOE-Sponsored IGCC Project in Texas Takes Important Step Forward, Fossil Energy Techline Gasification Technology R&D How Coal Gasification Power Plants Work 2010 Worldwide Gasification Database Follow NETL Gasification IGCC Research in DOE Databases Energy Citations Database Information Bridge Science.gov WorldWideScience.org Visit the Science Showcase homepage. OSTI Homepage Mobile Gallery Subscribe to RSS OSTI Blog Get Widgets Get Alert Services

208

Performance and risks of advanced pulverized-coal plants  

SciTech Connect

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

209

Illinois Coal Revival Program (Illinois)  

Energy.gov (U.S. Department of Energy (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...

210

Table 38. Coal Stocks at Coke Plants by Census Division  

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

Coal Stocks at Coke Plants by Census Division Coal Stocks at Coke Plants by Census Division (thousand short tons) U.S. Energy Information Administration | Quarterly Coal Report, April - June 2013 Table 38. Coal Stocks at Coke Plants by Census Division (thousand short tons) U.S. Energy Information Administration | Quarterly Coal Report, April - June 2013 Census Division June 30, 2013 March 31, 2013 June 30, 2012 Percent Change (June 30) 2013 versus 2012 Middle Atlantic w w w w East North Central 1,313 1,177 1,326 -1.0 South Atlantic w w w w East South Central w w w w U.S. Total 2,500 2,207 2,295 8.9 w = Data withheld to avoid disclosure. Note: Total may not equal sum of components because of independent rounding. Source: U.S. Energy Information Administration (EIA), Form EIA-5, 'Quarterly Coal Consumption and Quality Report - Coke Plants.'

211

NETL: Clean Coal Technology Demonstration Program (CCTDP) - Round 2  

NLE Websites -- All DOE Office Websites (Extended Search)

Combustion Engineering IGCC Repowering Project - (There is no Project Brief for this project) Combustion Engineering IGCC Repowering Project - (There is no Project Brief for this project) ABB Combustion Engineering, Inc. Program Publications Annual/Quarterly Technical Reports IGCC Repowering Project, Clean Coal II Project, Annual Report, (Oct 1992 - (Sept 1993 [PDF-7MB] (Oct1993) Annual Report, January - December 1992. U.S. Department of Energy report DOE/MC/26308-3645 (Available from NTIS as DE94004063). Interim Reports Use of the Lockheed Kinetic Extruder for Coal Feeding, Topical Report (Feb 1994) U.S. Department of Energy report DOE/MC/26308-3646 (Available from NTIS as DE94004066) Controls and Instrumentation, Topical Report (Dec 1993) U.S. Department of Energy report DOE/MC/26308-3648 (Available from NTIS as DE94004068) Topical Report: Sulfuric Acid Plant, Topical Report (Dec 1993)

212

BOILER MATERIALS FOR ULTRASUPERCRITICAL COAL POWER PLANTS  

Science Conference Proceedings (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

213

Boiler Materials for Ultrasupercritical Coal Power Plants  

Science Conference Proceedings (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

214

Boiler Materials for Ultrasupercritical Coal Power Plants  

Science Conference Proceedings (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

215

BOILER MATERIALS FOR ULTRASUPERCRITICAL COAL POWER PLANTS  

Science Conference Proceedings (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

216

BOILER MATERIALS FOR ULTRASUPERCRITICAL COAL POWER PLANTS  

Science Conference Proceedings (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

217

BOILER MATERIALS FOR ULTRASUPERCRITICAL COAL POWER PLANTS  

Science Conference Proceedings (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

218

Boiler Materials for Ultrasupercritical Coal Power Plants  

Science Conference Proceedings (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

219

Boiler Materials for Ultrasupercritical Coal Power Plants  

Science Conference Proceedings (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

220

Boiler Materials For Ultrasupercritical Coal Power Plants  

Science Conference Proceedings (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

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.


221

Cost and carbon emissions of coal and combined cycle power plants...  

NLE Websites -- All DOE Office Websites (Extended Search)

Cost and carbon emissions of coal and combined cycle power plants in India: international implications Title Cost and carbon emissions of coal and combined cycle power plants in...

222

Direct coal-fired gas turbines for combined cycle plants  

SciTech Connect

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

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

1993-11-01T23:59:59.000Z

223

IGCC: Current Status and Future Potential  

NLE Websites -- All DOE Office Websites (Extended Search)

Impact of Developing Technologies on the Impact of Developing Technologies on the Economics and Performance of Future IGCC Power Plants John Plunkett, Noblis David Gray, Noblis Charles White, Noblis Julianne Klara, NETL Copyright © 2008 Noblis, Inc. 2 Acknowledgement This work is sponsored by the U.S. Department of Energy, National Energy Technology Laboratory 3 Study Objective Starting with present-day baseline, evaluate improved IGCC performance and cost resulting from DOE-funded R&D over the next 18 years. Examine both with and without CO 2 capture. Study results will help to prioritize technology development based on relative impact. Results will also help to assess the impact of future potential CO 2 emissions restrictions. 4 Methodology * Use Aspen Plus simulator to provide model "transparency"

224

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

Science Conference Proceedings (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

225

Combustion characterization of the blend of plant coal and recovered coal fines  

SciTech Connect

The overall objective of this proposed research program is to determine the combustion characteristics of the blend derived from mixing a plant coal and recovered and clean coal fines from the pond. During this study, one plant coal and three blend samples will be prepared and utilized. The blend samples will be of a mixture of 90% plant coal + 10% fines, 85% plant coal + 15% fines, 80% plant coal + 20% fines having particle size distribution of 70% passing through {minus}200 mesh size. These samples' combustion behavior will be examined in two different furnaces at Penn State University, i.e., a down-fired furnace and a drop-tube furnace. The down-fired furnace will be used mainly to measure the emissions and ash deposition study, while the drop tube furnace will be used to determine burning profile, combustion efficiency, etc. This report covers the first quarter's progress. Major activities during this period were focused on finding the plants where a demo MTU column will be installed to prepare the samples needed to characterize the combustion behavior of slurry effluents. Also, a meeting was held at Penn State University to discuss the availability of the laboratory furnace for testing the plant coal/recovered coal fines blends.

Singh, Shyam.

1991-01-01T23:59:59.000Z

226

Operating Experience, Risk and Market Assessment of Clean Coal Technologies - 2004  

Science Conference Proceedings (OSTI)

Conventional pulverized coal (PC) plants provide the base line competition for the newer clean coal technologies (CCTs) such as ultra supercritical (USC) PC, atmospheric fluidized bed combustion (AFBC), and integrated gasification combined cycle (IGCC) plants that are now accumulating commercial experience. The objectives of these annual reports from EPRI are to: • Assess the state-of-the-art for design, operating experience and lessons learned of the various competing technologies. • Evaluate ...

2004-12-27T23:59:59.000Z

227

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 by using a combination of radiant/convective waste heat boiler or by direct water quench before processing of the raw gas. The selection of an optimum heat recovery system is a function of the product slate, overall economics, and the technical risks associated with the heat recovery equipment. An extensive use of heat recovery equipment is not necessarily more economical than a simpler system with modest thermal efficiency. A full heat recovery mode consisting of radiant and convective boilers along with economizers is recommended for Coal Gasification Combined Cycle to maximize energy efficiency. A water quench mode is suggested for hydrogen production because of the need to adjust the H2O/CO ratio for shift conversion. A partial heat-recovery mode is recommended for power/methanol co-production plant. These heat recovery systems are discussed in detail along with the economics associated with each system.

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

1982-01-01T23:59:59.000Z

228

Corrosion protection pays off for coal-fired power plants  

Science Conference Proceedings (OSTI)

Zinc has long been used to hot-dip galvanise steel to deliver protection in harsh environments. Powder River Basin or eastern coal-fired plants benefit from using galvanized steel for conveyors, vibratory feeders, coal hoppers, chutes, etc. because maintenance costs are essentially eliminated. When life cycle costs for this process are compared to an alternative three-coal paint system for corrosion protection, the latter costs 5-10 times more than hot-dip galvanizing. An AEP Power Plant in San Juan, Puerto Rico and the McDuffie Coal Terminal in Mobile, AL, USA have both used hot-dip galvanized steel. 1 fig., 1 tab.

Hansen, T.

2006-11-15T23:59:59.000Z

229

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 · Coal-fired Power Plant: Supercritical pulverized coal (SC PC) Illinois #6 Coal Capacity Factor 75

230

Demonstration Development Project: Evaluation of a Test Loop to Demonstrate Handling Properties of Liquid CO2-Coal Slurry  

Science Conference Proceedings (OSTI)

Integrated gasification combined cycle (IGCC) power plants employing liquid CO2 in lieu of water as the slurrying medium to feed coal to the gasifier are a promising option for carbon capture and storage (CCS). This report summarizes the design and cost estimate for a proposed CO2-coal slurry test loop system. The objective is to validate a cost estimate for the construction of a full scale CO2-coal slurry test loop and aid in technical aspects of working with ...

2014-01-07T23:59:59.000Z

231

Effects of Coal Quality on Power Plant Performance and Costs, Volume 4: Review of Coal Science Fundamentals  

Science Conference Proceedings (OSTI)

The costs of generating electricity in a coal-fired power plant depend not only on the delivered cost of coal but on how coal quality affects plant performance. Utilities need to account for both these factors to decide which coals provide the most power at the lowest cost.

1986-03-04T23:59:59.000Z

232

Phased Construction of Natural Gas Combined-Cycle Plants with Coal Gasification and CO2 Recovery  

Science Conference Proceedings (OSTI)

This report is a brief review of technologies and key issues involved in a phased construction approach for a low-emission integrated-gasification-combined-cycle (IGCC) plant where carbon dioxide (CO2) removal for use or sequestration can be added at a later date.

2002-10-10T23:59:59.000Z

233

Tracking new coal-fired power plants: coal's resurgence in electric power generation  

Science Conference Proceedings (OSTI)

This information package is intended to provide an overview of 'Coal's resurgence in electric power generation' by examining proposed new coal-fired power plants that are under consideration in the USA. The results contained in this package are derived from information that is available from various tracking organizations and news groups. Although comprehensive, this information is not intended to represent every possible plant under consideration but is intended to illustrate the large potential that exists for new coal-fired power plants. It should be noted that many of the proposed plants are likely not to be built. For example, out of a total portfolio (gas, coal, etc.) of 500 GW of newly planned power plant capacity announced in 2001, 91 GW have been already been scrapped or delayed. 25 refs.

NONE

2007-05-01T23:59:59.000Z

234

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

SciTech Connect

This is the ninth 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, comparative analyses were performed for lignite and PRB coals to determine how unit performance varies with coal product moisture. Results are given showing how the coal product moisture level and coal rank affect parameters such as boiler efficiency, station service power needed for fans and pulverizers and net unit heat rate. Results are also given for the effects of coal drying on cooling tower makeup water and comparisons are made between makeup water savings for various times of the year.

Edward Levy; Nenad Sarunac; Harun Bilirgen; Wei Zhang

2005-04-01T23:59:59.000Z

235

Process Engineering Division Texaco Gasifier IGCC Base Cases  

NLE Websites -- All DOE Office Websites (Extended Search)

Engineering Division Engineering Division Texaco Gasifier IGCC Base Cases PED-IGCC-98-001 July 1998 Latest Revision June 2000 PREFACE This report presents the results of an analysis of three Texaco Gasifier IGCC Base Cases. The analyses were performed by W. Shelton and J. Lyons of EG&G. EXECUTIVE SUMMARY 1. Process Descriptions 1.1 Texaco Gasifier 1.2 Air Separation Plant (ASU) 1.3 Gas Cooling/Heat Recovery/Hydrolysis/Gas Saturation (Case 1 and Case 2) 1.4 Cold Gas Cleanup Unit (CGCU) (Case 1 and Case 2) 1.5 Fine Particulate Removal/ Chloride Guard Bed - Case 3 1.6 Transport Desulfurization HGCU - Case 3 1.7 Sulfuric Acid Plant - Case 3 1.8 Gas Turbine 1.9 Steam Cycle 1.10 Power Production 2. Simulation Development 3. Cost of Electricity Analysis

236

Mercury Removal Characteristics of Coal-Fired Power Plants  

Science Conference Proceedings (OSTI)

The standard Ontario Hydro Method (OHM) was used into the flue gas mercury sampling before and after fabric filter (FF)/ electrostatic precipitator (ESP) locations in coal-fired power stations in China, and then various mercury speciation, Hg0, Hg2+ ... Keywords: coal-fired power plant, mercury, fabric filter, electrostatic precipitator

Yang Liguo, Fan Xiaoxu, Duanyu Feng, Wang Yunjun

2013-01-01T23:59:59.000Z

237

CE IGCC repowering project preliminary hazard analysis. Topical report, November 1, 1990--May 31, 1993  

SciTech Connect

A preliminary hazard analysis was conducted on the CE IGCC unit by representatives from ABB Lummus Crest Process Systems, Lummus Technical Division, Combustion Engineering, and Lummus Initial Operations. As a basis for the review, available technical data and documentation was used. Two areas of the unit were reviewed, the coal yard delivery system and the gasifier island. The coal yard consists of the coal delivery and handling systems, both of these systems are conventional. The gasifier island encompasses the coal pulverizer and feed system, gasifier and syngas cooler, char removal system, char recycle system, and high temperature sulfur removal system. With first of a kind equipment incorporated in the gasifier island, most of the concerns of potential hazards were centered here. At the time of the review, there were no process flow diagrams for the rest of the combined cycle. To prevent detaining the review of the gasifier island, the remaining areas were not reviewed at this time. However, the remaining areas will be reviewed before final unit design is completed. In reviewing the above mentioned systems, the PHA identified several hazards which will be the basis for a subsequent detailed Hazard and Operability (HAZOP) study which will be performed at a later stage of this project. Results from the evaluation were documented by the team and then reviewed by engineers in the IGCC Product Development department. From the concerns of risks developed by the review team, rethinking of proposed operation and design of the plant during the preliminary design stages took place. (In doing so, cost and redesign time during final design phase will be reduced).

Peletz, L.J.

1993-06-01T23:59:59.000Z

238

Low-Rank Coal Grinding Performance Versus Power Plant Performance  

SciTech Connect

The intent of this project was to demonstrate that Alaskan low-rank coal, which is high in volatile content, need not be ground as fine as bituminous coal (typically low in volatile content) for optimum combustion in power plants. The grind or particle size distribution (PSD), which is quantified by percentage of pulverized coal passing 74 microns (200 mesh), affects the pulverizer throughput in power plants. The finer the grind, the lower the throughput. For a power plant to maintain combustion levels, throughput needs to be high. The problem of particle size is compounded for Alaskan coal since it has a low Hardgrove grindability index (HGI); that is, it is difficult to grind. If the thesis of this project is demonstrated, then Alaskan coal need not be ground to the industry standard, thereby alleviating somewhat the low HGI issue (and, hopefully, furthering the salability of Alaskan coal). This project studied the relationship between PSD and power plant efficiency, emissions, and mill power consumption for low-rank high-volatile-content Alaskan coal. The emissions studied were CO, CO{sub 2}, NO{sub x}, SO{sub 2}, and Hg (only two tests). The tested PSD range was 42 to 81 percent passing 76 microns. Within the tested range, there was very little correlation between PSD and power plant efficiency, CO, NO{sub x}, and SO{sub 2}. Hg emissions were very low and, therefore, did not allow comparison between grind sizes. Mill power consumption was lower for coarser grinds.

Rajive Ganguli; Sukumar Bandopadhyay

2008-12-31T23:59:59.000Z

239

Trace metal particulates in coal-fired power plant emissions.  

E-Print Network (OSTI)

??Since coal-fired power plants produce approximately 50% of U.S. energy, the toxic and environmental damaging effects of this energy source are important. Trace metals are… (more)

Marett, Lanette Simone

2007-01-01T23:59:59.000Z

240

NETL: News Release - Making Tomorrow's Coal-Fired Power Plants...  

NLE Websites -- All DOE Office Websites (Extended Search)

May 4, 2001 Making Tomorrow's Coal-Fired Power Plants Cleaner and More Efficient August 21, 2001 DOE Selects 5 New Research Projects to Improve Combustors, Reduce Pollutants, and...

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.


241

Nitrogen oxide emissions from coal fired MHD plants  

DOE Green Energy (OSTI)

In this topical report, the nitrogen oxide emission issues from a coal fired MHD steam combined cycle power plant are summarized, both from an experimental and theoretical/calculational viewpoint. The concept of staging the coal combustion to minimize NO{sub x} is described. The impact of NO{sub x} control design choices on electrical conductivity and overall plant efficiency are described. The results of the NO{sub x} measurements in over 3,000 hours of coal fired testing are summarized. A chemical kinetics model that was used to model the nooks decomposition is described. Finally, optimum design choices for a low nooks plant are discussed and it is shown that the MHD Steam Coal Fired Combined Cycle Power Plant can be designed to operate with nooks emissions less than 0.05 lbm/MMBTU.

Chapman, J.N. [ed.

1996-03-01T23:59:59.000Z

242

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

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

b. Coal Prices to Electric Generating Plants, Projected vs. Actual Projected Price in Nominal Dollars (nominal dollars per million Btu) 1993 1994 1995 1996 1997 1998 1999 2000 2001...

243

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

SciTech Connect

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.

1990-12-01T23:59:59.000Z

244

Climate VISION: Events - Advanced Clean Coal Workshop  

Office of Scientific and Technical Information (OSTI)

Advanced Clean Coal Workshop Advanced Clean Coal Workshop Objective: Industry and government discussion of key issues and policy options related to deploying clean coal power plants in the marketplace. The following documents are available for download as Adobe PDF documents. Download Acrobat Reader AGENDA July 29, 2004 EEI Conference Center 701 Pennsylvania Avenue, N.W., Washington, DC 8:15 Welcome from Host Thomas Kuhn, President, EEI Opening (Context & Goals) & Introduction Larisa Dobriansky, DOE Kyle McSlarrow, Deputy Secretary, DOE James E. Rogers, Chairman, Cinergy 8:45 Framing the Risks and Challenges for Commercial Clean Coal Plants Results of Risk Framework Analysis, David Berg, DOE (PDF 267 KB) Cost Comparison of IGCC and Advanced Clean Coal Plants, Stu Dalton, EPRI (PDF 684 KB)

245

CE IGCC repowering project: Controls & instrumentation. Topical report, June 1993  

Science Conference Proceedings (OSTI)

The IGCC Control System is used to provide operator interface and controls for manual and auto operation of the IGCC Repowering Project Located at Springfield, Illinois. A Distributed Control System (DCS) is provided for analog (process control) loop functions and to provide the operator interface. A Data Acquisition System (DAS) is provided for gathering performance data and optimization. Programmable Logic Controllers will be provided for the following digital control systems: (a) GSSS (Gasifier Supervisory Safety System) including pulverized coal handling and char handling; (b) Coal Pulverization System; (c) HRSG (Heat Recovery Steam Generation); (d) Hot Gas Cleanup System; (e) Steam Turbine; and (f) Combined Cycle Operation. In general all systems are provided for auto/manual cascade operation; upstream equipment is interlocked to be proven in service operation and/or valve position before downstream equipment may operate.

Not Available

1993-12-01T23:59:59.000Z

246

Impact of Advanced Turbine Systems on coal-based power plants  

DOE Green Energy (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

247

How Coal Gasification Power Plants Work | Department of Energy  

Energy.gov (U.S. Department of Energy (DOE)) Indexed Site

Gasification » How Coal Gasification » How Coal Gasification Power Plants Work How Coal Gasification Power Plants Work How Coal Gasification Power Plants Work The heart of a gasification-based system is the gasifier. A gasifier converts hydrocarbon feedstock into gaseous components by applying heat under pressure in the presence of steam. A gasifier differs from a combustor in that the amount of air or oxygen available inside the gasifier is carefully controlled so that only a relatively small portion of the fuel burns completely. This "partial oxidation" process provides the heat. Rather than burning, most of the carbon-containing feedstock is chemically broken apart by the gasifier's heat and pressure, setting into motion chemical reactions that produce "syngas." Syngas is primarily hydrogen and carbon monoxide, but can include

248

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

E-Print Network (OSTI)

Capture-ready coal plants--Options, technologies and economics Mark C. Bohm a , Howard J. Herzog a. Introduction Interest in the construction of coal-fired power generation has increased significantly in recent the construction of coal-fired plants. Worldwide, the installed capacity of coal-fired plants is expected

249

Encoal mild coal gasification project: Commercial plant feasibility study  

SciTech Connect

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.

1997-07-01T23:59:59.000Z

250

NETL: News Release - Projects Selected to Study Coal Plant Particulate  

NLE Websites -- All DOE Office Websites (Extended Search)

5, 2004 5, 2004 Projects Selected to Study Coal Plant Particulate Matter, Human Health PITTSBURGH, PA - The Department of Energy has selected three projects to help determine whether fine particulates emitted from coal-fired power plants affect human health, and which components of the particulates may be most problematic. Past studies have established that particulate matter smaller than 2.5 microns in diameter from all sources does affect human health, but there is scant information to provide a link between PM2.5 emitted specifically from coal plants and cardiac or respiratory health problems in humans. PM2.5 refers to particles-invisible to the eye-no more than 1/30th of the width of a human hair Coal plants emit only small quantities of "primary" PM2.5 (e.g., fly ash) because all plants have high-efficiency particulate-collection devices. However, coal plants are responsible for a great deal of "secondary" PM2.5, which forms in the atmosphere from emissions of sulfur dioxide (SO2) and nitrogen oxides (NOx). Data collected in the new studies will be used to help design standards reviews and to devise strategies for controlling power plant emissions of PM2.5, SO2, and NOx.

251

Accelerating the deployment of cleaner coal plants  

SciTech Connect

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

252

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)

Coal-fired Plants .capture technologies to coal-fired plants is also likely togroups. Conventional Coal-fired Plants Sulfur During

Apps, J.A.

2006-01-01T23:59:59.000Z

253

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

Science Conference Proceedings (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

254

Gasification of New Zealand coals: a comparative simulation study  

Science Conference Proceedings (OSTI)

The aim of this study was to conduct a preliminary feasibility assessment of gasification of New Zealand (NZ) lignite and sub-bituminous coals, using a commercial simulation tool. Gasification of these coals was simulated in an integrated gasification combined cycle (IGCC) application and associated preliminary economics compared. A simple method of coal characterization was developed for simulation purposes. The carbon, hydrogen, and oxygen content of the coal was represented by a three component vapor solid system of carbon, methane, and water, the composition of which was derived from proximate analysis data on fixed carbon and volatile matter, and the gross calorific value, both on a dry, ash free basis. The gasification process was modeled using Gibb's free energy minimization. Data from the U.S. Department of Energy's Shell Gasifier base cases using Illinios No. 6 coal was used to verify both the gasifier and the IGCC flowsheet models. The H:C and O:C ratios of the NZ coals were adjusted until the simulated gasifier output composition and temperature matched the values with the base case. The IGCC power output and other key operating variables such as gas turbine inlet and exhaust temperatures were kept constant for study of comparative economics. The results indicated that 16% more lignite than sub-bituminous coal was required. This translated into the requirement of a larger gasifier and air separation unit, but smaller gas and steam turbines were required. The gasifier was the largest sole contributor (30%) to the estimated capital cost of the IGCC plant. The overall cost differential associated with the processing of lignite versus processing sub-bituminous coal was estimated to be of the order of NZ $0.8/tonne. 13 refs., 9 tabs.

Smitha V. Nathen; Robert D. Kirkpatrick; Brent R. Young [University of Auckland, Auckland (New Zealand). Department of Chemical and Materials Engineering

2008-07-15T23:59:59.000Z

255

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

SciTech Connect

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

256

Table 33. Coal Carbonized at Coke Plants by Census Division  

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

Coal Carbonized at Coke Plants by Census Division Coal Carbonized at Coke Plants by Census Division (thousand short tons) U.S. Energy Information Administration | Quarterly Coal Report, April - June 2013 Table 33. Coal Carbonized at Coke Plants by Census Division (thousand short tons) U.S. Energy Information Administration | Quarterly Coal Report, April - June 2013 Year to Date Census Division April - June 2013 January - March 2013 April - June 2012 2013 2012 Percent Change Middle Atlantic w w w w w w East North Central 3,051 2,997 3,092 6,048 6,156 -1.8 South Atlantic w w w w w w East South Central w w w w w w U.S. Total 5,471 5,280 5,296 10,751 10,579 1.6 w = Data withheld to avoid disclosure. Note: Total may not equal sum of components because of independent rounding. Source: U.S. Energy Information Administration (EIA), Form EIA-5, 'Quarterly Coal Consumption and Quality Report - Coke Plants

257

Coal Integrated Gasification Fuel Cell System Study  

DOE Green Energy (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

258

Blacksville No. 2 Coal Preparation Plant final report  

Science Conference Proceedings (OSTI)

This report discusses an investigation of the effects of washing on the concentrations of selected metals and non-metals in coal. The investigation concerned the Blacksville No. 2 coal preparation plant of CONSOL Inc. Samples of four solids and three water streams were collected at the plant with the assistance of CONSOL. The solids were the raw coal, the product coal, and both coarse and fine grades of refuse. The water streams analyzed were input water (a mixture of makeup water and recycled thickener overflow), output water (thickener overflow), and water from the thickener underflow. The contaminants determined in these materials were 16 trace metals, 5 major metals, and four non-metals.

NONE

1995-03-28T23:59:59.000Z

259

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

SciTech Connect

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

260

Engineering and Economic Evaluations of Integrated-Gasification Combined-Cycle Plant Designs with Carbon Dioxide Capture  

Science Conference Proceedings (OSTI)

The objectives of this research were to assess the performance and costs of coal-fired integrated-gasificationcombined-cycle (IGCC) power plants. The base cases are Greenfield designs without carbon dioxide (CO2) capture; two additional cases were studied with retrofitted full CO2 capture. The study represents Phase 3 of a multiyear study executed on behalf of the CoalFleet for Tomorrow program, a collaborative research and development program that promotes the deployment of advanced coal technologies, i...

2011-09-29T23:59:59.000Z

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

Nomogram calculates power plant coal use  

SciTech Connect

The number of tons of coal burned annually by a generating unit can be calculated by the following formula: Q = 43.8 (MW) (HR) (CF/HV)/10/sup 6/ where: Q = Annual usage, million tons MW = Unit capacity, MW HR = Unit heat rate, Btu/kWh CF = Annual unit capacity factor, % HV = Heating value of coal, Btu/lb The nomogram solves this equation and permits annual coal usage to be estimated quickly for various combinations of the other variables. The nomogram also can be used in reverse to determine such things as the annual capacity factor that a certain coal usage could sustain. Example: An 840-MW unit has an average heat rate of 10,000 Btu/kWh and burns coal with a heating value of 8600 Btu/lb. The annual capacity factor is 60%. Calculate the annual coal usage. Solution: (A) Align 840 on MW scale with 8600 on HV scale and mark intersection with CF scale; (B) align this marked point with 10,000 on HR scale and mark intersection with Reference Line; (C) align this point with 60 on CF scale and extend to Q scale. Read answer as approximately 2.6 million tons/year.

McAlister, J.

1984-05-01T23:59:59.000Z

262

Coal switch helps New York plants stay competitive  

Science Conference Proceedings (OSTI)

NRG Energy bought the Dunlook and Huntley Generating Stations in 1999 from Niagara Mohawk Power Corp. and has since then invested millions of dollars in converting them from bituminous coal to low sulphur Powder River Basin coal, combustion tuning and routine maintenance to help provide reliable stable-priced electricity to New York. The plants have reduced NOx, SO{sub 2} and particulate emissions. 1 photo.

Blankinship, S.

2009-04-15T23:59:59.000Z

263

Steam Turbine Materials for Ultrasupercritical Coal Power Plants  

Science Conference Proceedings (OSTI)

Lack of materials with the necessary fabricability and resistance to creep, oxidation, corrosion, and fatigue at the higher steam temperatures and pressures currently limits adoption of advanced ultra supercritical (USC) steam conditions in pulverized coal-fired plants. A major five-year national effort sponsored by the Department of Energy (DOE) and the Ohio Coal Development Office (OCDO) to develop materials for USC boilers for operation at 760C (1400F), 35 MPa (5000 psi) has been in progress and is be...

2007-06-20T23:59:59.000Z

264

Design Considerations for Coal Plant CO2 Capture Flexibility  

Science Conference Proceedings (OSTI)

Based on the input from various Electric Power Research Institute- (EPRI-) sponsored research and other respected industry sources, this report aims to initially present the implications for the case when existing pulverized coal (PC) plants are required to operate under frequently changing load conditions. Design improvements to enable more flexible operation of the current and next generation coal fleet are also presented. Finally, the report discusses the implications for operation flexibility of ...

2013-01-11T23:59:59.000Z

265

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

SciTech Connect

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

266

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

SciTech Connect

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

267

NETL: Gasification - Advanced Hydrogen Transport Membranes for Coal  

NLE Websites -- All DOE Office Websites (Extended Search)

Syngas Processing Systems Syngas Processing Systems Advanced Hydrogen Transport Membranes for Coal Gasification Praxair Inc. Project Number: FE0004908 Project Description Praxair is conducting research to develop hydrogen transport membrane (HTM) technology to separate carbon dioxide (CO2) and hydrogen (H2) in coal-derived syngas for IGCC applications. The project team has fabricated palladium based membranes and measured hydrogen fluxes as a function of pressure, temperature, and membrane preparation conditions. Membranes are a commercially-available technology in the chemical industry for CO2 removal and H2 purification. There is, however, no commercial application of membrane processes that aims at CO2 capture for IGCC syngas. Due to the modular nature of the membrane process, the design does not exhibit economy of scale-the cost of the system will increase linearly as the plant system scale increases making the use of commercially available membranes, for an IGCC power plant, cost prohibitive. For a membrane process to be a viable CO2 capture technology for IGCC applications, a better overall performance is required, including higher permeability, higher selectivity, and lower membrane cost.

268

Combinatorial Optimization of Pulverizers for Blended-Coal-Fired Power Plant  

Science Conference Proceedings (OSTI)

Coal blending has become an important way to ease the tension of coal purchase for many Chinese power plants. Mixed by pulverizers which has been widely used, is considered the most reasonable and convenient approach of coal blending. The implementation ... Keywords: power plant, coal blending, combinatorial optimization, pulverizer, NSGA-II

Xia Ji; Peng Peng; Hua Zhigang; Lu Pan; Chen Gang

2011-02-01T23:59:59.000Z

269

Coal gasification players, projects, prospects  

SciTech Connect

Integrated gasification combined cycle (IGCC) technology has been running refineries and chemical plants for decades. Power applications have dotted the globe. Two major IGCC demonstration plants operating in the United States since the mid-1900s have helped set the stage for prime time, which is now approaching. Two major reference plant designs are in the wings and at least two major US utilities are poised to build their own IGCC power plants. 2 figs.

Blankinship, S.

2006-07-15T23:59:59.000Z

270

Coal-fired power plants the next generation  

Science Conference Proceedings (OSTI)

Coal is today a very important source of energy and the resources are sufficient for a long period. To keep power generation with coal up-to-date in view of minimizing the pollution (especially the CO{sub 2}) and of better economy, we will have introduce new plant technologies. After a general overview three of these are presented and compared with the state-of-the-art PCF technology, in respect to plant efficiency, environmental impact, investment cost, cost of electricity, and unit size.

Schemenau, W.; Schoedel, J. (ABB Kraftwerke AG, Mannheim (DE))

1990-01-01T23:59:59.000Z

271

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

272

EA-1870: Utah Coal and Biomass Fueled Pilot Plant, Kanab, Kane...  

Energy.gov (U.S. Department of Energy (DOE)) Indexed Site

0: Utah Coal and Biomass Fueled Pilot Plant, Kanab, Kane County, Utah EA-1870: Utah Coal and Biomass Fueled Pilot Plant, Kanab, Kane County, Utah Summary This EA evaluates the...

273

Prestigious Coal-Fired Project of the Year Award Goes to Plant...  

Energy.gov (U.S. Department of Energy (DOE)) Indexed Site

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

274

Case studies on recent fossil-fired plants  

Science Conference Proceedings (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

275

Pushing the pulverized coal envelope with LEBS  

SciTech Connect

In response to challenges from technologies such as IGCC and PFBC, the ABB LEBS Team has proposed removing the barrier to very large advances in environmental and thermal performance of pulverized coal plants. Pulverized coal will continue to be the source of more than half of our electric generation well into the next century and we must develop low-risk low-cost advances that will compete with the claimed performance of other technologies. This paper describes near-term PC technologies for new and retrofit applications which will accomplish this.

Regan, J.W.; Borio, R.W.; Palkes, M. [and others

1995-12-31T23:59:59.000Z

276

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

Science Conference Proceedings (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

277

Combustion characterization of the blend of plant coal and recovered coal fines. Technical report, December 1, 1991--February 29, 1992  

SciTech Connect

The overall objective of this proposed research program is to determine the combustion characteristics of the blend derived from mixing a plant coal and recovered and clean coal fines from the pond. During this study, one plant coal and three blend samples will be prepared and utilized. The blend samples will be of a mixture of 90% plant coal + 10% fines, 85% plant coal + 15% fines, 80% plant coal + 20% fines having particle size distribution of 70% passing through -200 mesh size. These samples` combustion behavior will be examined in two different furnaces at Penn State University, i.e., a down-fired furnace and a drop-tube furnace. The down-fired furnace will be used mainly to measure the emissions and ash deposition study, while the drop tube furnace will be used to determine burning profile, combustion efficiency, etc.

Singh, S. [SS Energy Environmental International, Inc., Rockford, IL (United States); Scaroni, A.; Miller, B. [Pennsylvania State Univ., University Park, PA (United States). Combustion Lab.; Choudhry, V. [Praxis Engineers, Inc., Milpitas, CA (United States)

1992-08-01T23:59:59.000Z

278

Circular Economy Assessment for Coal-fired Power Plants Based on Supper-Efficiency DEA Model  

Science Conference Proceedings (OSTI)

Coal-fired power plants are the main pollution source in most areas of China. The implementation of circular economy in coal-fired power plants is necessary for environmental protection and also an effective way of energy saving and emission reduction. ... Keywords: circular economy assessment, circular economy improvement, coal-fired power plant, super-efficiency data envelopment analysis

Shao-lun Zeng; Hong Hu; Wei Wang

2009-10-01T23:59:59.000Z

279

COMBINATION OF MSWC AND COAL FIRED POWER PLANT Jiirgen Vehlow, Hans Hunsinger, Siegfried Kreisz, Helmut Seifert  

E-Print Network (OSTI)

COMBINATION OF MSWC AND COAL FIRED POWER PLANT Jiirgen Vehlow, Hans Hunsinger, Siegfried Kreisz for the combination of a municipal solid waste combustion plant and a coal fired power plant in such a way that the dedusted and pre cleaned offgas of the waste combustion serves as carrier gas for the pulverized coal

Columbia University

280

NETL: Clean Coal Technology Demonstration Program (CCTDP) - Round...  

NLE Websites -- All DOE Office Websites (Extended Search)

the Clean Coal Technology Program: Combustion Engineering IGCC Repowering Project, Clean Energy Demonstration Project (Oct 1994) -- Not Available PAPERS AND PRESENTATIONS...

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

NETL: Clean Coal Technology Demonstration Program (CCTDP) - Round...  

NLE Websites -- All DOE Office Websites (Extended Search)

Comprehensive Report to Congress Comprehensive Report to Congress on the Clean Coal Technology Program: Pion Pine IGCC Power Project PDF-335KB (June 1992) PAPERS AND...

282

A Coal-Fired Power Plant with Zero Atmospheric Emissions  

SciTech Connect

This paper presents the thermodynamic 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. This analysis is based on a 400 MW electric power generating plant that uses turbines that are currently under development by a U.S. turbine manufacturer. The power plant has a net thermal efficiency of 42.6%. 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. The paper also presents an analysis of the cost of electricity (COE) and the cost of conditioning carbon dioxide for sequestration for the 400 MW power plant. Electricity cost is compared for three different gasification processes (Texaco, Shell, and Koppers-Totzek) and two types of coals (Illinois No.6 and Wyodak). Cost of electricity ranges from 5.16 {cents}/kWhr to 5.42 {cents}/kWhr, indicating that the cost of electricity varies by 5% for the three gasification processes considered and the two coal types used.

Martinez-Frias, J; Aceves, S M; Smith, J R; Brandt, H

2003-05-27T23:59:59.000Z

283

Table 23. Coal Receipts at Coke Plants by Census Division  

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

Receipts at Coke Plants by Census Division Receipts at Coke Plants by Census Division (thousand short tons) U.S. Energy Information Administration | Quarterly Coal Report, April - June 2013 Table 23. Coal Receipts at Coke Plants by Census Division (thousand short tons) U.S. Energy Information Administration | Quarterly Coal Report, April - June 2013 Year to Date Census Division April - June 2013 January - March 2013 April - June 2012 2013 2012 Percent Change Middle Atlantic w w w w w w East North Central 3,189 2,679 3,225 5,867 5,993 -2.1 South Atlantic w w w w w w East South Central w w w w w w U.S. Total 5,770 4,962 5,370 10,732 10,440 2.8 w = Data withheld to avoid disclosure. Note: Total may not equal sum of components because of independent rounding. Source: U.S. Energy Information Administration (EIA), Form EIA-5, 'Quarterly Coal Consumption and Quality Report - Coke Plants

284

Evaluation of Stringent Emission Control Options for Pulverized Coal Plants  

Science Conference Proceedings (OSTI)

This report contains the results from one of a series of studies sponsored by the Canadian Clean Power Coalition (CCPC), EPRI, and the International Energy Agency (IEA). The CCPC established a goal to develop projects to demonstrate technology at a commercial utility scale for retrofit to existing plants, or for use in new coal-fired power plants, that would allow all emissions, including CO2, to be controlled to meet foreseeable new regulatory requirements. The purpose of this study conducted by Neill &...

2004-03-24T23:59:59.000Z

285

Dynamic simulation for IGCC process and control design  

Science Conference Proceedings (OSTI)

Detailed dynamic simulation analysis is a valuable tool that increases the understanding of unit interactions and control system performance in a complex integrated gasification combined-cycle (IGCC) plant. The Sarlux integrated gasification combined cycle (IGCC) plant must simultaneously satisfy electrical power and refinery hydrogen and steam demands (trigeneration gasification). The plant`s gasifier, heat recovery, sulfur removal, hydrogen recovery and steam power generation units are highly integrated and require coordinated control. In this study, dynamic simulation provides insights into the behavior of the process and combined cycle units during normal and upset conditions. The dynamic simulation is used to design a control system that drives the gasifiers to satisfy power, steam and hydrogen demands before a load change or upset is detected by the syngas pressure controller. At the study conclusion, the model will demonstrate how the IGCC plant will respond to the contractual maximum load change rate and process upsets. The study tests the basic process and control system design during the project engineering phase to minimize startup troubleshooting and expensive field changes.

Depew, C.; Martinez, A. [Fluor Daniel, Irvine, CA (United States); Collodi, G.; Meloni, R. [Snamprogetti, Milan (Italy)

1998-01-01T23:59:59.000Z

286

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

SciTech Connect

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

287

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)

Cornell's conversion of a coal fired heating plant to natural Gas University began operating with natural gas, instead of the coal-fired generators of the coal that had been stockpiled, the Plant is running completely on natural gas

Keinan, Alon

288

Steam Turbine Materials for Ultrasupercritical Coal Power Plants  

Science Conference Proceedings (OSTI)

Lack of materials that can be readily fabricated and that are resistant to creep, oxidation, corrosion, and fatigue at higher steam temperatures and pressures limits adoption of advanced ultrasupercritical (USC) steam conditions in pulverized coal-fired plants. An ongoing major five-year national effort8212sponsored by the U.S. Department of Energy (DOE) and the Ohio Coal Development Office (OCDO)8212to develop materials for USC boilers for operation at 760C (1400F), 35 MPa (5000 psi) is being carried ou...

2008-03-04T23:59:59.000Z

289

Power plants with topping gas turbines and coal gasification planning of new plants and upgrading of existing plants  

Science Conference Proceedings (OSTI)

This paper reports on existing and new power plants improved environmentally and economically by integrating gas turbines in the plant process. The rate of additional firing has an influence on the overall plant efficiency. The influence of the additional firing of natural gas-fired power plants is compared to that of power plants with integrated coal gasification. The differences are explained. The result of the examination lead to recommendations for the design of new plants and for upgrading of existing plants. The advantages of topping gas turbines are shown by examples of new power plants and upgraded plants.

Schoedel, J.; Mertens, K. (ABB Kraftwerke AG, Mannheim (DE))

1990-01-01T23:59:59.000Z

290

Great Plains Coal Gasification Plant public design report. Volume I  

SciTech Connect

This Public Design Report provides, in a single document, available nonproprietary design information for the Great Plains Gasification Project, the first commercial coal gasification facility in the United States. In addition to the design aspects, the history of the project, the organization of the plant owners, and the role of the Department of Energy are briefly discussed. Plant capital and operating costs are also presented. An overview of the mine and plant operations is presented and is followed by detailed nonproprietary descriptions of the individual process units, plant systems, and products. Narrative process descriptions, simplified process flow diagrams, input/output stream data, operating conditions, catalyst and chemical requirements, and utility requirements are given for each unit. The process units are described as they were planned by July 1984. Any modification or alteration that occurred after that date will be the subject of a followup work. Plant startup provisions, environmental considerations and control, monitoring and safety considerations are also addressed for each operating unit. The report is published in two volumes. Volume I contains: (1) introduction; (2) overview of project (plant and mine, plant facilities, Basin Electric Antelope Valley Station); and (3) plant process data (coal, oxygen and steam, gasification and gas processing). 53 refs., 80 figs., 36 tabs.

Miller, W.R.; Belt, R.J.; Honea, F.I.; Ness, H.M.; Lang, R.A.; Berty, T.E.; Delany, R.C.; Mako, P.F.

1985-07-01T23:59:59.000Z

291

Techno-economic evaluation of coal-to-liquids (CTL) plants with carbon capture and sequestration  

E-Print Network (OSTI)

Techno-economic evaluation of coal-to-liquids (CTL) plants with carbon capture and sequestration online 5 March 2011 Keywords: Coal-to-liquids Co-production Carbon capture and storage a b s t r a c t Coal-to-liquids (CTL) processes that generate synthetic liquid fuels from coal are of increasing

292

Proceedings: Effects of Coal Quality on Power Plants: Fifth International Conference  

Science Conference Proceedings (OSTI)

Coal quality has wide-ranging effects on handling, capacity, heat rate, availability, and maintenance of power plant equipment. EPRI's fifth international conference on coal quality featured discussions on corrosion, air toxics, heat rate, and a special session on software tools to support coal quality investigations. Such information can help utilities select coals that will enhance operations and overall generation costs.

1997-12-08T23:59:59.000Z

293

Combustion characterization of the blend of plant coal and recovered coal fines. Technical report, September 1--November 30, 1991  

SciTech Connect

The overall objective of this proposed research program is to determine the combustion characteristics of the blend derived from mixing a plant coal and recovered and clean coal fines from the pond. During this study, one plant coal and three blend samples will be prepared and utilized. The blend samples will be of a mixture of 90% plant coal + 10% fines, 85% plant coal + 15% fines, 80% plant coal + 20% fines having particle size distribution of 70% passing through {minus}200 mesh size. These samples` combustion behavior will be examined in two different furnaces at Penn State University, i.e., a down-fired furnace and a drop-tube furnace. The down-fired furnace will be used mainly to measure the emissions and ash deposition study, while the drop tube furnace will be used to determine burning profile, combustion efficiency, etc. This report covers the first quarter`s progress. Major activities during this period were focused on finding the plants where a demo MTU column will be installed to prepare the samples needed to characterize the combustion behavior of slurry effluents. Also, a meeting was held at Penn State University to discuss the availability of the laboratory furnace for testing the plant coal/recovered coal fines blends.

Singh, Shyam

1991-12-31T23:59:59.000Z

294

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

295

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

E-Print Network (OSTI)

Financing Capture Ready Coal-Fired Power Plants in China by Issuing Capture Options Xi Liang, Jia Li, Jon Gibbons and David Reiner December 2007 EPRG 0728 & CWPE 0761 #12;FINANCING CAPTURE READY COAL supercritical pulverized coal power plant in China, using a cash flow model with Monte-Carlo simulations

Aickelin, Uwe

296

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

E-Print Network (OSTI)

1 Quantification of Variability and Uncertainty in Hourly NOx Emissions from Coal-Fired Power to quantify variability and uncertainty for NOx emissions from coal-fired power plants. Data for hourly NOx Uncertainty, Variability, Emission Factors, Coal-Fired Power Plants, NOx emissions, Regression Models

Frey, H. Christopher

297

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 and Master of Science in Mechanical Engineering ABSTRACT Investments in three coal-fired power generation

298

Assessing the environmental pollutant vector of combustion gases emission from coal-fired power plants  

Science Conference Proceedings (OSTI)

Within the present industrial metabolism, electric and thermal energy production is one of the main consumers of fossil fuels. Coal is a natural resource and fossil fuel used in the coal-fired power plants in Romania. Unfortunately, beyond the environmental ... Keywords: coal-fired power plant, combustion gases, environmental impact, pollutant vector

Cornelia A. Bulucea; Andreea Jeles; Nikos E. Mastorakis; Carmen A. Bulucea; Constantin Brindusa

2011-07-01T23:59:59.000Z

299

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

E-Print Network (OSTI)

Mercury is a leading concern among the air toxic metals addressed in the 1990 Clean Air Act Amendments (CAAA) because of its volatility, persistence, and bioaccumulation as methylmercury in the environment and its neurological health impacts. The Environmental Protection Agency (EPA) reports for 2001 shows that total mercury emissions from all sources in USA is about 145 tons per annum, of which coal fired power plants contribute around 33% of it, about 48 tons per annum. Unlike other trace metals that are emitted in particulate form, mercury is released in vapor phase in elemental (Hg0) or oxidized (Hg2+, mainly HgCl2) form. To date, there is no post combustion treatment which can effectively capture elemental mercury vapor, but the oxidized form of mercury can be captured in traditional emission control devices such as wet flue gas defulrization (WFGD) units, since oxidized mercury (HgCl2) is soluble in water. The chlorine concentration present during coal combustion plays a major role in mercury oxidation, which is evident from the fact that plants burning coal having high chlorine content have less elemental mercury emissions. A novel method of co-firing blends of low chlorine content coal with high chlorine content cattle manure/biomass was used in order to study its effect on mercury oxidation. For Texas Lignite and Wyoming coal the concentrations of chlorine are 139 ppm and 309 ppm on dry ash free basis, while for Low Ash Partially Composted Dairy Biomass it is 2,691 ppm. Co-firing experiments 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 of Hg with 95:5, 90:10 and 80:20 blends were measured to be 28- 50%, 42-62% and 71-75% respectively. Though cattle biomass serves as an additive to coal, to increase the chlorine concentration, it leads to higher ash loading. Low Ash and High Ash Partially Composted Dairy Biomass have 164% and 962% more ash than Wyoming coal respectively. As the fraction of cattle biomass in blend increases in proportion, ash loading problems increase simultaneously. An optimum blend ratio is arrived and suggested as 90:10 blend with good reduction in mercury emissions without any compromise on ash loading.

Arcot Vijayasarathy, Udayasarathy

2007-12-01T23:59:59.000Z

300

Evaluation of Innovative Fossil Fuel Power Plants with CO2 Removal  

Science Conference Proceedings (OSTI)

This interim report presents initial results of an ongoing study of the potential cost of electricity (COE) produced in both conventional and innovative fossil fueled power plants that incorporate carbon dioxide (CO2) removal for subsequent sequestration or use. The baseline cases are natural gas combined cycle (NGCC) and ultra-supercritical pulverized coal (PC) plants, with and without post combustion CO2 removal, and integrated gasification combined cycle (IGCC) plants, with and without pre-combustion ...

2000-12-07T23:59:59.000Z

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

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

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

302

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

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

303

GASIFICATION PLANT COST AND PERFORMANCE OPTIMIZATION  

Science Conference Proceedings (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

304

Thermal energy storage for coal-fired power generation  

DOE Green Energy (OSTI)

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

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

1990-11-01T23:59:59.000Z

305

NETL: News Release - New Mexico Coal-Fired Power Plant to Demonstrate...  

NLE Websites -- All DOE Office Websites (Extended Search)

October 14, 2004 New Mexico Coal-Fired Power Plant to Demonstrate Multi-Pollutant Controls Project Will Help Meet President's Commitment to Clean Coal and Address National Energy...

306

EA-1642S: Small-Scale Pilot Plant for the Gasification of Coal...  

Energy.gov (U.S. Department of Energy (DOE)) Indexed Site

642S: 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...

307

NETL: Coal & Coal Biomass to Liquids - NETL H2-from-Coal Separations  

NLE Websites -- All DOE Office Websites (Extended Search)

and Coal/Biomass to Liquids - Reference Shelf and Coal/Biomass to Liquids - Reference Shelf NETL H2-from-Coal Separations Project Reviews April 29-30, 2008 National Energy Technology Laboratory Morgantown, WV Presentations NETL/ORD In-House Membrane Research Bryan Morreale - National Energy Technology Laboratory Development of Mixed-Conducting Dense Ceramic Membranes for Hydrogen Separation [PDF-1.4MB] Hydrogen Production by Water Dissociation Using Ceramic Membranes Balu Balachandran - Argonne National Laboratory High Flux Metallic Membranes for Hydrogen Recovery and Membrane Reactors [PDF-505KB] Robert Buxbaum - REB Research and Consulting Scale-Up of Hydrogen Transport Membranes for IGCC and FutureGen Plants Doug Jack - Eltron Research Sulfur and Halide Tolerance Kent Coulter - Southwest Research Institute

308

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

Science Conference Proceedings (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

309

CoalFleet Guideline for Advanced Pulverized Coal Power Plants: Version 6  

Science Conference Proceedings (OSTI)

This report provides an overview of state-of-the-art and emerging technologies for pulverized coal (PC) fired generating units along with lessons learned from current plants worldwide. The report is designed to facilitate the timely deployment of reliable, next-generation units that incorporate higher steam conditions that improve efficiency and thereby decrease fuel consumption, CO2 emissions, and other environmental impacts; advanced environmental controls that reduce emissions and discharges of solid ...

2009-09-30T23:59:59.000Z

310

CoalFleet Guideline for Advanced Pulverized Coal Power Plants: Version 5  

Science Conference Proceedings (OSTI)

This report provides an overview of state-of-the-art and emerging technologies for pulverized coal (PC) fired generating units along with lessons learned from current plants worldwide. The report is designed to facilitate timely deployment of reliable, next-generation units that incorporate higher steam conditions that improve efficiency and, thereby, decrease fuel consumption, CO2 emissions, and other environmental impacts; advanced environmental controls that reduce emissions and discharges of solid an...

2009-03-25T23:59:59.000Z

311

CoalFleet Guideline for Advanced Pulverized Coal Power Plants: Verison 4  

Science Conference Proceedings (OSTI)

This report provides an overview of state-of-the-art and emerging technologies for pulverized coal (PC) fired generating units along with lessons learned from current plants worldwide. The report is designed to facilitate the timely deployment of reliable, next-generation units that incorporate higher steam conditions that improve efficiency and thereby decrease fuel consumption, CO2 emissions, and other environmental impacts; advanced environmental controls that reduce emissions and discharges of solid ...

2008-09-30T23:59:59.000Z

312

Combined compressed air storage-low BTU coal gasification power plant  

DOE Patents (OSTI)

An electrical generating power plant includes a Compressed Air Energy Storage System (CAES) fueled with low BTU coal gas generated in a continuously operating high pressure coal gasifier system. This system is used in coordination with a continuously operating main power generating plant to store excess power generated during off-peak hours from the power generating plant, and to return the stored energy as peak power to the power generating plant when needed. The excess coal gas which is produced by the coal gasifier during off-peak hours is stored in a coal gas reservoir. During peak hours the stored coal gas is combined with the output of the coal gasifier to fuel the gas turbines and ultimately supply electrical power to the base power plant.

Kartsounes, George T. (Naperville, IL); Sather, Norman F. (Naperville, IL)

1979-01-01T23:59:59.000Z

313

Life Cycle Results from the IGCC LCI&C Study  

NLE Websites -- All DOE Office Websites (Extended Search)

Plant Construction Installation Coal Extraction Operation Train Operation Mine Decommissioning Stage 1 Raw Material Acquisition Stage 2 Raw Material Transport Plant Operation...

314

Characterization of the Toxicity of Coal-Fired Power Plant Effluents to Freshwater Mussels  

Science Conference Proceedings (OSTI)

Coal-fired power plant effluents contain trace metals, dissolved salts, and nutrients that may harm aquatic life, including fish, invertebrates, and freshwater mussels, living in receiving streams adjacent to the plants. This interim report discusses the results of effluent toxicity and water quality tests performed over the past year for three coal-fired power plantsMitchell Plant and Mountaineer Plant, both in West Virginia, and Marshall Plant in North Carolina.

2011-12-08T23:59:59.000Z

315

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

Science Conference Proceedings (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

316

Water vulnerabilities for existing coal-fired power plants.  

SciTech Connect

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

317

Controlling mercury emissions from coal-fired power plants  

Science Conference Proceedings (OSTI)

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

Chang, R. [Electric Power Research Institute, Palo Alto, CA (United States)

2009-07-15T23:59:59.000Z

318

Conceptual flow sheets development for coal conversion plant coal handling-preparation and ash/slag removal operations  

SciTech Connect

This report presents 14 conceptual flow sheets and major equipment lists for coal handling and preparation operations that could be required for future, commercial coal conversion plants. These flow sheets are based on converting 50,000 tons per day of clean coal representative of the Pittsburgh and Kentucky No. 9 coal seams. Flow sheets were used by Union Carbide Corporation, Oak Ridge National Laboratory, in a survey of coal handling/preparation equipment requirements for future coal conversion plants. Operations covered in this report include run-of-mine coal breaking, coarse coal cleaning, fine coal cleaning, live storage and blending, fine crushing (crushing to top sizes ranging from 1/4-inch to 20 mesh), drying, and grinding (70 percent minus 200 mesh). Two conceptual flow sheets and major equipment lists are also presented for handling ash or granulated slag and other solid wastes produced by nine leading coal conversion processes. These flow sheets provide for solid wastes transport to an environmentally acceptable disposal site as either dry solids or as a water slurry.

1979-07-01T23:59:59.000Z

319

Great Plains Coal Gasification Plant Public Design Report. Volume II  

Science Conference Proceedings (OSTI)

This Public Design Report provides, in a single document, available nonproprietary design information for the Great Plains Gasification Project, the first commercial coal gasification facility in the United States. In addition to the design aspects, the history of the project, the organization of the plant owners, and the role of the Department of Energy are briefly discussed. Plant capital and operating costs are also presented. An overview of the mine and plant operations is presented and is followed by detailed nonproprietary descriptions of the individual process units, plant systems, and products. Narrative process descriptions, simplified process flow diagrams, input/output stream data, operating conditions, catalyst and chemical requirements, and utility requirements are given for each unit. The process units are described as they were planned by July 1984. Any modification or alteration that occurred after that date will be the subject of a followup work. Plant startup provisions, environmental considerations and control, monitoring and safety considerations are also addressed for each operating unit. The report is published in two volumes. Volume II contains: (1) plant process data (sulfur recovery, main flare - area 8300, liquid processing, ash handling and solids disposal, other systems); (2) plant startup procedure and schedule; (3) plant and employee safety; (4) GPGP cost data; and (5) references. 53 refs., 46 figs., 38 tabs.

Miller, W.R.; Belt, R.J.; Honea, F.I.; Ness, H.M.; Lang, R.A.; Berty, T.E.; Delany, R.C.; Mako, P.F.

1985-07-01T23:59:59.000Z

320

Filter systems for IGCC applications  

SciTech Connect

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

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

Evaluating the environmental impact of coal-fired power plants through wastewater pollutant vector  

Science Conference Proceedings (OSTI)

Reliable and safe operation of a coal-fired power plant is strongly linked to freshwater resources, and environmental problems related to water source and wastewater discharging are challenging the power plant operation. This study deals with an evaluation ... Keywords: coal-fired power plant, environmental impact, pollutant vector, wastewater

Nikos E. Mastorakis; Andreea Jeles; Cornelia A. Bulucea; Carmen A. Bulucea; Constantin Brindusa

2011-07-01T23:59:59.000Z

322

EA-1642S: Small-Scale Pilot Plant for the Gasification of Coal and  

Energy.gov (U.S. Department of Energy (DOE)) Indexed Site

642S: Small-Scale Pilot Plant for the Gasification of Coal and 642S: 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 EA-1642S: 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 SUMMARY 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.

323

Prestigious Coal-Fired Project of the Year Award Goes to Plant  

Energy.gov (U.S. Department of Energy (DOE)) Indexed Site

Prestigious Coal-Fired Project of the Year Award Goes to Plant Prestigious Coal-Fired Project of the Year Award Goes to Plant Demonstrating Innovative DOE-Funded Technology Prestigious Coal-Fired Project of the Year Award Goes to Plant Demonstrating Innovative DOE-Funded Technology December 16, 2010 - 12:00pm Addthis Washington, DC - An innovative project demonstrating DryFining™ technology, a more cost-effective way to control coal-based power plant emissions while improving fuel quality, has been named the 2010 Coal-Fired Project of the Year by the editors of Power Engineering magazine. The project, managed by the Office of Fossil Energy's National Energy Technology Laboratory, was developed with funding from the Department of Energy's Clean Coal Power Initiative and was originally implemented at Great River Energy's Coal Creek Station in Underwood, ND, in 2009. The

324

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

325

Coal plants without scrubbers account for a majority of U.S. SO 2 ...  

U.S. Energy Information Administration (EIA)

Coal-fired electric power plants make up the largest source of national sulfur dioxide (SO 2) emissions. The Cross-State Air Pollution Rule (CSAPR) ...

326

Cost of transporting coal to power plants rose almost 50% in ...  

U.S. Energy Information Administration (EIA)

The average cost of shipping coal by railroad to power plants increased almost 50% in the United States from 2001 to 2010.

327

Cost of transporting coal to power plants rose almost 50% in ...  

U.S. Energy Information Administration (EIA)

Nuclear & Uranium. Uranium fuel, ... The average cost of shipping coal by railroad to power plants increased almost 50% in the United ... National numbers can be ...

328

U.S. coal stockpile levels at electric power plants approach five ...  

U.S. Energy Information Administration (EIA)

Total coal stockpile levels at U.S. electric power plants were 139 million tons in August 2011—the lowest total level for August since 2006.

329

A baseline assessment of local mercury deposition from coal-fired power plants in Central Texas.  

E-Print Network (OSTI)

??Coal-fired power plants represent the largest source of anthropogenic mercury in the world. The Central Texas region as represented by the Heart of Texas Council… (more)

Furl, Chad Van.

2006-01-01T23:59:59.000Z

330

Mercury concentrations in wetlands associated with coal-fired power plants in Illinois.  

E-Print Network (OSTI)

??Burning of fossil fuels by coal-fired power plants (CFPPs) is one of the largest sources of environmental mercury in the United States and there have… (more)

Weir, Scott

2009-01-01T23:59:59.000Z

331

Impacts of TMDLs on coal-fired power plants.  

SciTech Connect

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

332

Combustion Engineering Integrated Coal Gasification Combined Cycle Repowering Project, Clean Coal Technology Program. Environmental Assessment  

Science Conference Proceedings (OSTI)

The DOE entered into a cooperative agreement with Combustion Engineering, Inc. (C-E) under which DOE proposes to provide cost-shared funding to design, construct, and operate an Integrated Coal Gasification Combined Cycle (IGCC) project to repower an existing steam turbine generator set at the Springfield (Illinois) City Water, Light and Power (CWL&P) Lakeside Generating Station, while capturing 90% of the coal`s sulfur and producing elemental sulfur as a salable by-product. The proposed demonstration would help determine the technical and economic feasibility of the proposed IGCC technology on a scale that would allow the utility industry to assess its applicability for repowering other coal-burning power plants. This Environmental Assessment (EA) has been prepared by DOE in compliance with the requirements of National Environmental Policy Act (NEPA). The sources of information for this EA include the following: C-E`s technical proposal for the project submitted to DOE in response to the Innovative Clean Coal Technology (ICCT) Program Opportunity Notice (PON); discussions with C-E and CWL&P staff; the volume of environmental information for the project and its supplements provided by C-E; and a site visit to the proposed project site.

Not Available

1992-03-01T23:59:59.000Z

333

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

E-Print Network (OSTI)

and states in the Northeast was high electricity prices, reflecting high historical average costs from efficiency, cost of coal purchases, and utilization among coal-fired power plants using a panel data set from recent years allows us to examine longer term impacts of restructuring; (2) the focus on coal-fired power

334

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

E-Print Network (OSTI)

1 Capture-Ready Coal Plants - Options, Technologies and Economics Mark C. Bohm1 , Howard J. Herzog1 be employed during the initial design and construction of a both pulverized coal and integrated gasification the Internet in the summer of 2006 [7]. Introduction Interest in the construction of coal-fired power

335

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-combustion capture retrofits are expected to a near-term option for mitigating CO2 emissions from existing coal

336

Innovative coal gas cleaning at Sparrows Point Coal Chemical Plant, Maryland for Bethlehem Steel Corporation  

SciTech Connect

In response to the Clean Coal II solicitation, Bethlehem Steel Corporation (BSC) submitted a proposal to the DOE in May 1988. The proposal submitted by BSC describes a Unique integration of commercial technologies developed by Davy/Still Otto to clean coke oven gas being produced at its Sparrows Point, Maryland steel plant. This innovative coke oven gas cleaning system combines secondary gas cooling with hydrogen sulfide and ammonia removal, hydrogen sulfide and ammonia recovery, ammonia destruction and sulfur recovery to produce a cleaner fuel gas for plant use. The primary environmental benefit associated with employing this innovative coke oven gas cleaning system is realized when the fuel gas is burned within the steel plant. Emissions of sulfur dioxide are reduced by more than 60 percent. The removal, recovery and destruction of ammonia eliminates the disposal problems associated with an unmarketable ammonium sulfate by-product. Significant reduction in benzene and hydrogen cyanide emissions are also obtained.

Antrobus, K.; Platts, M. (Davy/Still Otto, Pittsburgh, PA (US)); Harbold, L. (Bethlehem Steel Corp., PA (USA)); Kornosky, R. (Office of Clean Coal Technology, US DOE, Pittsburgh, PA (US))

1990-01-01T23:59:59.000Z

337

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

SciTech Connect

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

338

NETL: Gasification Systems - Liquid Carbon Dioxide/Coal Slurry for Feeding  

NLE Websites -- All DOE Office Websites (Extended Search)

Feed Systems Feed Systems Liquid Carbon Dioxide/Coal Slurry for Feeding Low-Rank Coal to Gasifiers Project Number: DE-FE0007977 There is increased interest in carbon capture and storage (CCS) for future coal-based power plants, and in a CCS integrated gasification plant, relatively pure, high pressure CO2 stream(s) will be available within the power plant. Electric Power Research Institute (EPRI) aims to help reduce the cost and improve the efficiency of integrated gasification combined cycle (IGCC) with CCS by using a portion of the high purity CO2 product stream as the carrier fluid to feed low rank coal (LRC) into the gasifier. EPRI proposes to confirm the potential advantages of LRC/liquid carbon dioxide (LCO2) slurries by: Conducting plant-wide technical and economic simulations.

339

NETL: IEP - Air Quality Research: Health Effects of Coal Plant Emissions  

NLE Websites -- All DOE Office Websites (Extended Search)

Health Effects of Coal Plant Emissions Health Effects of Coal Plant Emissions Health Effects of Coal Plant Emissions Map Click on a Project Name to Get More Information Click to read a DOE TechLine [PDF-22KB] describing three new projects that will improve our current understanding of the link between power plant emissions, PM2.5, and human health. The Health Effects component of NETL's Air Quality Research Program is designed to enhance the body of scientific evidence relating stack emissions from coal plants to adverse health effects resulting from human exposures to air pollution. Despite the fact that coal plants emit significant amounts of PM2.5 and mercury to the atmosphere, there is currently a great deal of uncertainty regarding the actual amount of health damage resulting from these emissions. In order to devise cost-effective

340

Cost and performance baseline for fossil energy plants  

SciTech Connect

The objective of this report is to present performance and cost data for fossil energy power systems, specifically integrated gasification combined cycle (IGCC), pulverized coal (PC), and natural gas combined cycle (NGCC) plants, in a consistent technical and economic manner that accurately reflects current market conditions for plants starting operation in 2010. This is Volume 2 of the three-volume report. Twelve different power plant design configurations were analyzed. These include six IGCC cases utilizing the General Electric Energy (GEE), ConocoPhillips (CoP), and Shell gasifiers each with and without CO{sub 2} capture, and six cases representing conventional technologies: PC-subcritical, PC-supercritical, and NGCC plants both with and without CO{sub 2} capture. Cases 7 and 8 were originally included in this study and involve production of synthetic natural gas (SNG) and the repowering of an existing NGCC facility using SNG. The two SNG cases were subsequently moved to Volume 2 of this report resulting in the discontinuity of case numbers (1-6 and 9-14). Chapter 2 provides the basis for technical, environmental and cost evaluations. Chapter 3 describes the IGCC technologies modeled and presents the results for the six IGCC cases. Chapter 4 describes the PC technologies modeled and presents the results for the four PC cases. Chapter 5 described the NGCC technologies modeled and presents the results for the two NGCC cases. Chapter 6 contains the reference list. 64 refs., 253 exhibits.

NONE

2007-05-15T23:59:59.000Z

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.


341

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

342

Color Removal from Pulp Mill Effluent Using Coal Ash Produced from Georgia Coal Combustion Power Plants  

E-Print Network (OSTI)

Color Removal from Pulp Mill Effluent Using Coal Ash Produced from Georgia Coal Combustion Power color from pulp mill effluent using coal ash. Prevent coal ash adsorbent from leaching arsenic, chromium, lead, and zinc. Define a treatment procedure using coal ash that will result in the maximum

Hutcheon, James M.

343

Testing of a coal-fired diesel power plant  

DOE Green Energy (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

344

Testing of a coal-fired diesel power plant  

DOE Green Energy (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

345

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

SciTech Connect

This is the sixth 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. Coal drying experiments were performed with a Powder River Basin coal to measure the effects of fluidization velocity and drying temperature on rate of drying in a batch drying process. Comparisons to computational results using the batch bed drying model show good agreement. Comparisons to drying results with North Dakota lignite at the same process conditions confirm the lignite dries slightly more rapidly than the PRB. Experiments were also carried out to determine the effects of inlet air humidity on drying rate. The specific humidity ranged from a value typical for air at temperatures near freezing to a value for 30 C air at 90 percent relative humidity. The experimental results show drying rate is strongly affected by inlet air humidity, with the rate decreasing with more humid inlet air. The temperature of the drying process also plays a strong role, with the negative impacts of high inlet moisture being less of a factor in a higher temperature drying process. Concepts for coal drying systems integrated into a power plant were developed. These make use of hot circulating cooling water from the condenser, steam extraction from the turbine cycle and thermal energy extracted from hot flue gas, in various combinations. Analyses are under way to calculate the effects of drying system design and process conditions on unit performance, emissions, and cooling tower makeup water.

Edward K. Levy; Nenad Sarunac; Wei Zhang

2004-07-01T23:59:59.000Z

346

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

Science Conference Proceedings (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

347

Characterizing Coal-Fired Power Plant Mercury Emissions Variability at Low Concentrations  

Science Conference Proceedings (OSTI)

This technical update presents a further evaluation of the variability of mercury emission from coal-fired power plants, based on additional measurements by continuous mercury monitors (CMMs) at two coal-fired power plants with low-level mercury emissions. Emissions variability is important for control technology selection as well as regulatory considerations.

2003-10-20T23:59:59.000Z

348

Evaluation of 450-MWe BGL GCC Power Plants Fueled With Pittsburgh No. 8 Coal  

Science Conference Proceedings (OSTI)

Detailed design and cost estimates have been developed for conventionally and highly integrated 450-MWe, British Gas/Lurgi (BGL) gasification-combined-cycle (GCC) power plants employing two General Electric (GE) MS-7001F gas turbines and fueled with Pittsburgh No. 8 coal. The plants have attractive heat rates and capital costs that are competitive with conventional coal-based power technology.

1992-12-01T23:59:59.000Z

349

Evaluation of a 510-MWe Destec GCC Power Plant Fueled with Illinois No. 6 Coal  

Science Conference Proceedings (OSTI)

A detailed design and cost estimate has been developed for a 510-MWe, conventionally integrated, Destec gasification-combined-cycle (GCC) power plant employing two General Electric (GE) MS-7001F gas turbines and fueled with Illinois no. 6 coal. The plant has an attractive heat rate and a capital cost that is competitive with conventional coal-based power technology.

1992-07-14T23:59:59.000Z

350

Evaluation of a Dow-Based Gasification-Combined-Cycle Plant Using Low-Rank Coals  

Science Conference Proceedings (OSTI)

This feasibility study developed performance and cost data for two different Dow-based gasification-combined-cycle (GCC) power plants, designed to fire either Texas lignite or Wyoming subbituminous coals at a Gulf Coast location. It demonstrated the cost-effectiveness and efficiency of these plants for generating power from low-rank coals.

1989-04-25T23:59:59.000Z

351

Research on Resource Value Flow Accounting Based on Circular Economy for Coal-fired Power Plant  

Science Conference Proceedings (OSTI)

This paper presents the methodology of resource value flow accounting developed for a study which combined material flow analysis?MFA? for the coal-fired power generation plant, in order to shed light on concepts such as resource productivity ... Keywords: Circular economy, Coal-fired power plant, Material flow analysis, Resource value flow accounting

Xie Zhiming; Yi Xuan

2010-05-01T23:59:59.000Z

352

Water Extraction from Coal-Fired Power Plant Flue Gas  

Science Conference Proceedings (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

353

How clean is coal : coal power plant ash pond regulations compared to nuclear reactor decommissioning standards.  

E-Print Network (OSTI)

??Coal power is the prominent source of energy in the United States (U.S.) and around the world. The byproducts of coal power contain many of… (more)

[No author

2011-01-01T23:59:59.000Z

354

Workers Demolish Coal-fired Steam Plant at EM's Portsmouth Site |  

Energy.gov (U.S. Department of Energy (DOE)) Indexed Site

Workers Demolish Coal-fired Steam Plant at EM's Portsmouth Site Workers Demolish Coal-fired Steam Plant at EM's Portsmouth Site Workers Demolish Coal-fired Steam Plant at EM's Portsmouth Site September 18, 2013 - 12:00pm Addthis A high-pressure water cannon is used to control dust for the demolition of the X-600 Steam Plant. A high-pressure water cannon is used to control dust for the demolition of the X-600 Steam Plant. One of three large smoke stacks comes down during the demolition. One of three large smoke stacks comes down during the demolition. A high-pressure water cannon is used to control dust for the demolition of the X-600 Steam Plant. One of three large smoke stacks comes down during the demolition. PIKETON, Ohio - Towering above most nearby buildings, the X-600 Coal-fired Steam Plant had been part of the Portsmouth Gaseous Diffusion

355

Workers Demolish Coal-fired Steam Plant at EM's Portsmouth Site |  

Energy.gov (U.S. Department of Energy (DOE)) Indexed Site

Workers Demolish Coal-fired Steam Plant at EM's Portsmouth Site Workers Demolish Coal-fired Steam Plant at EM's Portsmouth Site Workers Demolish Coal-fired Steam Plant at EM's Portsmouth Site September 18, 2013 - 12:00pm Addthis A high-pressure water cannon is used to control dust for the demolition of the X-600 Steam Plant. A high-pressure water cannon is used to control dust for the demolition of the X-600 Steam Plant. One of three large smoke stacks comes down during the demolition. One of three large smoke stacks comes down during the demolition. A high-pressure water cannon is used to control dust for the demolition of the X-600 Steam Plant. One of three large smoke stacks comes down during the demolition. PIKETON, Ohio - Towering above most nearby buildings, the X-600 Coal-fired Steam Plant had been part of the Portsmouth Gaseous Diffusion

356

Utility to Purchase Low-Carbon Power from Innovative Clean Coal Plant |  

Energy.gov (U.S. Department of Energy (DOE)) Indexed Site

Utility to Purchase Low-Carbon Power from Innovative Clean Coal Utility to Purchase Low-Carbon Power from Innovative Clean Coal Plant Utility to Purchase Low-Carbon Power from Innovative Clean Coal Plant January 19, 2012 - 5:00pm Addthis Lawrence Livermore National Laboratory demonstrated coal gasification in large-scale field experiments at the Rocky Mountain Test Facility (above) near Hanna, Wyoming. Coal gasification and sequestration of the carbon dioxide produced are among the technologies being used in the Texas Clean Energy Project. | Photo courtesy of llnlphotos. Lawrence Livermore National Laboratory demonstrated coal gasification in large-scale field experiments at the Rocky Mountain Test Facility (above) near Hanna, Wyoming. Coal gasification and sequestration of the carbon

357

Combustion Engineering Integrated Coal Gasification Combined Cycle Repowering Project, Clean Coal Technology Program  

Science Conference Proceedings (OSTI)

The DOE entered into a cooperative agreement with Combustion Engineering, Inc. (C-E) under which DOE proposes to provide cost-shared funding to design, construct, and operate an Integrated Coal Gasification Combined Cycle (IGCC) project to repower an existing steam turbine generator set at the Springfield (Illinois) City Water, Light and Power (CWL P) Lakeside Generating Station, while capturing 90% of the coal's sulfur and producing elemental sulfur as a salable by-product. The proposed demonstration would help determine the technical and economic feasibility of the proposed IGCC technology on a scale that would allow the utility industry to assess its applicability for repowering other coal-burning power plants. This Environmental Assessment (EA) has been prepared by DOE in compliance with the requirements of National Environmental Policy Act (NEPA). The sources of information for this EA include the following: C-E's technical proposal for the project submitted to DOE in response to the Innovative Clean Coal Technology (ICCT) Program Opportunity Notice (PON); discussions with C-E and CWL P staff; the volume of environmental information for the project and its supplements provided by C-E; and a site visit to the proposed project site.

Not Available

1992-03-01T23:59:59.000Z

358

Coal gasification for power generation. 2nd ed.  

SciTech Connect

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.

2006-10-15T23:59:59.000Z

359

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

DOE Green Energy (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

360

for Coal-Fired Power Plants, 1970-2000  

E-Print Network (OSTI)

This paper relies on interviews and documentary evidence to describe federal RD&D policy for SO2 and NOx emissions controls for coal-fired power plants from 1970 to 2000 and to assess its impact on technology development. The narrative begins by describing the RD&D program of the EPA in the 1970s, which many observers deem to have been successful, but which was largely dismantled after the election of Ronald Reagan to the presidency in 1980. We then turn to the contributions of the U.S. Department of Energy (DOE), which has been the main federal agency operating in this area since 1980, and particularly to DOE’s Clean Coal Technology Demonstration Program (CCTDP), which began in 1985. The narrative as a whole suggests a mixed verdict on the effectiveness of past federal emissions control RD&D. In the paper’s conclusion, we mine this narrative history for insights that may be useful to current policy-makers. We argue first that regulatory pull is a necessary component for an effective greenhouse gas reduction policy, while technology push is not. However, a welldesigned technology push may enhance the impact of regulation and lower the cost of compliance. Second, we should not expect that these two components will be well-aligned, due

David M. Hart; Kadri Kallas; David M. Hart; Kadri Kallas

2010-01-01T23:59:59.000Z

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.


361

Thermal energy storage for integrated gasification combined-cycle power plants  

SciTech Connect

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

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

1990-07-01T23:59:59.000Z

362

Thermal energy storage for integrated gasification combined-cycle power plants  

DOE Green Energy (OSTI)

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

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

1990-07-01T23:59:59.000Z

363

Improving process performances in coal gasification for power and synfuel production  

Science Conference Proceedings (OSTI)

This paper is aimed at developing process alternatives of conventional coal gasification. A number of possibilities are presented, simulated, and discussed in order to improve the process performances, to avoid the use of pure oxygen, and to reduce the overall CO{sub 2} emissions. The different process configurations considered include both power production, by means of an integrated gasification combined cycle (IGCC) plant, and synfuel production, by means of Fischer-Tropsch (FT) synthesis. The basic idea is to thermally couple a gasifier, fed with coal and steam, and a combustor where coal is burnt with air, thus overcoming the need of expensive pure oxygen as a feedstock. As a result, no or little nitrogen is present in the syngas produced by the gasifier; the required heat is transferred by using an inert solid as the carrier, which is circulated between the two modules. First, a thermodynamic study of the dual-bed gasification is carried out. Then a dual-bed gasification process is simulated by Aspen Plus, and the efficiency and overall CO{sub 2} emissions of the process are calculated and compared with a conventional gasification with oxygen. Eventually, the scheme with two reactors (gasifier-combustor) is coupled with an IGCC process. The simulation of this plant is compared with that of a conventional IGCC, where the gasifier is fed by high purity oxygen. According to the newly proposed configuration, the global plant efficiency increases by 27.9% and the CO{sub 2} emissions decrease by 21.8%, with respect to the performances of a conventional IGCC process. 29 refs., 7 figs., 5 tabs.

M. Sudiro; A. Bertucco; F. Ruggeri; M. Fontana [University of Padova, Milan (Italy). Italy and Foster Wheeler Italiana Spa

2008-11-15T23:59:59.000Z

364

Advanced Coal Wind Hybrid: Economic Analysis  

E-Print Network (OSTI)

Advanced Coal-Wind Non-Hybrid SNG IGCC+CCS PC CCGT Windor a synthetic natural gas (SNG) production facility) and anwithout Fuel With with SNG Production or Syncrude Production

Phadke, Amol

2008-01-01T23:59:59.000Z

365

Coal....  

U.S. Energy Information Administration (EIA)

DOE EIA WEEKLY COAL ... Coal Prices and Earnings (updated April 28, 2004) Spot coal prices in the East rose steadily since Labor Day 2003, with rapid escalations ...

366

Coal....  

U.S. Energy Information Administration (EIA)

DOE EIA WEEKLY COAL ... Coal Prices and Earnings (updated September 26) The average spot prices for reported coal purchases rose once again ...

367

Capture-ready power plants - options, technologies and economics  

SciTech Connect

A plant can be considered to be capture-ready if at some point in the future it can be retrofitted for carbon capture and sequestration and still be economical to operate. The first part of the thesis outlines the two major designs that are being considered for construction in the near-term - pulverized coal (PC) and integrated gasification/combined cycle (IGCC). It details the steps that are necessary to retrofit each of these plants for CO{sub 2} capture and sequestration and assesses the steps that can be taken to reduce the costs and output de-rating of the plant after a retrofit. The second part of the thesis evaluates the lifetime (40 year) net present value (NPV) costs of plants with differing levels of pre-investment for CO{sub 2} capture. Three scenarios are evaluated - a baseline supercritical PC plant, a baseline IGCC plant and an IGCC plant with pre-investment for capture. The results of this thesis show that a baseline PC plant is the most economical choice under low CO{sub 2} tax rates, and IGCC plants are preferable at higher tax rates. The third part of this thesis evaluates the concept of CO{sub 2} 'lock-in'. CO{sub 2} lock-in occurs when a newly built plant is so prohibitively expensive to retrofit for CO{sub 2} capture that it will never be retrofitted for capture, and offers no economic opportunity to reduce the CO{sub 2} emissions from the plant, besides shutting down or rebuilding. The results show that IGCC plants are expected to have lower lifetime CO{sub 2} emissions than a PC plant, given moderate (10-35 $/ton CO{sub 2}) initial tax rates. Higher 4 (above $40) or lower (below $7) initial tax rates do not result in significant differences in lifetime CO{sub 2} emissions from these plants. Little difference is seen in the lifetime CO{sub 2} emissions between the IGCC plants with and without pre-investment for CO{sub 2} capture. 32 refs., 22 figs., 20 tabs., 1 app.

Bohm, M.C. [Massachusetts Institute of Technology, Cambridge, MA (United States). Engineering Systems Division

2006-06-15T23:59:59.000Z

368

Development of Improved Metallic Hot Gas Filters for IGCC and...  

NLE Websites -- All DOE Office Websites (Extended Search)

in materials and processes, coal utilization science, sensors and controls, computational energy science, and bioprocessing-opening new avenues to gains in power plant...

369

Capturing Carbon from Existing Coal-Fired Power Plants  

NLE Websites -- All DOE Office Websites (Extended Search)

CEP April 2009 www.aiche.org/cep 33 CEP April 2009 www.aiche.org/cep 33 DOE's National Energy Technology Laboratory is spearheading R&D on a variety of post-combustion and oxy-combustion technologies to cost-effectively achieve 90% CO 2 capture. Jared P. Ciferno Timothy E. Fout U.S. Dept. of Energy, National Energy Technology Laboratory Andrew P. Jones James T. Murphy Science Applications International Corp. C oal-fi red power plants generate about half of the electricity in the United States today, and will con- tinue to be a major source of energy for the fore- seeable future. The U.S. Dept. of Energy's (DOE) Energy Information Administration (EIA) projects that the nation's 300+ gigawatts (GW) of coal-fi red electricity-generating capacity currently in operation will increase to more than

370

GASIFICATION PLANT COST AND PERFORMANCE OPTIMIZATION  

DOE Green Energy (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

371

GASIFICATION PLANT COST AND PERFORMANCE OPTIMIZATION  

Science Conference Proceedings (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

372

Valuing the Flexibility of Providing System Services for Coal Plants with Carbon Capture Capability  

Science Conference Proceedings (OSTI)

This technical update describes a preliminary study of the potential value associated with using the operating flexibility available from advanced coal plant designs with carbon capture and storage (CCS) systems, as well as from existing coal plants with CCS retrofits, to participate in ancillary service markets. New analytical approaches are introduced that offer the ability to examine plant outputs and operating modes in the context of varying power market conditions151for real power and for reserve a...

2010-12-31T23:59:59.000Z

373

Metallic Membrane Materials Development for Hydrogen Production from Coal Derived Syngas  

DOE Green Energy (OSTI)

The goals of Office of Clean Coal are: (1) Improved energy security; (2) Reduced green house gas emissions; (3) High tech job creation; and (4) Reduced energy costs. The goals of the Hydrogen from Coal Program are: (1) Prove the feasibility of a 40% efficient, near zero emissions IGCC plant that uses membrane separation technology and other advanced technologies to reduce the cost of electricity by at least 35%; and (2) Develop H{sub 2} production and processing technologies that will contribute {approx}3% in improved efficiency and 12% reduction in cost of electricity.

O.N. Dogan; B.H. Howard; D.E. Alman

2012-02-26T23:59:59.000Z

374

Report on Geothermal Power Plant Cost and Comparative Cost of Geothermal and Coal Fired Steam Power Plants  

DOE Green Energy (OSTI)

This report is to be used by Utah Power and Light Company (UP and L) in making studies of geothermal power plants. The dollars per kilowatt comparison between a geothermal plant and a UP and L coal-fired plant is to be developed. Geothermal gathering system costs and return to owner are to be developed for information.

None

1977-07-01T23:59:59.000Z

375

Combustion characterization of the blend of plant coal and recovered coal fines. Final technical report, September 1, 1991--August 31, 1992  

SciTech Connect

The overall objective of this proposed research program was to determine the combustion characteristics of the blend derived from mixing a plant coal and recovered and clean coal fines from the pond. During this study, one plant coal and three blend samples were prepared as 100% plant coal, 90% plant coal/10% fines, 85% plant coal/15% fines, and 80% plant coal /20% fines with a particle size distribution of 70% passing through {minus}200 mesh size. The plant coal and recovered coal fines were obtained from the Randolph Preparation Plant of Peabody Coal Co., Marissa, IL. These samples` combustion behavior will be examined in two different furnaces at Penn State University, i.e., a down-fired furnace and a drop-tube furnace. The down-fired furnace was used mainly to measure the emissions and ash deposition study, while the drop tube furnace was used to determine burning profile, combustion efficiency, etc. The burning profile of the plant coal and the three blends was determined in a thermogravimetric analyzer. Results indicated slower burning of the blends due to low volatile matter and oxidized coal particles. Combustion emissions of these samples were determined in the down-fired combustor, while relative ignition temperatures were determined in the drop tube furnace. Chemical composition of ashes were analyzed to establish a correlation with their respective ash fusion temperatures. Overall study of these samples suggested that the blended samples had combustion properties similar to the original plant coal. In other words, flames were stable under identical firing rates of approximately 200,000 Btu`s/hr and 25% excess air. CO, NO{sub x}, and SO{sub x}, were similar to each other and within the experimental error. Combustion efficiency of 99{sup +}% was achievable. Ash chemical analysis of each sample revealed that slagging and fouling should not be different from each other.

Singh, S. [SS Energy Environmental International, Inc., Rockford, IL (United States); Scaroni, A.; Miller, B. [Pennsylvania State Univ., University Park, PA (United States). Combustion Lab.; Choudhry, V. [Praxis Engineers, Inc., Milpitas, CA (United States)

1992-12-31T23:59:59.000Z

376

Microsoft Word - CurrentFutureIGCC2Revisionfinal.doc  

NLE Websites -- All DOE Office Websites (Extended Search)

M M T R - 2 0 0 4 - 0 5 Mitretek Technical Report Current and Future IGCC Technologies: Bituminous Coal to Power AUGUST 2004 David Gray Salvatore Salerno Glen Tomlinson Customer: Concurrent Technology Corporation Customer Name Contract No.:001000045 Dept. No.: H050 H050 Project No.:0601CTC4 ©Year Mitretek Systems ©M Falls Church, Virginia ii Disclaimer This report was prepared as an account of work sponsored by an agency of the United States (U.S.) Government. Neither the U.S., nor any agency thereof, nor any of their employees, nor any of their contractors, subcontractors, or their employees makes any warranty, expressed or implied, or assumes any legal liability or responsibility for the accuracy, completeness, or usefulness of any information, apparatus, product, or process

377

Coal-CO2 Slurry Feeding System for Pressurized Gasifiers  

NLE Websites -- All DOE Office Websites (Extended Search)

Feed Systems Feed Systems Coal-CO2 Slurry Feeding System for Pressurized Gasifiers Massachusetts Institute of Technology Project Number: FE0012500 Project Description This project will develop and assess a slurry feeding system based on a suspension of coal in liquid CO2 that can be pumped into a high-pressure gasifier. The advantages of this solution are that CO2 has a low heat capacity, a low heat of vaporization and low viscosity. Thus, the liquid CO2 imposes a much smaller thermal load on the gasifier relative to a water slurry, and has the potential to improve the efficiency and economics of integrated gasification combined cycle (IGCC) power plants with carbon capture and dramatically reduce greenhouse gas emissions from coal fired power plants. Project Details

378

Coal....  

U.S. Energy Information Administration (EIA)

Coal Prices and Earnings (updated August 12) According to Platts Coal Outlook’s Weekly Price Survey (August 11), the ...

379

Coal....  

U.S. Energy Information Administration (EIA)

Coal Prices and Earnings (updated September 2) The average spot prices for coal traded last week were relatively ...

380

Potential of hybrid geothermal/coal fired power plants in Arizona  

DOE Green Energy (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,
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.


381

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

E-Print Network (OSTI)

Tri-State Synfuels Company, in cooperation with the Commonwealth of Kentucky, undertook a comprehensive coal testing program to support the development of an indirect coal liquefaction project. One of the major elements of the program was a 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 coal, and to establish the design bases for the TriState Synfuels Project. Other elements of the overall program with Kentucky 9 coal included coal selection, coal characterization, stockpile weatherability, corrosion testing, by-product characterization, and wastewater treatability. The results from this testing program formed the basis for recommendations concerning technical and environmental design criteria and permit applications.

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

1983-01-01T23:59:59.000Z

382

U.S. Program on Materials Technology for Ultrasupercritical Coal Power Plants  

Science Conference Proceedings (OSTI)

The use of coal for electrical generation is essential for maintaining adequate energy supplies in the United States in the 21st Century, but traditional methods of coal combustion emit pollutants and CO2 at high levels relative to other generation options. To address these problems, a government/industry consortium is undertaking 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, termed "Ultrasuperc...

2006-03-27T23:59:59.000Z

383

Demonstration Development Project: Assessment of Pressurized Oxy-Coal Technology for Steam-Electric Power Plants  

Science Conference Proceedings (OSTI)

The use of pressurized oxy-combustion technology to support steam–electric power production has been proposed by several organizations as a potential low-cost way to enable a dramatic reduction in CO2 emissions from coal-fired power plants. The pressurized oxy-coal technology realizes most of the benefits of atmospheric pressure oxy-coal technology and offers the prospect of additional efficiency and cost benefits. The technology is, however, in the early stages of development.

2010-12-17T23:59:59.000Z

384

Demonstration of On-Line Elemental Coal Analyzer at TVA's Cumberland Fossil Plant  

Science Conference Proceedings (OSTI)

A Pulsed-Fast-Thermal-Neutron Analysis (PFTNA) on-line elemental coal analyzer, developed by Western Kentucky University's Applied Physics Institute, was installed at TVA's Cumberland Fossil Plant. The analyzer is designed to continuously determine the incoming coal's quality properties. The overall effort was coordinated by EPRI's Instrumentation and Control Center. The demonstration and evaluation of the coal analyzer at Cumberland identified and quantified the elements of ash formation along with mois...

2008-03-25T23:59:59.000Z

385

CERAMIC MEMBRANE ENABLING TECHNOLOGY FOR IMPROVED IGCC EFFICIENCY  

SciTech Connect

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

386

Problems and Solutions for Multi-coals Blending in Thermal Plant  

Science Conference Proceedings (OSTI)

Multi-coals blending is an applicable method for energy-saving and pollutant reduction in thermal plants. However, the utilizations have been hampered by problems such as complexities of practical implements, risks against safety during operation, difficulties ... Keywords: multi-coals blending, whole process, global optimization, expert system

Peng Peng; Xia Ji; Yang Tao

2011-02-01T23:59:59.000Z

387

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

Science Conference Proceedings (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

388

Steam Turbine Materials for Ultrasupercritical Coal Power Plants  

SciTech Connect

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

389

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.

390

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.

391

Prediction of power output of a coal-fired power plant by artificial neural network  

Science Conference Proceedings (OSTI)

Accurate modeling of thermal power plant is very useful as well as difficult. Conventional simulation programs based on heat and mass balances represent plant processes with mathematical equations. These are good for understanding the processes but usually ... Keywords: ANN model, Coal-fired boiler, Extrapolation, Interpolation, Real plant data, Steam turbine

J. Smrekar; D. Pandit; M. Fast; M. Assadi; Sudipta De

2010-07-01T23:59:59.000Z

392

Review of Alternatives for Co-firing Biomass in Coal-Based Power Plants  

Science Conference Proceedings (OSTI)

This Technical Update presents information gathered during visits to three European coal-based plants co-fired with biomass. In addition to process details of the plants visited, the report draws together the insight gained of the political and technical approaches that Member States of the European Union (EU) are following to reduce fossil-derived carbon dioxide emissions from their power plants.

2003-12-15T23:59:59.000Z

393

Global warming and the future of coal carbon capture and storage  

SciTech Connect

The paper considers how best to change the economic calculus of power plant developers so they internalize CCS costs when selecting new generation technologies. Five policy tools are analyzed: establishing a greenhouse gas cap-and-trade program; imposing carbon taxes; defining CCS systems as a so-called Best Available Control Technology for new power plants under the USA Clean Air Act's New Source Review program; developing a 'low carbon portfolio' standard that requires utilities to provide an increasing proportion of power from low-carbon generation sources over time; and requiring all new coal power plants to meet an 'emission performance' standard that limits CO{sub 2} emissions to levels achievable with CCS systems. Each of these tools has advantages and drawbacks but an emission performance standard for new power plants is likely to be most effective in spurring broad-scale adoption of CCS systems. Chapter headings are: global warming and the future of coal; new coal-fired power plants threaten all other efforts to combat global warming; a potential path to zero emissions through carbon capture and storage; CO{sub 2} capture at coal plants: the promise of IGCC and other technologies; barriers to commercialization of IGCC technology; crossing the chasm: a new policy framework to push ccs implementation forward; encouraging CCS systems with carbon caps and trading programs; using the existing Clean Air Act to require CCS systems for new coal plants; retail low carbon portfolio standard; carbon tax; emission performance standards for new coal power plants; and conclusions. 16 figs.

Ken Berlin; Robert M. Sussman [Skadden Arps, Slate, Meagher and Flom (United States)

2007-05-15T23:59:59.000Z

394

Characterizing Variation in Mercury Emissions from Coal-Fired Power Plants  

Science Conference Proceedings (OSTI)

This report evaluates the variability of mercury emissions from coal-fired power plants, using EPRI's continuous mercury monitor (CMM) dataset. Emission variability is important for control technology selection as well as regulatory considerations.

2003-06-03T23:59:59.000Z

395

Carbon Management for a Coal/Biomass to Liquids Plant in Northeast...  

NLE Websites -- All DOE Office Websites (Extended Search)

Carbon ManageMent for a CoalbioMass to liquids Plant in northeast ohio Background This project involves the development of a carbon management plan for a proposed coal and biomass...

396

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.

397

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

NLE Websites -- All DOE Office Websites (Extended Search)

Effect of the shutdown of a large coal-fired power plant on ambient mercury species Yungang Wang 1 , Jiaoyan Huang 2,a , Philip K. Hopke 3,* , Oliver V. Rattigan 4 , David C....

398

SO2 impacts on forage and soil sulfur concentrations near coal-fired power plants.  

E-Print Network (OSTI)

??The goal of this research was to determine if S02 emissions from coal-fired power plants could be contributing to the copper deficiency in cattle. Copper… (more)

Beene, Jack Stephen

2012-01-01T23:59:59.000Z

399

EIA Energy Kids - Coal  

U.S. Energy Information Administration (EIA)

Sometimes, coal-fired electric power plants are built near coal mines to lower ... industries and businesses with their own power plants use coal to generate ...

400

ConocoPhillips Sweeny IGCC/CCS Project  

SciTech Connect

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.


401

Post-Combustion CO2 Capture Design Considerations for Coal Plant Load Following Flexibility  

Science Conference Proceedings (OSTI)

The Electric Power Research Institute (EPRI) is currently examining the feasibility of large scale 90 CO2 post combustion capture (PCC) on pulverized Coal (PC) power plants for both new build and retrofit scenarios. The CoalFleet program has undertaken extensive engineering and economic assessments of state-of-the-art ultra-supercritical (USC) PC with capture, alongside plants retrofitted with highly integrated PCC systems. Based on extensive knowledge accrued to date, this report aims to illustrate the ...

2011-12-30T23:59:59.000Z

402

Slipstream Testing of a Membrane CO2 Capture Process for Existing Coal-Fired Power Plants  

NLE Websites -- All DOE Office Websites (Extended Search)

Testing of a Membrane CO Testing of a Membrane CO 2 Capture Process for Existing Coal-Fired Power Plants Background The mission of the U.S. Department of Energy/National Energy Technology Laboratory (DOE/NETL) Existing Plants, Emissions & Capture (EPEC) Research & Development (R&D) Program is to develop innovative environmental control technologies to enable full use of the nation's vast coal reserves, while at the same time allowing the current fleet of

403

Estimation Methodology for Total and Elemental Mercury Emissions from Coal-Fired Power Plants  

Science Conference Proceedings (OSTI)

This report provides a tool for estimating total and speciated mercury emissions from coal-fired power plants. The mercury emissions methodology is based on EPRI's analyses of the results from the U.S. Environmental Protection Agency (EPA) Mercury Information Collection Request (ICR). The Mercury ICR required owner/operators of coal-fired electric utility steam generating units to report for calendar year 1999 the quantity of fuel consumed and the mercury content of that fuel. In addition, 84 power plant...

2001-04-18T23:59:59.000Z

404

Options for Removing Multiple Pollutants Including CO2 at Existing Coal-Fired Power Plants  

Science Conference Proceedings (OSTI)

This report is a technical review of the fuel changes and technology options for existing coal-fired power plants in response to potential new requirements for increasingly stringent multi-pollutant air emissions reductions, possibly including carbon dioxide (CO2). Preliminary costing of the major options is included. A database of the U.S. coal-fired power plants has been developed for further, more specific analyses.

2002-10-08T23:59:59.000Z

405

NETL: Coal Utilization By-Products (CUB)  

NLE Websites -- All DOE Office Websites (Extended Search)

Home > Technologies > Coal & Power Systems > Innovations for Existing Plants > Coal Utilization Byproducts Innovations for Existing Plants Solid Waste (Coal Utilization...

406

CERAMIC MEMBRANE ENABLING TECHNOLOGY FOR IMPROVED IGCC EFFICIENCY  

SciTech Connect

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

407

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

SciTech Connect

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

408

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

SciTech Connect

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

409

Superheater Corrosion in Plants Burning High-Chlorine Coals  

Science Conference Proceedings (OSTI)

Corrosion caused by molten alkali sulfates can cause premature failure in superheaters and reheaters of coal-fired boilers. Coals with a high chlorine content are more likely to cause molten sulfate corrosion than those with a low chlorine content. Tests in a boiler burning coal with 0.37% chlorine and 1.3% sulfur show that stainless steels with at least 35% chromium are very corrosion resistant, while steels containing less than 20% chromium have high corrosion rates.

1992-12-01T23:59:59.000Z

410

Projected retirements of coal-fired power plants - Today in ...  

U.S. Energy Information Administration (EIA)

Current trends in the electric power market put many coal-fired generators in the United States at risk for retirement. In the Annual Energy Outlook ...

411

Coal....  

U.S. Energy Information Administration (EIA)

DOE EIA WEEKLY COAL ... Coal Prices and Earnings (updated July 7, 2004) In the trading week ended July 2, the average spot coal prices tracked by EIA were mixed.

412

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

413

Combustion characterization of the blend of plant coal and recovered coal fines. [Quarterly] technical report, March 1, 1992--May 31, 1992  

SciTech Connect

The overall objective of this proposed research program is to determine the combustion characteristics of the blend derived from mixing a plant coal and recovered and clean coal fines from the pond. One plant coal and three blend samples will be prepared and utilized. The blend samples will be of a mixture of 90% plant coal + 10% fines, 85% plant coal + 15% fines, 80% plant coal + 20% fines having particle size distribution of 70% passing through -200 mesh size. These samples` combustion behavior will be examined in two different furnaces at Penn State University, i.e., a down-fired furnace and a drop-tube furnace. The down-fired furnace win be used mainly to measure the emissions and ash deposition study, while the drop tube furnace will be used to determine burning profile, combustion efficiency, etc. The burning profile of the plant coal and the three blends was determined in a thermogravimetric analyzer. Results indicated slower burning of the blends due to low volatile matter and oxidized coal particles. Ash fusing temperatures of the samples were determined using ASTM procedure. Preliminary combustion evaluation of the samples (100% plant coal, 80% plant coal/20% recovered coal fines) indicated that the flame was stable at 100,000-200,000 Btu/hr firing rate. Carbon conversion efficiency of 85 to 90% was recorded using the Ash Tracer technique. Tests are continuing to determine the operating boundaries for these blends while measuring the emissions of SO{sub x}, NO{sub x}, CO and O{sub 2}, maintaining a stable flame.

Singh, S. [SS Energy Environmental International, Inc., Rockford, IL (United States); Scaroni, A.; Miller, B. [Pennsylvania State Univ., University Park, PA (United States). Combustion Lab.; Choudhry, V. [Praxis Engineers, Inc., Milpitas, CA (United States)

1992-10-01T23:59:59.000Z

414

NUCLEAR-CONVENTIONAL POWER PLANT COST STUDY CONVENTIONAL COAL FIRED POWER PLANTS, 25,000 KW TO 325,000 KW, FOR ARGONNE NATIONAL LABORATORY, LEMONT, ILLINOIS  

SciTech Connect

In order to establish a basis for comparing the estimated cost of nuclear power plant designs, a set of general and detailed design considerations for conventional coal-fired power plants was established. Five preliminary designs of conventional coal-fired power plants ranging in size from 25to 325 mw were selected, and cost estimates were prepared. ( A.C.)

Chittenden, W.A.

1959-03-01T23:59:59.000Z

415

Application of Multi-objects Fuzzy Comprehension Evaluation in Selecting Location of Coal-Fired Plant Construction Project  

Science Conference Proceedings (OSTI)

The paper introduces the method of multi-objects fuzzy comprehension evaluation briefly, and applies it to select location of coal-fired plants construction project. Multi-objective fuzzy comprehensive evaluation in plant site application has strong ... Keywords: Fuzzy comprehension evaluation, Multi-objects decision, Selecting location of coal-fired plant

Li Wei; Zhang Zhen-gang; Wen Xinpu

2008-12-01T23:59:59.000Z

416

NETL: Gasification - Feasibility Studies to Improve Plant Availability...  

NLE Websites -- All DOE Office Websites (Extended Search)

Feasibility Studies to Improve Plant Availability and Reduce Total Installed Cost in IGCC Plants General Electric Company Project Number: FE0007859 Project Description General...

417

Hydrometallurgical recovery of germanium from coal gasification fly ash: pilot plant scale evaluation  

Science Conference Proceedings (OSTI)

In this article, a hydrometallurgical method for the selective recovery of germanium from fly ash (FA) has been tested at pilot plant scale. The pilot plant flowsheet comprised a first stage of water leaching of FA, and a subsequent selective recovery of the germanium from the leachate by solvent extraction method. The sol