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Note: This page contains sample records for the topic "integrated coal-gasification combined" 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

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...

2

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

SciTech Connect

On February 22, 1988, DOE issued Program Opportunity Notice (PON) Number-DE-PS01-88FE61530 for Round II of the CCT Program. The purpose of the PON was to solicit proposals to conduct cost-shared ICCT projects to demonstrate technologies that are capable of being commercialized in the 1990s, that are more cost-effective than current technologies, and that are capable of achieving significant reduction of SO[sub 2] and/or NO[sub x] emissions from existing coal burning facilities, particularly those that contribute to transboundary and interstate pollution. The Combustion Engineering (C-E) Integrated Coal Gasification Combined Cycle (IGCC) Repowering Project was one of 16 proposals selected by DOE for negotiation of cost-shared federal funding support from among the 55 proposals that were received in response to the PON. The ICCT Program has developed a three-level strategy for complying with the National Environmental Policy Act (NEPA) that is consistent with the President's Council on Environmental Quality regulations implementing NEPA (40 CFR 1500-1508) and the DOE guidelines for compliance with NEPA (10 CFR 1021). The strategy includes the consideration of programmatic and project-specific environmental impacts during and subsequent to the reject selection process.

1992-03-01T23:59:59.000Z

3

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

4

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

5

Coal gasification-based integrated coproduction energy facilities  

SciTech Connect

Coal gasification has been a technological reality for over a half century, being first used in great detail in Europe as an alternative to petroleum. Several projects in the US in the last decade have led to the commercial demonstration and verification of the coal gasification process. This paper reports that, in an effort to reduce the cost of electricity from an Integrated Gasification Combined Cycle Plant, the Electric Power Research Institute embarked in a program to research, evaluate and potentially demonstrate a coal gasification-based integrated coproduction energy facility, and release an RFP in mid 1990 as Phase I of that program. Houston Lighting and Power Company responded with a proposal in its ongoing effort to study emerging technologies for electricity production. HL and P recognized the opportunities available to them in coproduction because of their close proximity to the world's largest petrochemical complex located on the Houston Ship Channel.

Baumann, P.D. (InterFact, Inc., Dallas, TX (US)); Epstein, M. (Electric Power Research Inst., Palo Alto, CA (United States)); Kern, E.E. (Houston Lighting and Power Co., TX (United States))

1992-01-01T23:59:59.000Z

6

Thermal energy storage for an integrated coal gasification combined-cycle power plant  

DOE Green Energy (OSTI)

This study investigates the use of molten nitrate salt thermal energy storage in an integrated gasification combined-cycle power plant allowing the facility to economically provide peak- and intermediate-load electric power. The results of the study show that an integrated gasification combined-cycle power plant with thermal energy storage can reduce the cost of coal-fired peak- or intermediate-load electric power by between 5% and 20% depending on the plants operating schedule. The use of direct-contact salt heating can further improve the economic attractiveness of the concept. 11 refs., 1 fig., 4 tabs.

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

1990-03-01T23:59:59.000Z

7

Thermal energy storage for an integrated coal gasification combined-cycle power plant  

Science Conference Proceedings (OSTI)

This study investigates the use of molten nitrate salt thermal energy storage in an integrated gasification combined-cycle power plant allowing the facility to economically provide peak- and intermediate-load electric power. The results of the study show that an integrated gasification combined-cycle power plant with thermal energy storage can reduce the cost of coal-fired peak- or intermediate-load electric power by between 5% and 20% depending on the plants operating schedule. The use of direct-contact salt heating can further improve the economic attractiveness of the concept. 12 refs., 1 fig., 5 tabs.

Drost, K.; Antoniak, Z.; Brown, D.; Somasundaram, S.

1991-10-01T23:59:59.000Z

8

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

9

Integration of carbonate fuel cells with advanced coal gasification systems  

DOE Green Energy (OSTI)

Carbonate fuel cells have attributes which make them ideally suited to operate on coal-derived fuel gas; they can convert the methane, hydrogen, and carbon monoxide present in coal derived fuel gas directly to electricity, are not subject to thermodynamic cycle limits as are heat engines, and operate at temperatures compatible with coal gasifiers. Some new opportunities for improved efficiency have been identified in integrated coal gasification/carbonate fuel cells which take advantage of low temperature catalytic coal gasification producing a methane-rich fuel gas, and the internal methane reforming capabilities of Energy Research Corporation's carbonate fuel cells. By selecting the appropriate operating conditions and catalyst in the gasifier, methane formation is maximized to improve gasification efficiency and to take advantage of the heat management aspects of the internal reforming carbonate fuel cell. These advanced integrated gasification/carbonate fuel cell systems are projected to have better efficiencies than gasification/carbonate fuel cell systems employing conventional gasification, and also competing non-fuel cell systems. These improved efficiencies would be accompanied by a corresponding reduction in impact on the environment as well.

Steinfeld, G. (Energy Research Corp., Danbury, CT (United States)); Meyers, S.J. (Fluor Daniel, Inc., Irvine, CA (United States)); Hauserman, W.B. (North Dakota Univ., Grand Forks, ND (United States). Energy and Environmental Research Center)

1992-01-01T23:59:59.000Z

10

Integration of carbonate fuel cells with advanced coal gasification systems  

DOE Green Energy (OSTI)

Carbonate fuel cells have attributes which make them ideally suited to operate on coal-derived fuel gas; they can convert the methane, hydrogen, and carbon monoxide present in coal derived fuel gas directly to electricity, are not subject to thermodynamic cycle limits as are heat engines, and operate at temperatures compatible with coal gasifiers. Some new opportunities for improved efficiency have been identified in integrated coal gasification/carbonate fuel cells which take advantage of low temperature catalytic coal gasification producing a methane-rich fuel gas, and the internal methane reforming capabilities of Energy Research Corporation`s carbonate fuel cells. By selecting the appropriate operating conditions and catalyst in the gasifier, methane formation is maximized to improve gasification efficiency and to take advantage of the heat management aspects of the internal reforming carbonate fuel cell. These advanced integrated gasification/carbonate fuel cell systems are projected to have better efficiencies than gasification/carbonate fuel cell systems employing conventional gasification, and also competing non-fuel cell systems. These improved efficiencies would be accompanied by a corresponding reduction in impact on the environment as well.

Steinfeld, G. [Energy Research Corp., Danbury, CT (United States); Meyers, S.J. [Fluor Daniel, Inc., Irvine, CA (United States); Hauserman, W.B. [North Dakota Univ., Grand Forks, ND (United States). Energy and Environmental Research Center

1992-12-01T23:59:59.000Z

11

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.

12

Coal Gasification Report.indb  

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

Integrated Coal Integrated Coal Gasification Combined Cycle: Market Penetration Recommendations and Strategies Produced for the Department of Energy (DOE)/ National Energy Technology Laboratory (NETL) and the Gasification Technologies Council (GTC) September 2004 Coal-Based Integrated Gasification Combined Cycle: Market Penetration Strategies and Recommendations Final Report Study Performed by:

13

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

14

Coal-gasification/MHD/steam-turbine combined-cycle (GMS) power generation  

DOE Green Energy (OSTI)

The coal-gasification/MHD/steam-turbine combined cycle (GMS) refers to magnetohydrodynamic (MHD) systems in which coal gasification is used to supply a clean fuel (free of mineral matter and sulfur) for combustion in an MHD electrical power plant. Advantages of a clean-fuel system include the elimination of mineral matter or slag from all components other than the coal gasifier and gas cleanup system; reduced wear and corrosion on components; and increased seed recovery resulting from reduced exposure of seed to mineral matter or slag. Efficiencies in some specific GMS power plants are shown to be higher than for a comparably sized coal-burning MHD power plant. The use of energy from the MHD exhaust gas to gasify coal (rather than the typical approach of burning part of the coal) results in these higher efficiencies.

Lytle, J.M.; Marchant, D.D.

1980-11-01T23:59:59.000Z

15

Wabash River coal gasification repowering project: Public design report  

SciTech Connect

The Wabash River Coal Gasification Repowering Project (the Project), conceived in October of 1990 and selected by the US Department of Energy as a Clean Coal IV demonstration project in September 1991, is expected to begin commercial operations in August of 1995. The Participants, Destec Energy, Inc., (Destec) of Houston, Texas and PSI Energy, Inc., (PSI) of Plainfield, Indiana, formed the Wabash River Coal Gasification Repowering Project Joint Venture (the JV) to participate in the DOE`s Clean Coal Technology (CCT) program by demonstrating the coal gasification repowering of an existing 1950`s vintage generating unit affected by the Clean Air Act Amendments (CAAA). The Participants, acting through the JV, signed the Cooperative Agreement with the DOE in July 1992. The Participants jointly developed, and separately designed, constructed, own, and will operate an integrated coal gasification combined cycle (CGCC) power plant using Destec`s coal gasification technology to repower Unit {number_sign}1 at PSI`s Wabash River Generating Station located in Terre Haute, Indiana. PSI is responsible for the new power generation facilities and modification of the existing unit, while Destec is responsible for the coal gasification plant. The Project demonstrates integration of the pre-existing steam turbine generator, auxiliaries, and coal handling facilities with a new combustion turbine generator/heat recovery steam generator tandem and the coal gasification facilities.

1995-07-01T23:59:59.000Z

16

WABASH RIVER COAL GASIFICATION REPOWERING PROJECT  

Science Conference Proceedings (OSTI)

The close of 1999 marked the completion of the Demonstration Period of the Wabash River Coal Gasification Repowering Project. This Final Report summarizes the engineering and construction phases and details the learning experiences from the first four years of commercial operation that made up the Demonstration Period under Department of Energy (DOE) Cooperative Agreement DE-FC21-92MC29310. This 262 MWe project is a joint venture of Global Energy Inc. (Global acquired Destec Energy's gasification assets from Dynegy in 1999) and PSI Energy, a part of Cinergy Corp. The Joint Venture was formed to participate in the Department of Energy's Clean Coal Technology (CCT) program and to demonstrate coal gasification repowering of an existing generating unit impacted by the Clean Air Act Amendments. The participants jointly developed, separately designed, constructed, own, and are now operating an integrated coal gasification combined-cycle power plant, using Global Energy's E-Gas{trademark} technology (E-Gas{trademark} is the name given to the former Destec technology developed by Dow, Destec, and Dynegy). The E-Gas{trademark} process is integrated with a new General Electric 7FA combustion turbine generator and a heat recovery steam generator in the repowering of a 1950's-vintage Westinghouse steam turbine generator using some pre-existing coal handling facilities, interconnections, and other auxiliaries. The gasification facility utilizes local high sulfur coals (up to 5.9% sulfur) and produces synthetic gas (syngas), sulfur and slag by-products. The Project has the distinction of being the largest single train coal gasification combined-cycle plant in the Western Hemisphere and is the cleanest coal-fired plant of any type in the world. The Project was the first of the CCT integrated gasification combined-cycle (IGCC) projects to achieve commercial operation.

Unknown

2000-09-01T23:59:59.000Z

17

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

18

Steam-injected gas turbines uneconomical with coal gasification equipment  

SciTech Connect

Researchers at the Electric Power Research Institute conducted a series of engineering and economic studies to assess the possibility of substituting steam-injected gas (STIG) turbines for the gas turbines currently proposed for use in British Gas Corporation (BGC)/Lurgi coal gasification-combined cycle plants. The study sought to determine whether steam-injected gas turbines and intercooled steam-injected gas turbines, as proposed by General Electric would be economically competitive with conventional gas and steam turbines when integrated with coal gasification equipment. The results are tabulated in the paper.

1986-09-01T23:59:59.000Z

19

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

20

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

Note: This page contains sample records for the topic "integrated coal-gasification combined" 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

Performance and operational economics estimates for a coal gasification combined-cycle cogeneration powerplant  

SciTech Connect

A performance and operational economics analysis is presented for an integrated-gasifier, combined-cycle (IGCC) system to meet the steam and baseload electrical requirements. The effect of time variations in steam and electrial requirements is included. The amount and timing of electricity purchases from sales to the electric utility are determined. The resulting expenses for purchased electricity and revenues from electricity sales are estimated by using an assumed utility rate structure model. Cogeneration results for a range of potential IGCC cogeneration system sizes are compared with the fuel consumption and costs of natural gas and electricity to meet requirements without cogeneration. The results indicate that an IGCC cogeneration system could save about 10 percent of the total fuel energy presently required to supply steam and electrical requirements without cogeneration. Also for the assumed future fuel and electricity prices, an annual operating cost savings of 21 percent to 26 percent could be achieved with such a cogeneration system. An analysis of the effects of electricity price, fuel price, and system availability indicates that the IGCC cogeneration system has a good potential for economical operation over a wide range in these assumptions.

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

1982-03-01T23:59:59.000Z

22

The Role of Oxygen in Coal Gasification  

E-Print Network (OSTI)

Air Products supplies oxygen to a number of coal gasification and partial oxidation facilities worldwide. At the high operating pressures of these processes, economics favor the use of 90% and higher oxygen purities. The effect of inerts in the oxidant on gasifier and downstream production units also favor the use of oxygen in place of air. Factors that must be considered in selecting the optimum oxygen purity include: end use of the gasifier products, oxygen delivery pressure and the cost of capital and energy. This paper examines the major factors in oxygen purity selection for typical coal gasifiers. Examples demonstrating the effect of oxygen purity on several processes are presented: production of synthetic natural gas (SNG), integrated gasification combined-cycle (IGCC) power generation and methanol synthesis. The potential impact of a non-cryogenic air separation process currently under development is examined based on integration with a high temperature processes.

Klosek, J.; Smith, A. R.; Solomon, J.

1986-06-01T23:59:59.000Z

23

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

24

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

Science Conference Proceedings (OSTI)

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

Not Available

1993-05-01T23:59:59.000Z

25

Catalytic Coal Gasification Process  

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

Catalytic Coal Gasification Process Catalytic Coal Gasification Process for the Production of Methane-Rich Syngas Opportunity Research is active on the patent pending technology, titled "Production of Methane-Rich Syngas from Fuels Using Multi-functional Catalyst/Capture Agent." This technology is available for licensing and/or further collaborative research from the U.S. Department of Energy's National Energy Technology Laboratory. Overview Reducing pollution emitted by coal and waste power plants in an economically viable manner and building power plants that co-generate fuels and chemicals during times of low electricity demand are pressing goals for the energy industry. One way to achieve these goals in an economically viable manner is through the use of a catalytic gasifier that

26

PNNL Coal Gasification Research  

Science Conference Proceedings (OSTI)

This report explains the goals of PNNL in relation to coal gasification research. The long-term intent of this effort is to produce a syngas product for use by internal Pacific Northwest National Laboratory (PNNL) researchers in materials, catalysts, and instrumentation development. Future work on the project will focus on improving the reliability and performance of the gasifier, with a goal of continuous operation for 4 hours using coal feedstock. In addition, system modifications to increase operational flexibility and reliability or accommodate other fuel sources that can be used for syngas production could be useful.

Reid, Douglas J.; Cabe, James E.; Bearden, Mark D.

2010-07-28T23:59:59.000Z

27

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

28

Coal gasification vessel  

DOE Patents (OSTI)

A vessel system (10) comprises an outer shell (14) of carbon fibers held in a binder, a coolant circulation mechanism (16) and control mechanism (42) and an inner shell (46) comprised of a refractory material and is of light weight and capable of withstanding the extreme temperature and pressure environment of, for example, a coal gasification process. The control mechanism (42) can be computer controlled and can be used to monitor and modulate the coolant which is provided through the circulation mechanism (16) for cooling and protecting the carbon fiber and outer shell (14). The control mechanism (42) is also used to locate any isolated hot spots which may occur through the local disintegration of the inner refractory shell (46).

Loo, Billy W. (Oakland, CA)

1982-01-01T23:59:59.000Z

29

Two-stage coal gasification and desulfurization  

DOE Patents (OSTI)

The present invention is directed to a system which effectively integrates a two-stage, fixed-bed coal gasification arrangement with hot fuel gas desulfurization of a first stream of fuel gas from a lower stage of the two-stage gasifier and the removal of sulfur from the sulfur sorbent regeneration gas utilized in the fuel-gas desulfurization process by burning a second stream of fuel gas from the upper stage of the gasifier in a combustion device in the presence of calcium-containing material. The second stream of fuel gas is taken from above the fixed bed in the coal gasifier and is laden with ammonia, tar and sulfur values. This second stream of fuel gas is burned in the presence of excess air to provide heat energy sufficient to effect a calcium-sulfur compound forming reaction between the calcium-containing material and sulfur values carried by the regeneration gas and the second stream of fuel gas. Any ammonia values present in the fuel gas are decomposed during the combustion of the fuel gas in the combustion chamber. The substantially sulfur-free products of combustion may then be combined with the desulfurized fuel gas for providing a combustible fluid utilized for driving a prime mover. 1 fig.

Bissett, L.A.; Strickland, L.D.

1990-08-03T23:59:59.000Z

30

Beluga Coal Gasification - ISER  

SciTech Connect

ISER was requested to conduct an economic analysis of a possible 'Cook Inlet Syngas Pipeline'. The economic analysis was incorporated as section 7.4 of the larger report titled: 'Beluga Coal Gasification Feasibility Study, DOE/NETL-2006/1248, Phase 2 Final Report, October 2006, for Subtask 41817.333.01.01'. The pipeline would carry CO{sub 2} and N{sub 2}-H{sub 2} from a synthetic gas plant on the western side of Cook Inlet to Agrium's facility. The economic analysis determined that the net present value of the total capital and operating lifecycle costs for the pipeline ranges from $318 to $588 million. The greatest contributor to this spread is the cost of electricity, which ranges from $0.05 to $0.10/kWh in this analysis. The financial analysis shows that the delivery cost of gas may range from $0.33 to $0.55/Mcf in the first year depending primarily on the price for electricity.

Steve Colt

2008-12-31T23:59:59.000Z

31

The Caterpillar Coal Gasification Facility  

E-Print Network (OSTI)

This paper is a review of one of America's premier coal gasification installations. The caterpillar coal gasification facility located in York, Pennsylvania is an award winning facility. The plant was recognized as the 'pace setter plant of the year' in 1981 and won the 'energy conservation award' for 1983. The decision to install and operate a coal gasification plant was based on severe natural gas curtailments at York with continuing supply interruptions. This paper will present a detailed description of the equipment used in the coal gasification system and the process itself. It also includes operating and gas production information along with an economic analysis. The characteristics of producer gas and its use in the various plant applications will be reviewed and compared with natural gas. In summary, this paper deals with caterpillar's experience with coal gasification to date. Caterpillar concludes that the coal gas system has the potential to favorably affect the corporation's commitment to stimulate coal utilization. The three years' operating experience at the York plant has demonstrated the practical use of coal gas as well as the economics associated with producing gas from coal.

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

1983-01-01T23:59:59.000Z

32

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

33

Great Plains Coal Gasification Project:  

Science Conference Proceedings (OSTI)

This progress report on the Great Plains Coal Gasification Project discusses Lignite coal, natural gas, and by-products production as well as gas quality. A tabulation of raw material, product and energy consumption is provided for plant operations. Capital improvement projects and plant maintenance activities are detailed and summaries are provided for environmental, safety, medical, quality assurance, and qualtiy control activities.

Not Available

1988-01-29T23:59:59.000Z

34

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

35

CFD Simulation of Underground Coal Gasification.  

E-Print Network (OSTI)

??Underground Coal Gasification (UCG) is a process in which coal is converted to syngas in-situ. UCG has gained popularity recently as it could be used… (more)

Sarraf Shirazi, Ahad

2012-01-01T23:59:59.000Z

36

EA-1219: Hoe Creek Underground Coal Gasification Test Site Remediation...  

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

9: Hoe Creek Underground Coal Gasification Test Site Remediation, Campbell County, Wyoming EA-1219: Hoe Creek Underground Coal Gasification Test Site Remediation, Campbell County,...

37

Short Communication Catalytic coal gasification: use of calcium versus potassium*  

E-Print Network (OSTI)

career on process optimization and control, fluid mechanics, the analysis of coal gasification reactors my earlier work on coal gasification reactors, polymer fiber spinning, and the activated sludge

38

Integrated Sensing and Controls for Coal Gasification - Development of Model-Based Controls for GE's Gasifier and Syngas Cooler  

Science Conference Proceedings (OSTI)

This report summarizes the achievements and final results of this program. The objective of this program is to develop a comprehensive systems approach to integrated design of sensing and control systems for an Integrated Gasification Combined Cycle (IGCC) plant, using advanced model-based techniques. In particular, this program is focused on the model-based sensing and control system design for the core gasification section of an IGCC plant. The overall approach consists of (i) developing a first-principles physics-based dynamic model of the gasification section, (ii) performing model-reduction where needed to derive low-order models suitable for controls analysis and design, (iii) developing a sensing system solution combining online sensors with model-based estimation for important process variables not measured directly, and (iv) optimizing the steady-state and transient operation of the plant for normal operation as well as for startup using model predictive controls (MPC). Initially, available process unit models were implemented in a common platform using Matlab/Simulink{reg_sign}, and appropriate model reduction and model updates were performed to obtain the overall gasification section dynamic model. Also, a set of sensor packages were developed through extensive lab testing and implemented in the Tampa Electric Company IGCC plant at Polk power station in 2009, to measure temperature and strain in the radiant syngas cooler (RSC). Plant operation data was also used to validate the overall gasification section model. The overall dynamic model was then used to develop a sensing solution including a set of online sensors coupled with model-based estimation using nonlinear extended Kalman filter (EKF). Its performance in terms of estimating key unmeasured variables like gasifier temperature, carbon conversion, etc., was studied through extensive simulations in the presence sensing errors (noise and bias) and modeling errors (e.g. unknown gasifier kinetics, RSC fouling). In parallel, an MPC solution was initially developed using ideal sensing to optimize the plant operation during startup pre-heating as well as steady state and transient operation under normal high-pressure conditions, e.g. part-load, base-load, load transition and fuel changes. The MPC simulation studies showed significant improvements both for startup pre-heating and for normal operation. Finally, the EKF and MPC solutions were coupled to achieve the integrated sensing and control solution and its performance was studied through extensive steady state and transient simulations in the presence of sensor and modeling errors. The results of each task in the program and overall conclusions are summarized in this final report.

Aditya Kumar

2010-12-30T23:59:59.000Z

39

Wabash River Coal Gasification Repowering Project: A DOE Assessment  

SciTech Connect

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

National Energy Technology Laboratory

2002-01-15T23:59:59.000Z

40

Improved catalysts for carbon and coal gasification  

DOE Patents (OSTI)

This invention relates to improved catalysts for carbon and coal gasification and improved processes for catalytic coal gasification for the production of methane. The catalyst is composed of at least two alkali metal salts and a particulate carbonaceous substrate or carrier is used. 10 figures, 2 tables.

McKee, D.W.; Spiro, C.L.; Kosky, P.G.

1984-05-25T23:59:59.000Z

Note: This page contains sample records for the topic "integrated coal-gasification combined" 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

Coal gasification vessel. [Patent application  

DOE Patents (OSTI)

A vessel system comprises an outer shell of carbon fibers held in a binder, a coolant circulation mechanism and control mechanism and an inner shell comprised of a refractory material and is of light weight and capable of withstanding the extreme temperature and pressure environment of, for example, a coal gasification process. The control mechanism can be computer controlled and can be used to monitor and modulate the coolant which is provided through the circulation mechanism for cooling and protecting the carbon fiber and outer shell. The control mechanism is also used to locate any isolated hot spots which may occur through the local disintegration of the inner refractory shell.

Loo, B.W.

1981-03-17T23:59:59.000Z

42

Coal gasification plant  

DOE Patents (OSTI)

A removable annular hearth member, shaped to fit over the slag outlet of a slagging gasifier, comprises a cast body of high thermal conductivity having integral coolant passageways, said passageways being formed by shaping a metal tube into a coil having an inlet and an outlet, and casting metal to the desired shape around the coil such that the inlet and outlet communicate exteriorly of the cast body.

Wood, Andrew (Dunfermline, GB6)

1978-01-01T23:59:59.000Z

43

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

44

Wabash River Coal Gasification Repowering Project: A DOE Assessment  

Science Conference Proceedings (OSTI)

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

National Energy Technology Laboratory

2002-01-15T23:59:59.000Z

45

Apparatus for fixed bed coal gasification  

DOE Patents (OSTI)

An apparatus for fixed-bed coal gasification is described in which coal such as caking coal is continuously pyrolyzed with clump formation inhibited, by combining the coal with a combustible gas and an oxidant, and then continually feeding the pyrolyzed coal under pressure and elevated temperature into the gasification region of a pressure vessel. The materials in the pressure vessel are allowed to react with the gasifying agents in order to allow the carbon contents of the pyrolyzed coal to be completely oxidized. The combustion of gas produced from the combination of coal pyrolysis and gasification involves combining a combustible gas coal and an oxidant in a pyrolysis chamber and heating the components to a temperature of at least 1600.degree. F. The products of coal pyrolysis are dispersed from the pyrolyzer directly into the high temperature gasification region of a pressure vessel. Steam and air needed for gasification are introduced in the pressure vessel and the materials exiting the pyrolyzer flow down through the pressure vessel by gravity with sufficient residence time to allow any carbon to form carbon monoxide. Gas produced from these reactions are then released from the pressure vessel and ash is disposed of.

Sadowski, Richard S. (Greenville, SC)

1992-01-01T23:59:59.000Z

46

Two-stage coal gasification and desulfurization apparatus  

DOE Patents (OSTI)

The present invention is directed to a system which effectively integrates a two-stage, fixed-bed coal gasification arrangement with hot fuel gas desulfurization of a first stream of fuel gas from a lower stage of the two-stage gasifier and the removal of sulfur from the sulfur sorbent regeneration gas utilized in the fuel-gas desulfurization process by burning a second stream of fuel gas from the upper stage of the gasifier in a combustion device in the presence of calcium-containing material. The second stream of fuel gas is taken from above the fixed bed in the coal gasifier and is laden with ammonia, tar and sulfur values. This second stream of fuel gas is burned in the presence of excess air to provide heat energy sufficient to effect a calcium-sulfur compound forming reaction between the calcium-containing material and sulfur values carried by the regeneration gas and the second stream of fuel gas. Any ammonia values present in the fuel gas are decomposed during the combustion of the fuel gas in the combustion chamber. The substantially sulfur-free products of combustion may then be combined with the desulfurized fuel gas for providing a combustible fluid utilized for driving a prime mover.

Bissett, Larry A. (Morgantown, WV); Strickland, Larry D. (Morgantown, WV)

1991-01-01T23:59:59.000Z

47

Diffusion Coatings for Corrosion Resistant Components in Coal Gasification Systems  

SciTech Connect

Heat-exchangers, particle filters, turbines, and other components in integrated coal gasification combined cycle system must withstand the highly sulfiding conditions of the high temperature coal gas over an extended period of time. The performance of components degrades significantly with time unless expensive high alloy materials are used. Deposition of a suitable coating on a low cost alloy may improve its resistance to such sulfidation attack and decrease capital and operating costs. The alloys used in the gasifier service include austenitic and ferritic stainless steels, nickel-chromium-iron alloys, and expensive nickel-cobalt alloys. During this reporting period we focused on getting a bench-scale test system to expose alloy coupons to simulated gasifier environment. The test facility was designed to allow about 20 specimen coupons to be exposed simultaneously for an extend period to a simulated coal gas stream at temperatures up to 1000 C. The simulated gas stream contained about 26%H{sub 2}, 39%CO, 17%CO{sub 2}, 1.4% H{sub 2}S and balance steam. We successfully ran a 100+h test with coated and uncoated stainless steel coupons. The tested alloys include SS304, SS316, SS405, SS409, SS410, and IN800. The main finding is that Ti/Ta coating provides excellent protection to SS405 under conditions where uncoated austenitic and ferritic stainless steel alloy coupons are badly corroded. Cr coatings also appear to afford some protection against corrosion.

Gopala N. Krishnan; Ripudaman Malhotra; Esperanza Alvarez; Kai-Hung Lau; Angel Sanjurjo

2005-01-01T23:59:59.000Z

48

Diffusion Coatings for Corrosion-Resistant Components in Coal Gasification Systems  

SciTech Connect

Heat-exchangers, particle filters, turbines, and other components in integrated coal gasification combined cycle system must withstand the highly sulfiding conditions of the high-temperature coal gas over an extended period of time. The performance of components degrades significantly with time unless expensive high alloy materials are used. Deposition of a suitable coating on a low-cost alloy may improve its resistance to such sulfidation attack, and decrease capital and operating costs. The alloys used in the gasifier service include austenitic and ferritic stainless steels, nickel-chromium-iron alloys, and expensive nickel-cobalt alloys. During this period, we analyzed several coated and exposed samples of 409 steel by scanning electron microscopy (SEM) and energy-dispersive X-ray (EDX), and report on the findings of four samples: (1) Analysis of two porous coupons after exposure to the porous metal particulate filter of the coal gasification power plant at 370 C for 2140 hours revealed that corrosion takes place in the bulk of the sample while the most external zone surface survived the test. (2) Coating and characterization of several porous 409 steel coupons after being coated with nitrides of Ti, Al and/or Si showed that adjusting experimental conditions results in thicker coatings in the bulk of the sample. (3) Analysis of coupons exposed to simulated coal gas at 370 C for 300 hours showed that a better corrosion resistance is achieved by improving the coatings in the bulk of the samples.

Gopala N. Krishnan; Ripudaman Malhotra; Esperanza Alvarez; Kai-Hung Lau; Jordi Perez-Mariano; Angel Sanjurjo

2006-12-31T23:59:59.000Z

49

Production of Hydrogen from Underground Coal Gasification  

DOE Patents (OSTI)

A system of obtaining hydrogen from a coal seam by providing a production well that extends into the coal seam; positioning a conduit in the production well leaving an annulus between the conduit and the coal gasification production well, the conduit having a wall; closing the annulus at the lower end to seal it from the coal gasification cavity and the syngas; providing at least a portion of the wall with a bifunctional membrane that serves the dual purpose of providing a catalyzing reaction and selectively allowing hydrogen to pass through the wall and into the annulus; and producing the hydrogen through the annulus.

Upadhye, Ravindra S. (Pleasanton, CA)

2008-10-07T23:59:59.000Z

50

Co-Production of Substitute Natural Gas/Electricity Via Catalytic Coal Gasification  

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

9 9 Co-ProduCtion of SubStitute natural GaS / eleCtriCity via CatalytiC Coal GaSifiCation Description The United States has vast reserves of low-cost coal, estimated to be sufficient for the next 250 years. Gasification-based technology, such as Integrated Gasification Combined Cycle (IGCC), is the only environmentally friendly technology that provides the flexibility to co-produce hydrogen, substitute natural gas (SNG), premium hydrocarbon liquids including transportation fuels, and electric power in desired combinations from coal and other carbonaceous feedstocks. Rising costs and limited domestic supply of crude oil and natural gas provide a strong incentive for the development of coal gasification-based co-production processes. This project addresses the co-production of SNG and electricity from coal via gasification

51

Science and Technology Gaps in Underground Coal Gasification  

DOE Green Energy (OSTI)

Underground coal gasification (UCG) is an appropriate technology to economically access the energy resources in deep and/or unmineable coal seams and potentially to extract these reserves through production of synthetic gas (syngas) for power generation, production of synthetic liquid fuels, natural gas, or chemicals. India is a potentially good area for underground coal gasification. India has an estimated amount of about 467 billion British tons (bt) of possible reserves, nearly 66% of which is potential candidate for UCG, located at deep to intermediate depths and are low grade. Furthermore, the coal available in India is of poor quality, with very high ash content and low calorific value. Use of coal gasification has the potential to eliminate the environmental hazards associated with ash, with open pit mining and with greenhouse gas emissions if UCG is combined with re-injection of the CO{sub 2} fraction of the produced gas. With respect to carbon emissions, India's dependence on coal and its projected rapid rise in electricity demand will make it one of the world's largest CO{sub 2} producers in the near future. Underground coal gasification, with separation and reinjection of the CO{sub 2} produced by the process, is one strategy that can decouple rising electricity demand from rising greenhouse gas contributions. UCG is well suited to India's current and emerging energy demands. The syngas produced by UCG can be used to generate electricity through combined cycle. It can also be shifted chemically to produce synthetic natural gas (e.g., Great Plains Gasification Plant in North Dakota). It may also serve as a feedstock for methanol, gasoline, or diesel fuel production and even as a hydrogen supply. Currently, this technology could be deployed in both eastern and western India in highly populated areas, thus reducing overall energy demand. Most importantly, the reduced capital costs and need for better surface facilities provide a platform for rapid acceleration of coal-gas-fired electric power and other high value products. In summary, UCG has several important economic and environmental benefits relevant to India's energy goals: (1) It requires no purchase of surface gasifiers, reducing capital expense substantially. (2) It requires no ash management, since ash remains in the subsurface. (3) It reduces the cost of pollution management and emits few black-carbon particulates. (4) It greatly reduces the cost of CO2 separation for greenhouse gas management, creating the potential for carbon crediting through the Kyoto Clean Development Mechanism. (5) It greatly reduces the need to mine and transport coal, since coal is used in-situ.

Upadhye, R; Burton, E; Friedmann, J

2006-06-27T23:59:59.000Z

52

Higgins coal gasification/repowering study: feasibility study for alternate fuels. [Higgins power plant, Pinellar County, Florida  

Science Conference Proceedings (OSTI)

In 1978, FPC determined that repowering the existing 138 MW Higgins power plant would provide the most economical means for meeting immediate additional power requirements. The use of an integrated coal gasification combined cycle power plant offered the opportunity to revive the Higgins repowering concept without potential Fuel Use Act restrictions. The existing Higgins power plant is located at the north end of Tampa Bay on Booth Point, near the City of Oldsmar in Pinellas County, Florida. The basis for this feasibility study is to prepare a preliminary facility design for repowering the existing Higgins plant steam turbine generators utilizing coal gasification combined cycle (CGCC) technology to produce an additional 300 MW of power. The repowering is to be accomplished by integrating British Gas/Lurgi slagging gasifiers with combined cycle equipment consisting of new combustion turbines and heat recovery steam generators (HRSGs), and the existing steam turbines. The proposed CGCC facility has been designed for daily cyclic duty. However, since it was anticipated that the heat rate would be lower than at other existing FPC units, the CGCC facility has also been designed with base load operation capabilities.

Not Available

1981-12-01T23:59:59.000Z

53

Diffusion Coatings for Corrosion-Resistant Components in Coal Gasification Systems  

Science Conference Proceedings (OSTI)

Heat-exchangers, particle filters, turbines, and other components in integrated coal gasification combined cycle system must withstand the highly sulfiding conditions of the high temperature coal gas over an extended period of time. The performance of components degrades significantly with time unless expensive high alloy materials are used. Deposition of a suitable coating on a low-cost alloy may improve its resistance to such sulfidation attack, and decrease capital and operating costs. The alloys used in the gasifier service include austenitic and ferritic stainless steels, nickel-chromium-iron alloys, and expensive nickel-cobalt alloys. The primary activity this period was preparation and presentation of the findings on this project at the Twenty-Third annual Pittsburgh Coal Conference. Dr. Malhotra attended this conference and presented a paper. A copy of his presentation constitutes this quarterly report.

Gopala N. Krishnan; Ripudaman Malhotra; Esperanza Alvarez; Kai-Hung Lau; Jordi Perez Mariano; Angel Sanjurjo

2006-09-30T23:59:59.000Z

54

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

55

Fluidized bed injection assembly for coal gasification  

DOE Patents (OSTI)

A coaxial feed system for fluidized bed coal gasification processes including an inner tube for injecting particulate combustibles into a transport gas, an inner annulus about the inner tube for injecting an oxidizing gas, and an outer annulus about the inner annulus for transporting a fluidizing and cooling gas. The combustibles and oxidizing gas are discharged vertically upward directly into the combustion jet, and the fluidizing and cooling gas is discharged in a downward radial direction into the bed below the combustion jet.

Cherish, Peter (Bethel Park, PA); Salvador, Louis A. (Hempfield Township, Westmoreland County, PA)

1981-01-01T23:59:59.000Z

56

The Study of Coal Gasification by Molten Blast Furnace Slag  

Science Conference Proceedings (OSTI)

About this Abstract. Meeting, 2011 TMS Annual Meeting & Exhibition. Symposium , Waste Heat Recovery. Presentation Title, The Study of Coal Gasification by ...

57

Houston Lighting and Power Company's evaluation of coal gasification coproduction energy facilities  

SciTech Connect

In an effort to reduce the cost of electricity from Integral ed Gasification Combined Cycle (IGCC) Power Plants, the Electric Power Research Institute has embarked on a program to evaluate and potentially demonstrate a coal gasification-based coproduction energy facility. Houston Lighting Power Company (HL P) responded with a proposal in its ongoing effort to study emerging technologies for electricity production. HL P recognized the opportunities available to them in coproduction because of their close proximity to the world's largest petrochemical complex located on the Houston Ship Channel. Coparticipant utilities with HL P were Central and South West Services and TU Electric. Two sites were selected for study, a Houston Ship Channel site, utilizing barge-delivered Illinois No. 6 coal blended with petroleum coke, and to satisfy C SWS and TU needs, a central Texas site utilizing Texas lignite. Stone Webster Engineering and InterFact, Inc. were engineers and consulting partners in the study.Eight cases were developed to cover the various possibilities for coproduction. Four cases involved utilizing Texas lignite and four cases involved utilizing Illinois No. 6 as fuel blended with petroleum coke. The eight cases are described. Each of the cases utilized the Shell coal gasification process and were evaluated for either base load operation using two G.E. 7F gas turbines and a spare gasifier for chemicals production or for cyclic operationusing four G.E. 7EA gas turbines and no spare gasifier. The sum of the coproducts produced over all eight cases were electricity, methanol, ammonia, and urea, depending on location and economics.

Kern, E.E.; Havemann, S.D.; Chmielewski, R.G. (Houston Lighting and Power Co., TX (United States)); Baumann, P. (InterFact, Inc., Dallas, TX (United States)); Goelzer, A.R.; Karayel, R.; Keady, G.S.; Chernoff, B. (Stone and Webster Engineering Corp., Houston, TX (United States))

1992-12-01T23:59:59.000Z

58

Wabash River Coal Gasification Repowering Project Final Technical Report  

Office of Scientific and Technical Information (OSTI)

Wabash River Coal Gasification Wabash River Coal Gasification Repowering Project Final Technical Report August 2000 Work Performed Under Cooperative Agreement DE-FC21-92MC29310 For: The U.S. Department of Energy Office of Fossil Energy National Energy Technology Laboratory Morgantown, West Virginia Prepared by: The Men and Women of Wabash River Energy Ltd. For Further Information Contact: Roy A. Dowd, CHMM Environmental Supervisor Wabash River Coal Gasification Repowering Project 444 West Sandford Avenue West Terre Haute, IN 47885 LEGAL NOTICE/DISCLAIMER This report was prepared by the Wabash River Coal Gasification Repowering Project Joint Venture pursuant to a Cooperative Agreement partially funded by the U.S. Department of Energy, and neither the Wabash River Coal Gasification Repowering

59

Method for control of subsurface coal gasification  

SciTech Connect

The burn front in an in situ underground coal gasification operation is controlled by utilizing at least two parallel groups of vertical bore holes disposed in the coalbed at spaced-apart locations in planes orthogonal to the plane of maximum permeability in the coalbed. The combustion of the coal is initiated in the coalbed adjacent to one group of the bore holes to establish a combustion zone extending across the group while the pressure of the combustion supporting gas mixture and/or the combustion products is regulated at each well head by valving to control the burn rate and maintain a uniform propagation of the burn front between the spaced-apart hole groups to gasify virtually all the coal lying therebetween.

Komar, Charles A. (Uniontown, PA)

1976-12-14T23:59:59.000Z

60

Underground Coal Gasification at Tennessee Colony  

E-Print Network (OSTI)

The Tennessee Colony In Situ Coal Gasification Project conducted by Basic Resources Inc. is the most recent step in Texas Utilities Company's ongoing research into the utilization of Texas lignite. The project, an application of the Soviet technology which was acquired under a license agreement in 1975, is a continuation of the field testing program to examine the feasibility of in situ lignite gasification in Texas which began with a 27-day test burn at a site near Fairfield in August of 1976. The objectives of the Tennessee Colony Project are to examine the economic, technological and environmental aspects of a commercial project. The Project which began in August of 1978 utilizes air as the oxidizing agent and is comprised of two channels of gasification operating simultaneously. The test is presently still in progress and producing gas with a heat content in the range of 8-100 Btu.

Garrard, C. W.

1979-01-01T23:59:59.000Z

Note: This page contains sample records for the topic "integrated coal-gasification combined" 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

Coal gasification construction materials: an overview  

SciTech Connect

Materials performance test results are presented for two coal gasification processes, HYGAS SNG process, which converts any type of coal to substitute natural gas (SNG), and U-GAS fuel gas process, which converts coal to a low- or medium-heat value gas. A description of the pilot plant for each process and discussion of some experiences with materials and components used in plant construction is presented. Metals performance inside the gasifier reactors and in off-gas locations depended upon the character of the process. At moderate operating temperatures (427/sup 0/C), low-carbon steels are advisable. Very high-temperature environments may not only require use of exotic alloys, clads, and/or coatings but may also preclude extensive use of internal piping/valving in scale-up designs. Inconel 182, 600, and Monel 400 have all performed erratically in the plants; but in quench and purification sections, austenitic stainless steels performed well. 9 references. (BLM)

Arnold, J.M. (Inst. of Gas Tech., Chicago, IL); Laurens, R.M.; Danyluk, S.

1981-12-01T23:59:59.000Z

62

Low temperature steam-coal gasification catalysts  

SciTech Connect

Shrinking domestic supplies and larger dependence on foreign sources have made an assortment of fossil fuels attractive as possible energy sources. The high sulfur and mineral coals of Illinois would be an ideal candidate as possible gasification feedstock. Large reserves of coal as fossil fuel source and a projected shortage of natural gas (methane) in the US, have made development of technology for commercial production of high Btu pipeline gases from coal of interest. Several coal gasification processes exist, but incentives remain for the development of processes that would significantly increase efficiency and lower cost. A major problem in coal/char gasification is the heat required which make the process energy intensive. Hence, there is a need for an efficient and thermally neutral gasification process. Results are described for the gasification of an Illinois No. 6 coal with transition metal catalysts and added potassium hydroxide.

Hippo, E.J.; Tandon, D. [Southern Illinois Univ., Carbondale, IL (United States)

1996-12-31T23:59:59.000Z

63

NETL: News Release - Coal Gasification Plant Returns $79 Million to DOE in  

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

2, 2006 2, 2006 Coal Gasification Plant Returns $79 Million to DOE in Revenue-Sharing Gas Sales Plant Currently Supplies Carbon Dioxide for DOE Sequestration Project Washington, DC -A coal gasification plant purchased from the U.S. Department of Energy (DOE) in 1988 recently paid millions of dollars to DOE as part of a revenue sharing agreement and continues to be an integral part of a Department project to sequester millions of tons of carbon dioxide while doubling an oil field's recovery rate. MORE INFO Learn more about the Great Plains Synfuels Plant The Dakota Gasification Company (DGC), which purchased the Great Plains Synfuels Plant near Beulah, N.D., recently announced the payment of more than $79 million to DOE as part of a revenue-sharing agreement signed in

64

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

65

Coal gasification via the Lurgi process: Topical report: Volume 1, Production of SNG (substitute material gas)  

Science Conference Proceedings (OSTI)

A Lurgi baseline study was requested by the DOE/GRI Operating Committee of the Joint Coal Gasification Program for the purpose of updating the economics of earlier Lurgi coal gasification plant studies for the production of substitute natural gas (SNG) based on commercially advanced technologies. The current study incorporates the recent experience with large size Lurgi plants in an effort to improve capital and operating costs of earlier plant designs. The present coal gasification study is based on a mine mouth plant producing 250 billion Btu (HHV) per day of SNG using the Lurgi dry bottom coal gasification technology. A Western subbituminous coal was designated as the plant food, obtained from the Rosebud seam at Colstrip, Montana. This study presents the detailed description of an integrated facility which utilizes coal, air, and water to produce 250 billion Btu (HHV) per day of SNG. The plant consists of coal handling and preparation, twenty-six Lurgi dry bottom gasifiers, shift conversion, acid gas removal, methanation, compression and drying of product gas, sulfur recovery, phenol and ammonia recovery, as well as necessary support facilities. The plant is a grass roots, mine mouth facility located in a Western location similar to the town of Colstrip in Rosebud County, Montana. The Lurgi Corporation assisted in this study, under subcontract to Foster Wheeler, by supplying the heat and material balances, flow sheets, utilities, catalysts and chemical requirements, and cost data for Lurgi designed process sections. Details of material supplied by Lurgi Corporation are presented in Appendix A. 52 refs., 36 figs., 64 tabs.

Zahnstecher, L.W.

1984-09-01T23:59:59.000Z

66

Diffusion Coatings for Corrosion-Resistant Components in Coal Gasification Systems  

Science Conference Proceedings (OSTI)

Heat-exchangers, particle filters, turbines, and other components in integrated coal gasification combined cycle system must withstand the highly sulfiding conditions of the high-temperature coal gas over an extended period of time. The performance of components degrades significantly with time unless expensive high alloy materials are used. Deposition of a suitable coating on a low-cost alloy may improve its resistance to such sulfidation attack, and decrease capital and operating costs. The alloys used in the gasifier service include austenitic and ferritic stainless steels, nickel-chromium-iron alloys, and expensive nickel-cobalt alloys. During this period, we conducted two 300-hour tests. In the first test, we exposed samples at 900 C under conditions simulating the high-temperature heat recovery unit (HTHRU). The second test was at 370 C, corresponding to the filter units following the HTHRU. The tests were showed the resilience of silicon nitride as a coating component, and the new coating procedures better penetrated the pores in sintered metal filter samples. Finally, we also received samples that were exposed in the Wabash River plant. Unfortunately, all these samples, that were prepared last year, were severely eroded and/or corroded.

Gopala N. Krishnan; Ripudaman Malhotra; Esperanza Alvarez; Kai-Hung Lau; Jordi Perez-Mariano; Angel Sanjurjo

2005-03-15T23:59:59.000Z

67

Diffusion Coatings for Corrosion-Resistant Components in Coal Gasification Systems  

Science Conference Proceedings (OSTI)

Heat-exchangers, particle filters, turbines, and other components in integrated coal gasification combined cycle system must withstand the highly sulfiding conditions of the high-temperature coal gas over an extended period of time. The performance of components degrades significantly with time unless expensive high alloy materials are used. Deposition of a suitable coating on a low-cost alloy may improve its resistance to such sulfidation attack, and decrease capital and operating costs. The alloys used in the gasifier service include austenitic and ferritic stainless steels, nickel-chromium-iron alloys, and expensive nickel-cobalt alloys. In previous tests, we had frequently encountered problems with our steam generator that were exacerbated by the very low flow rates that we needed. During this period we installed a new computer-controlled system for injecting water into the steam generator that eliminated this problem. We also tested alloy coupons coated by using the improved procedures described in our last quarterly report. Most of these coatings were nitrided Ti and Ta coatings, either by themselves, or sometimes with barrier layers of Al and Si nitrides. The samples were tested for 300 h at 900 C in a gas stream designed to mimic the environment in the high temperature heat recovery unit (HTHRU). Three samples that showed least corrosion were exposed for an additional 100 h.

Gopala N. Krishnan; Ripudaman Malhotra; Esperanza Alvarez; Kai-Hung Lau; Angel Sanjurjo

2006-06-01T23:59:59.000Z

68

Wabash River Coal Gasification Repowering Project  

SciTech Connect

The Destec gasification process features an oxygen-blown, two stage entrained flow gasifier. PSI will procure coal for the Project consistent with the design specification ranges of Destec's coal gasification facility. Destec's plant will be designed to accept coal with a maximum sulfur content of 5.9% (dry basis) and a minimum energy content of 13,5000 BTU/pound (moisture and ash free basis). PSI and Destec will test at least two other coals for significant periods during the demonstration period. In the Destec process, coal is ground with water to form a slurry. It is then pumped into a gasification vessel where oxygen is added to form a hot raw gas through partial combustion. Most of the noncarbon material in the coal melts and flows out the bottom of the vessel forming slag -- a black, glassy, non-leaching, sand-like material. Particulates, sulfur and other impurities are removed from the gas before combustion to make it acceptable fuel for the gas turbine. The synthetic fuel gas (syngas) is piped to a General Electric MS 7001F high temperature combustion turbine generator. A heat recovery steam generator recovers gas turbine exhaust heat to produce high pressure steam. This steam and the steam generated in the gasification process supply an existing steam turbine-generator. The plant will be designed to outperform air emission standards established by the Clean Air Act Amendments for the year 2000.

Amick, P.; Mann, G.J.; Cook, J.J.; Fisackerly, R.; Spears, R.C.

1992-01-01T23:59:59.000Z

69

Wabash River Coal Gasification Repowering Project  

SciTech Connect

The Destec gasification process features an oxygen-blown, two stage entrained flow gasifier. PSI will procure coal for the Project consistent with the design specification ranges of Destec`s coal gasification facility. Destec`s plant will be designed to accept coal with a maximum sulfur content of 5.9% (dry basis) and a minimum energy content of 13,5000 BTU/pound (moisture and ash free basis). PSI and Destec will test at least two other coals for significant periods during the demonstration period. In the Destec process, coal is ground with water to form a slurry. It is then pumped into a gasification vessel where oxygen is added to form a hot raw gas through partial combustion. Most of the noncarbon material in the coal melts and flows out the bottom of the vessel forming slag -- a black, glassy, non-leaching, sand-like material. Particulates, sulfur and other impurities are removed from the gas before combustion to make it acceptable fuel for the gas turbine. The synthetic fuel gas (syngas) is piped to a General Electric MS 7001F high temperature combustion turbine generator. A heat recovery steam generator recovers gas turbine exhaust heat to produce high pressure steam. This steam and the steam generated in the gasification process supply an existing steam turbine-generator. The plant will be designed to outperform air emission standards established by the Clean Air Act Amendments for the year 2000.

Amick, P.; Mann, G.J.; Cook, J.J.; Fisackerly, R.; Spears, R.C.

1992-11-01T23:59:59.000Z

70

Pressure coal gasification experience in Czechoslovakia  

SciTech Connect

Czechoslovakia's large deposits of brown coal supply the country's three operating pressure gasification plants. The gas produced is suitable for further treatment to provide fuel for household and industrial consumers. Coal gasification is not new to the energy planners in Czechoslovakia. Since 1948, 56 gasifiers have been installed in the three pressure gasification plants currently in operation. The newest and biggest of these plants is at Vresova. The plant processes 5,000 tons of brown coal per day. The locally mined coal used for feed at the Vresova plant has a calorific value of 12 to 14 megajoules per kilogram (52 to 60 Btu's per pound). The gasifiers produce up to 13,000 cubic meters (459,000 cubic feet) per hour of crude gas per gasifier. Gasification technology has been under development in Czechoslovakia since 1945. The country has virtually no oil or natural gas reserves, a fact that emphasizes the importance of coal-based energy. Production of gas from coal in Czechoslovak gasifiers is based on gasification in the fixed bed of a gasifier.

Not Available

1981-03-01T23:59:59.000Z

71

Pneumatic solids feeder for coal gasification reactor  

DOE Patents (OSTI)

This invention is comprised of a pneumatic feeder system for a coal gasification reactor which includes one or more feeder tubes entering the reactor above the level of the particle bed inside the reactor. The tubes are inclined downward at their outer ends so that coal particles introduced into the tubes through an aperture at the top of the tubes slides downward away from the reactor and does not fall directly into the reactor. Pressurized gas introduced into, or resulting from ignition of recycled combustible gas in a chamber adjacent to the tube ends, propels the coal from the tube into the reactor volume and onto the particle bed. Leveling of the top of the bed is carried out by a bladed rotor mounted on the reactor stirring shaft. Coal is introduced into the tubes from containers above the tubes by means of rotary valves placed across supply conduits. This system avoids placement of feeder hardware in the plenum above the particle bed and keeps the coal from being excessively heated prior to reaching the particle bed.

Notestein, J.E.; Halow, J.S.

1991-12-31T23:59:59.000Z

72

Cyclic flow underground coal gasification process  

SciTech Connect

The present invention is directed to a method of in situ coal gasification for providing the product gas with an enriched concentration of carbon monoxide. The method is practiced by establishing a pair of combustion zones in spaced-apart boreholes within a subterranean coal bed and then cyclically terminating the combustion in the first of the two zones to establish a forward burn in the coal bed so that while an exothermic reaction is occurring in the second combustion zone to provide CO.sub.2 -laden product gas, an endothermic CO-forming reaction is occurring in the first combustion zone between the CO.sub.2 -laden gas percolating thereinto and the hot carbon in the wall defining the first combustion zone to increase the concentration of CO in the product gas. When the endothermic reaction slows to a selected activity the roles of the combustion zones are reversed by re-establishing an exothermic combustion reaction in the first zone and terminating the combustion in the second zone.

Bissett, Larry A. (Morgantown, WV)

1978-01-01T23:59:59.000Z

73

Underground coal gasification using oxygen and steam  

Science Conference Proceedings (OSTI)

In this paper, through model experiment of the underground coal gasification, the effects of pure oxygen gasification, oxygen-steam gasification, and moving-point gasification methods on the underground gasification process and gas quality were studied. Experiments showed that H{sub 2} and CO volume fraction in product gas during the pure oxygen gasification was 23.63-30.24% and 35.22-46.32%, respectively, with the gas heating value exceeding 11.00 MJ/m{sup 3}; under the oxygen-steam gasification, when the steam/oxygen ratio stood at 2: 1, gas compositions remained virtually stable and CO + H{sub 2} was basically between 61.66 and 71.29%. Moving-point gasification could effectively improve the changes in the cavity in the coal seams or the effects of roof inbreak on gas quality; the ratio of gas flowing quantity to oxygen supplying quantity was between 3.1:1 and 3.5:1 and took on the linear changes; on the basis of the test data, the reasons for gas quality changes under different gasification conditions were analyzed.

Yang, L.H.; Zhang, X.; Liu, S. [China University of Mining & Technology, Xuzhou (China)

2009-07-01T23:59:59.000Z

74

LLNL Capabilities in Underground Coal Gasification  

DOE Green Energy (OSTI)

Underground coal gasification (UCG) has received renewed interest as a potential technology for producing hydrogen at a competitive price particularly in Europe and China. The Lawrence Livermore National Laboratory (LLNL) played a leading role in this field and continues to do so. It conducted UCG field tests in the nineteen-seventies and -eighties resulting in a number of publications culminating in a UCG model published in 1989. LLNL successfully employed the ''Controlled Retraction Injection Point'' (CRIP) method in some of the Rocky Mountain field tests near Hanna, Wyoming. This method, shown schematically in Fig.1, uses a horizontally-drilled lined injection well where the lining can be penetrated at different locations for injection of the O{sub 2}/steam mixture. The cavity in the coal seam therefore gets longer as the injection point is retracted as well as wider due to reaction of the coal wall with the hot gases. Rubble generated from the collapsing wall is an important mechanism studied by Britten and Thorsness.

Friedmann, S J; Burton, E; Upadhye, R

2006-06-07T23:59:59.000Z

75

Investigation of plasma-aided bituminous coal gasification  

Science Conference Proceedings (OSTI)

This paper presents thermodynamic and kinetic modeling of plasma-aided bituminous coal gasification. Distributions of concentrations, temperatures, and velocities of the gasification products along the gasifier are calculated. Carbon gasification degree, specific power consumptions, and heat engineering characteristics of synthesis gas at the outlet of the gasifier are determined at plasma air/steam and oxygen/steam gasification of Powder River Basin bituminous coal. Numerical simulation showed that the plasma oxygen/steam gasification of coal is a more preferable process in comparison with the plasma air/steam coal gasification. On the numerical experiments, a plasma vortex fuel reformer is designed.

Matveev, I.B.; Messerle, V.E.; Ustimenko, A.B. [Applied Plasma Technology, Mclean, VA (United States)

2009-04-15T23:59:59.000Z

76

Study on the Nitric Compounds during Coal Gasification  

Science Conference Proceedings (OSTI)

This investigation involved the formation and evolution of NO? HCN and NH3 during coal gasification. Since HCN and NH3 are the precursors of NOX, their summation are considered to show the characteristics of the precursors in this paper. The experiments ... Keywords: gasification, NOX precursors, particle size, agent

Jun Xiang; Qingsen Zhao; Song Hu; Lushi Sun; Sheng Su; Kai Xu; Tengfei Lu; Gang Chen

2009-10-01T23:59:59.000Z

77

Diffusion Coatings for Corrosion-Resistant Components in Coal Gasification Systems  

Science Conference Proceedings (OSTI)

Heat-exchangers, particle filters, turbines, and other components in integrated coal gasification combined cycle system must withstand the highly sulfiding conditions of the high-temperature coal gas over an extended period of time. The performance of components degrades significantly with time unless expensive high alloy materials are used. Deposition of a suitable coating on a low-cost alloy may improve its resistance to such sulfidation attack, and decrease capital and operating costs. The alloys used in the gasifier service include austenitic and ferritic stainless steels, nickel-chromium-iron alloys, and expensive nickel-cobalt alloys. During this period, we analyzed several coated and exposed samples of 409 steel by scanning electron microscopy (SEM) and energy-dispersive X-ray (EDX). We report here on findings of this analysis: (1) A SS409 coupon that was coated with multilayered combined nitrides of Ti, Al, and Si showed adherent coatings on the surface; (2) A similarly coated coupon, after exposure to simulated coal gas at 900 C for 300 h, revealed that the coating has cracked during the exposure; (3) An SS409 coupon that was coated with nitrides of Ti and Si with a barrier layer of tungsten in between to improve the adhesion of the coating and to prevent outward diffusion of iron to the surface. (4) A porous coupon was coated with nitrides of Ti and Al and examination of the coupon revealed deposition of Ti at the interior surfaces. A similarly prepared coupon was exposed to simulated coal gas at 370 C for 300 h, and it showed no corrosion.

Gopala N. Krishnan; Ripudaman Malhotra; Esperanza Alvarez; Kai-Hung Lau; Jordi Perez-Mariano; Angel Sanjurjo

2006-06-30T23:59:59.000Z

78

Diffusion Coatings for Corrosion-Resistant Components in Coal Gasification Systems  

SciTech Connect

Heat-exchangers, particle filters, turbines, and other components in integrated coal gasification combined cycle system must withstand the highly sulfiding conditions of the hightemperature coal gas over an extended period of time. The performance of components degrades significantly with time unless expensive high alloy materials are used. Deposition of a suitable coating on a low-cost alloy may improve its resistance to such sulfidation attack, and decrease capital and operating costs. The alloys used in the gasifier service include austenitic and ferritic stainless steels, nickel-chromium-iron alloys, and expensive nickel-cobalt alloys. During this period, we analyzed several 409 low alloy steel samples after coating them in our fluidized bed reactor and also after exposing them to our corrosion test. We report the following findings: 1. A protective coating was deposited inside a porous 409 steel sample to protect it from sulfidation attack. The coating was based on a combination of Si diffusion layer, Nb interlayer and nitrides of titanium and silicon. 2. Analysis of solid coupons exposed to simulated coal gas at 900 C for 300 h showed that multilayer metal/ceramic coatings provide a better protection than ceramic coatings. 3. Deposition of several ceramic/metal multilayer coatings showed that coatings with niobium and tantalum interlayers have good adhesion. However, coatings with a tungsten interlayer suffered localized delaminating and coatings with Zr interlayers showed poor adhesion. 4. Analysis of solid coupons, coated with the above-mentioned multilayer films, after exposure to simulated coal gas at 900 C for 300 h showed that niobium is the best candidate for interlayer material.

Gopala N. Krishnan; Ripudaman Malhotra; Esperanza Alvarez; Kai-Hung Lau; Jordi Perez-Mariano; Angel Sanjurjo

2007-03-31T23:59:59.000Z

79

A review of the efficacy of silicon carbide hot-gas filters in coal gasification and pressurized fluidized bed combustion environments  

SciTech Connect

Reviews of relevant literature and interviews with individuals cognizant of the state of the art in ceramic filters for hot-gas cleaning were conducted. Thermodynamic calculations of the stability of various ceramic phases were also made. Based on these calculations, reviews, and interviews, conclusions were reached regarding the use of silicon carbide-based ceramics at hot-gas filter media. Arguments are presented that provide the basis for the conclusion that high-purity silicon carbide is a viable material in the integrated coal gasification combined cycle (IGCC) and pressurized fluidized-bed combustion (PFBC) environments which were examined. Clay-bonded materials are, the authors concluded, suspect for these applications, their extensive use notwithstanding. Operations data reviewed focused primarily on clay-bonded filters, for which a great deal of experience exists. The authors used the clay-bonded filter experience as a point of reference for their review and analysis.

Judkins, R.R.; Stinton, D.P.; DeVan, J.H. [Oak Ridge National Lab., TN (United States). Metals and Ceramics Div.

1996-07-01T23:59:59.000Z

80

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

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81

Diffusion Coatings for Corrosion-Resistant Components in Coal Gasification Systems  

SciTech Connect

Heat-exchangers, particle filters, turbines, and other components in integrated coal gasification combined cycle system must withstand the highly sulfiding conditions of the high-temperature coal gas over an extended period of time. The performance of components degrades significantly with time unless expensive high alloy materials are used. Deposition of a suitable coating on a low-cost alloy may improve its resistance to such sulfidation attack, and decrease capital and operating costs. The alloys used in the gasifier service include austenitic and ferritic stainless steels, nickel-chromium-iron alloys, and expensive nickel-cobalt alloys. During this period we tested coated alloy coupons under conditions designed to mimic the conditions in the filter unit after the high-temperature heat recovery unit (HTHRU). The filter unit is another important area where corrosion has caused unscheduled downtime, and the remedy has been the use of sintered metal tubes made of expensive alloys such as inconel. The objective of our test was to determine if those coatings on 400-series steel that were not able to withstand the harsher conditions of the HTHRU, may be sufficiently resistant for use in the filter unit, at the reduced temperatures. Indeed, most of our coatings survived well; the exceptions were the coated porous samples of SS316. We continued making improvements to our coatings apparatus and the procedure began during the last quarter. As a result of these modifications, the coupons we are now producing are uniform. We describe the improved procedure for preparing diffusion coatings. Finally, because porous samples of steel in grades other than SS316 are not readily available, we also decided to procure SS409 powder and fabricate our own sintered porous coupons.

Gopala N. Krishnan; Ripudaman Malhotra; Esperanza Alvarez; Kai-Hung Lau; Angel Sanjurjo

2006-01-01T23:59:59.000Z

82

Potential of the heat pipe in coal gasification processes  

SciTech Connect

The declining production of natural gas in the United States has provided great impetus to the development of economcal methods of producing methane from coal. Coal gasification systems share in common a need for highly efficient heat transfer and energy recovery methods in order to maximize the coal-methane conversion efficiency. Characteristics of heat pipe heat transfer units that offer potential for increasing conversion efficiency and/or reducing production costs include: (1) complete physical separation of process streams, (2) capability of handling more than two process streams in a single unit, (3) heat removal at near-constant temperature, (4) high heat recovery efficiency, (5) low operating cost-with no requirement for auxiliary power, and (6) relative ease of cleaning. Design concepts incorporating heat pipes into indirect coal gasification units, methanators, and energy recovery units are presented and technological impediments that must be surmounted in the successful development of these units are discussed.

Ranken, W.A.

1976-01-01T23:59:59.000Z

83

Underground coal gasification: a brief review of current status  

SciTech Connect

Coal gasification is a promising option for the future use of coal. Similarly to gasification in industrial reactors, underground coal gasification (UCG) produces syngas, which can be used for power generation or for the production of liquid hydrocarbon fuels and other valuable chemical products. As compared with conventional mining and surface gasification, UCG promises lower capital/operating costs and also has other advantages, such as no human labor underground. In addition, UCG has the potential to be linked with carbon capture and sequestration. The increasing demand for energy, depletion of oil and gas resources, and threat of global climate change lead to growing interest in UCG throughout the world. In this article, we review the current status of this technology, focusing on recent developments in various countries.

Shafirovich, E.; Varma, A. [Purdue University, West Lafayette, IN (United States). School of Chemical Engineering

2009-09-15T23:59:59.000Z

84

Update on the Great Plains Coal Gasification Project  

SciTech Connect

The Great Plains Gasification Plant is the US's first commercial synthetic fuels project based on coal conversion. The ANG Coal Gasification Company is the administer of the Great Plains Coal Gasification Project for the United States Department of Energy. The Project is designed to convert 14 M TPD of North Dakota of lignite into 137.5 MM SCFD of pipeline quality synthetic natural gas (SNG). Located in Mercer County, North Dakota, the gasification plant, and an SNG pipeline. Some 12 years passed from the time the project was conceived unit it became a reality by producing SNG into the Northern Border pipeline in 1984 for use by millions of residential, commercial, and industrial consumers. In this paper, the basic processes utilized in the plant are presented. This is followed by a discussion of the start-up activities and schedule. Finally, some of the more interesting start-up problems are described.

Imler, D.L.

1985-12-01T23:59:59.000Z

85

Separating hydrogen from coal gasification gases with alumina membranes  

DOE Green Energy (OSTI)

Synthesis gas produced in coal gasification processes contains hydrogen, along with carbon monoxide, carbon dioxide, hydrogen sulfide, water, nitrogen, and other gases, depending on the particular gasification process. Development of membrane technology to separate the hydrogen from the raw gas at the high operating temperatures and pressures near exit gas conditions would improve the efficiency of the process. Tubular porous alumina membranes with mean pore radii ranging from about 9 to 22 {Angstrom} have been fabricated and characterized. Based on hydrostatic tests, the burst strength of the membranes ranged from 800 to 1600 psig, with a mean value of about 1300 psig. These membranes were evaluated for separating hydrogen and other gases. Tests of membrane permeabilities were made with helium, nitrogen, and carbon dioxide. Measurements were made at room temperature in the pressure range of 15 to 589 psi. Selected membranes were tested further with mixed gases simulating a coal gasification product gas. 5 refs., 7 figs.

Egan, B.Z. (Oak Ridge National Lab., TN (USA)); Fain, D.E.; Roettger, G.E.; White, D.E. (Oak Ridge K-25 Site, TN (USA))

1991-01-01T23:59:59.000Z

86

CAPITAL AND OPERATING COST OF HYDROGEN PRODUCTION FROM COAL GASIFICATION  

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

CAPITAL AND OPERATING COST OF HYDROGEN CAPITAL AND OPERATING COST OF HYDROGEN PRODUCTION FROM COAL GASIFICATION Final Report April 2003 Prepared for: The United States Department of Energy National Energy Technology Laboratory (NETL) under: Contract No. DE-AM26-99FT40465 between the NETL and Concurrent Technologies Corporation (CTC) Subcontract No. 990700362 between CTC and Parsons Infrastructure & Technology Group Inc. Task 50611 DOE Task Managers: James R. Longanbach Gary J. Stiegel Parsons Project Manager: Michael D. Rutkowski Principal Investigators: Thomas L. Buchanan Michael G. Klett Ronald L. Schoff PARSONS Capital and Operating Cost of Hydrogen Production from Coal Gasification Page i April 2003 TABLE OF CONTENTS Section Title Page List of Tables iii List of Figures iii

87

Exxon Catalytic Coal Gasification Process Predevelopment Program. Final project report  

SciTech Connect

This report summarizes the results of work conducted on Predevelopment Research for the Exxon Catalytic Coal Gasification Process. The eighteen-month effort (July 1976-December 1977) was a coordinated program which included operation of a continuous fluidized-bed gasifier, parallel bench-scale research, and engineering studies leading to the preparation of a commercial-scale plant study design and economics for producing SNG from Illinois coal.

Kalina, T.; Nahas, N.C.

1978-12-01T23:59:59.000Z

88

Thermogravimetric Study of Effect of Mineral Content and Maceral Composition on Illinois Coal Gasification.  

E-Print Network (OSTI)

??The effects of mineral and maceral composition on Illinois coal gasification were studied by thermogravimetric analysis and semi-batch reactor. Macerals were separated from coal samples.… (more)

Zhang, Quan

2013-01-01T23:59:59.000Z

89

Model-based estimation of adiabatic flame temperature during coal gasification.  

E-Print Network (OSTI)

??Coal gasification temperature distribution in the gasifier is one of the importantissues. High temperature may increase the risk of corrosion of the gasifier wall or… (more)

Sarigul, Ihsan Mert

2012-01-01T23:59:59.000Z

90

Mathematical modelling of underground coal gasification.  

E-Print Network (OSTI)

??Mathematical models were developed to understand cavity growth mechanisms, heat and mass transfer in combination with chemical reaction, and the factors which affect gas production… (more)

Perkins, Gregory Martin Parry

2005-01-01T23:59:59.000Z

91

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

92

Synthetic fuels: Status of the Great Plains coal gasification project  

Science Conference Proceedings (OSTI)

Sponsors of the Great Plains coal gasification project in North Dakota defaulted on a federal loan in the amount of $1.54 billion. The Department of Energy has obtained title to the Great Plains project and is evaluating proposals from investment banking-type companies to assist it in selling the plant and its assets. This fact sheet highlights recent legal action concerning gas purchase agreements and mortgage foreclosure; the status of the project's sponsors' outstanding liability; DOE's progress in evaluating its options; revenue, expense, production, and plant employment data; capital improvement projects; and plant maintenance issues.

Not Available

1987-01-01T23:59:59.000Z

93

Great Plains coal gasification project - historical overview and progress  

SciTech Connect

The first commercial scale coal gasification plant in the US is nearing completion in North Dakota. The plant shares the site and other facilities with the Basin Electric Power Station. The gasification plant will draw its power directly from the Basin substation and Basin will receive coal fines from the gasification plant. (Coal fines cannot be gasified in the Lurgi units.) Planning, loan guarantee commitments, scheduling of construction, labor relations, and current situation are all briefly discussed. A table of project statistics is included.

Deeths, W.R.

1984-01-01T23:59:59.000Z

94

Higgins coal gasification/repowering study, feasibility study for alternate fuels. Vol. 1. Executive summary  

SciTech Connect

Florida Power has completed a study to determine the feasibility of repowering 138 MW gross of oil-fired steam-generating capacity at its A.W. Higgins power station (Pinellas Co., Fla.) by utilizing coal-gasification combined-cycle (CGCC) technology. The repowering would add approximately 320 MW of gross electrical generation to the Higgins station through the use of combustion turbines and heat recovery equipment. This study provided Florida Power with the technical, environmental, and economic information necessary to determine the viability of using CGCC at the Higgins station. The plant would use BGC/Lurgi slagging gasifiers and the Selexol acid-gas removal system. Although this new technology represents an acceptable level of risk for the proposed project to be considered technically feasible, the capital-cost estimates were much higher than expected. Florida Power plans to continue further economic evaluations of this CGCC repowering option.

Not Available

1981-12-01T23:59:59.000Z

95

UTILIZATION OF LIGHTWEIGHT MATERIALS MADE FROM COAL GASIFICATION SLAGS  

Science Conference Proceedings (OSTI)

The objective of the project entitled ''Utilization of Lightweight Materials Made from Coal Gasification Slags'' was to demonstrate the technical and economic viability of manufacturing low-unit-weight products from coal gasification slags which can be used as substitutes for conventional lightweight and ultra-lightweight aggregates. In Phase I, the technology developed by Praxis to produce lightweight aggregates from slag (termed SLA) was applied to produce a large batch (10 tons) of expanded slag using pilot direct-fired rotary kilns and a fluidized bed calciner. The expanded products were characterized using basic characterization and application-oriented tests. Phase II involved the demonstration and evaluation of the use of expanded slag aggregates to produce a number of end-use applications including lightweight roof tiles, lightweight precast products (e.g., masonry blocks), structural concrete, insulating concrete, loose fill insulation, and as a substitute for expanded perlite and vermiculite in horticultural applications. Prototypes of these end-use applications were made and tested with the assistance of commercial manufacturers. Finally, the economics of expanded slag production was determined and compared with the alternative of slag disposal. Production of value-added products from SLA has a significant potential to enhance the overall gasification process economics, especially when the avoided costs of disposal are considered.

Vas Choudhry; Stephen Kwan; Steven R. Hadley

2001-07-01T23:59:59.000Z

96

Modeling of contaminant transport in underground coal gasification  

Science Conference Proceedings (OSTI)

In order to study and discuss the impact of contaminants produced from underground coal gasification on groundwater, a coupled seepage-thermodynamics-transport model for underground gasification was developed on the basis of mass and energy conservation and pollutant-transport mechanisms, the mathematical model was solved by the upstream weighted multisell balance method, and the model was calibrated and verified against the experimental site data. The experiment showed that because of the effects of temperature on the surrounding rock of the gasification panel the measured pore-water-pressure was higher than the simulated one; except for in the high temperature zone where the simulation errors of temperature, pore water pressure, and contaminant concentration were relatively high, the simulation values of the overall gasification panel were well fitted with the measured values. As the gasification experiment progressed, the influence range of temperature field expanded, the gradient of groundwater pressure decreased, and the migration velocity of pollutant increased. Eleven months and twenty months after the test, the differences between maximum and minimum water pressure were 2.4 and 1.8 MPa, respectively, and the migration velocities of contaminants were 0.24-0.38 m/d and 0.27-0.46 m/d, respectively. It was concluded that the numerical simulation of the transport process for pollutants from underground coal gasification was valid. 42 refs., 13 figs., 1 tab.

Lanhe Yang; Xing Zhang [China University of Mining and Technology, Xuzhou (China). College of Resources and Geosciences

2009-01-15T23:59:59.000Z

97

Process for fixed bed coal gasification  

SciTech Connect

The combustion of gas produced from the combination of coal pyrolysis and gasification involves combining a combustible gas coal and an oxidant in a pyrolysis chamber and heating the components to a temperature of at least 1600.degree. F. The products of coal pyrolysis are dispersed from the pyrolyzer directly into the high temperature gasification region of a pressure vessel. Steam and air needed for gasification are introduced in the pressure vessel and the materials exiting the pyrolyzer flow down through the pressure vessel by gravity with sufficient residence time to allow any carbon to form carbon monoxide. Gas produced from these reactions are then released from the pressure vessel and ash is disposed of.

Sadowski, Richard S. (Greenville, SC)

1992-01-01T23:59:59.000Z

98

The ENCOAL Mild Coal Gasification Project, A DOE Assessment  

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

71 71 The ENCOAL ® Mild Coal Gasification Project A DOE Assessment March 2002 U.S. Department of Energy National Energy Technology Laboratory P.O. Box 880, 3610 Collins Ferry Road Morgantown, WV 26507-0880 and P.O. Box 10940, 626 Cochrans Mill Road Pittsburgh, PA 15236-0940 website: www.netl.doe.gov 2 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

99

Proceedings of the ninth annual underground coal gasification symposium  

SciTech Connect

The Ninth Underground Coal Gasification Symposium was held August 7 to 10, 1983 at the Indian Lakes Resort and Conference Center in Bloomingdale, Illinois. Over one-hundred attendees from industry, academia, National Laboratories, State Government, and the US Government participated in the exchange of ideas, results and future research plans. Representatives from six countries including France, Belgium, United Kingdom, The Netherlands, West Germany, and Brazil also participated by presenting papers. Fifty papers were presented and discussed in four formal sessions and two informal poster sessions. The presentations described current and future field testing plans, interpretation of field test data, environmental research, laboratory studies, modeling, and economics. All papers were processed for inclusion in the Energy Data Base.

Wieber, P.R.; Martin, J.W.; Byrer, C.W. (eds.)

1983-12-01T23:59:59.000Z

100

Status of the Great Plains coal gasification project - Summer 1983  

SciTech Connect

Construction of the Great Plains coal gasification plant in North Dakota was 3 weeks behind schedule as of May 31, 1983, but cumulative project costs were less than originally estimated. A March 1983 analysis by Great Plains raised questions about the project's economic viability, which is closely linked to future energy prices. The estimated gas prices used in the analysis were lower than those used in January 1982 to justify construction. As a result, the project's investors are concerned about possible losses during the early years of operations. GAO's review shows, however, that Great Plains did not consider substantial tax benefits which may be available to the parent companies of the project's investors. If these benefits are considered, the project's economic viability could be more positive. Should the investors end their participation, some tax benefits previously obtained would have to be repaid.

Not Available

1983-09-20T23:59:59.000Z

Note: This page contains sample records for the topic "integrated coal-gasification combined" 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

Great Plains: status of the Great Plains coal gasification project  

SciTech Connect

Updated information is presented on the Great Plains coal gasification project in North Dakota following the default of a $1.54 billion federal loan by the project sponsors. This report includes updated information obtained through October 31, 1985, on the loan default, Great Plains loan and gas pricing formula, legal matters and agreements, the Department of Energy's options and actions, Great Plains operations, and socioeconomic issues. The new information highlights changes in the gas pricing calculations; the Department's action to pay off the defaulted loan; legal action concerning gas purchase agreements; the project sponsors' proposed settlement; September revenue, expense, and production data; coal lease payments; capital improvement projects; plant by-products; and the final results of a North Dakota task force study of the potential socioeconomic impact if the plant closes.

Not Available

1985-11-01T23:59:59.000Z

102

Status of the Great Plains coal gasification project  

SciTech Connect

Construction of the Great Plains coal gasification plant in North Dakota was 95 percent complete and only about 2 weeks behind schedule as of November 30, 1983. Cumulative project costs were less than originally estimated for this date. Due to a drop in forecasted energy prices, Great Plains, in September 1983, projected that plant operations could result in large after-tax losses and negative cash flows for the sponsors. Great Plains notified the Department of Energy that it was considering terminating its participation in the project in the absence of additional federal assistance. In this regard, additional assistance in the form of price guarantees for the project's synthetic natural gas are being considered by the US Synthetic Fuels Corporation.

Not Available

1984-03-22T23:59:59.000Z

103

Status of the Great Plains coal gasification project, August 1982  

SciTech Connect

Construction of the Great Plains coal gasification plant in Mercer County, North Dakota, is 4 to 6 weeks behind schedule, but no long-term impacts are anticipated. Cumulative project costs are lower than originally estimated. Overall, the management system established to oversee project construction appears comprehensive. However, some weaknesses exist in the computerized information system, which produces most project data. The Department of Energy complied with statutory requirements in awarding the Great Plains loan guarantee for an alternative fuel demonstration project and is actively working to fulfill its responsibilities as the project's overseer. However, the Department needs to audit the costs incurred by Great Plains to determine that funds are being used only for eligible project costs.

Not Available

1982-09-14T23:59:59.000Z

104

Process for control of pollutants generated during coal gasification  

DOE Patents (OSTI)

The present invention is directed to an improvement in the coal gasification process that effectively eliminates substantially all of the environmental pollutants contained in the producer gas. The raw producer gas is passed through a two-stage water scrubbing arrangement with the tars being condensed essentially water-free in the first stage and lower boiling condensables, including pollutant laden water, being removed in the second stage. The pollutant-laden water is introduced into an evaporator in which about 95 percent of the water is vaporized and introduced as steam into the gas producer. The condensed tars are combusted and the resulting products of combustion are admixed with the pollutant-containing water residue from the evaporator and introduced into the gas producer.

Frumerman, Robert (Pittsburgh, PA); Hooper, Harold M. (Sewickley, PA)

1979-01-01T23:59:59.000Z

105

Encoal mild coal gasification project: Final design modifications report  

Science Conference Proceedings (OSTI)

The design, construction and operation Phases of the Encoal Mild Coal Gasification Project have been completed. The plant, designed to process 1,000 ton/day of subbituminous Power River Basin (PRB) low-sulfur coal feed and to produce two environmentally friendly products, a solid fuel and a liquid fuel, has been operational for nearly five years. The solid product, Process Derived Fuel (PDF), is a stable, low-sulfur, high-Btu fuel similar in composition and handling properties to bituminous coal. The liquid product, Coal Derived Liquid (CDL), is a heavy, low-sulfur, liquid fuel similar in properties to heavy industrial fuel oil. Opportunities for upgrading the CDL to higher value chemicals and fuels have been identified. Significant quantities of both PDF and CDL have been delivered and successfully burned in utility and industrial boilers. A summary of the Project is given.

NONE

1997-07-01T23:59:59.000Z

106

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

107

DOE/NETL-2002/1164 Wabash River Coal Gasification Repowering...  

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

4 Wabash River Coal Gasification Repowering Project: A DOE Assessment January 2002 U.S. Department of Energy National Energy Technology Laboratory P.O. Box 880, 3610 Collins Ferry...

108

EA-1219: Hoe Creek Underground Coal Gasification Test Site Remediation, Campbell County, Wyoming  

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

This EA evaluates the environmental impacts for the proposed Hoe Creek Underground Coal Gasification Test Site Remediation that would be performed at the Hoe Creek site in Campbell County, Wyoming.

109

The ENCOAL Mild Coal Gasification Project, A DOE Assessment  

Science Conference Proceedings (OSTI)

This report is a post-project assessment of the ENCOAL{reg_sign} Mild Coal Gasification Project, which was selected under Round III of the U.S. Department of Energy (DOE) Clean Coal Technology (CCT) Demonstration Program. The CCT 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 commercial-scale facilities. The ENCOAL{reg_sign} Corporation, a wholly-owned subsidiary of Bluegrass Coal Development Company (formerly SMC Mining Company), which is a subsidiary of Ziegler Coal Holding Company, submitted an application to the DOE in August 1989, soliciting joint funding of the project in the third round of the CCT Program. The project was selected by DOE in December 1989, and the Cooperative Agreement (CA) was approved in September 1990. Construction, commissioning, and start-up of the ENCOAL{reg_sign} mild coal gasification facility was completed in June 1992. In October 1994, ENCOAL{reg_sign} was granted a two-year extension of the CA with the DOE, that carried through to September 17, 1996. ENCOAL{reg_sign} was then granted a six-month, no-cost extension through March 17, 1997. Overall, DOE provided 50 percent of the total project cost of $90,664,000. ENCOAL{reg_sign} operated the 1,000-ton-per-day mild gasification demonstration plant at Triton Coal Company's Buckskin Mine near Gillette, Wyoming, for over four years. The process, using Liquids From Coal (LFC{trademark}) technology originally developed by SMC Mining Company and SGI International, utilizes low-sulfur Powder River Basin (PRB) coal to produce two new fuels, Process-Derived Fuel (PDF{trademark}) and Coal-Derived Liquids (CDL{trademark}). The products, as alternative fuel sources, are capable of significantly lowering current sulfur emissions at industrial and utility boiler sites throughout the nation thus reducing pollutants causing acid rain. In support of this overall objective, the following goals were established for the ENCOAL{reg_sign} Project: Provide sufficient quantity of products for full-scale test burns; Develop data for the design of future commercial plants; Demonstrate plant and process performance; Provide capital and O&M cost data; and Support future LFC{trademark} technology licensing efforts. Each of these goals has been met and exceeded. The plant has been in operation for nearly 5 years, during which the LFC{trademark} process has been demonstrated and refined. Fuels were made, successfully burned, and a commercial-scale plant is now under contract for design and construction.

National Energy Technology Laboratory

2002-03-15T23:59:59.000Z

110

Green Manufacturing II  

Science Conference Proceedings (OSTI)

Oct 18, 2011 ... In an integrated coal gasification combined cycle power generation (IGCC) and an integrated coal gasification Fuel cell power generation ...

111

ENCOAL mild coal gasification project public design and construction report  

SciTech Connect

This Public Design Report describes the 1000 ton per day ENCOAL mild coal gasification demonstration plant now in operation at the Buckskin Mine near Gillette, Wyoming. The objective of the project is to demonstrate that the proprietary Liquids From Coal (LFC) technology can reliably and economically convert low Btu PRB coal into a superior, high-Btu solid fuel (PDF), and an environmentally attractive low-sulfur liquid fuel (CDL). The Project`s plans also call for the production of sufficient quantities of PDF and CDL to permit utility companies to carry out full scale burn tests. While some process as well as mechanical design was done in 1988, the continuous design effort was started in July 1990. Civil construction was started in October 1990; mechanical erection began in May 1991. Virtually all of the planned design work was completed by July 1991. Most major construction was complete by April 1992 followed by plant testing and commissioning. Plant operation began in late May 1992. This report covers both the detailed design and initial construction aspects of the Project.

NONE

1994-12-01T23:59:59.000Z

112

Fate of catechols in coal gasification condensate waters  

Science Conference Proceedings (OSTI)

Even after the wastewater has been subjected to rigorous cleaning, many chemicals still remain. In order to remove these compounds, they must be identified. Catechol is a compound which appears in the condensate water and, because its concentration changes, its fate is somewhat uncertain. In recent experiments modeling the condensate water conditions, catechol solutions were aerated in the presence of ammonia. Upon acidification of the solutions, a polymer precipitates. This polymer was compared to the black compound isolated from the condensate water by spectral and elemental analyses. The structures of the two polymers were reasonably similar. The kinetics of oxidation, as determined by the uptake of oxygen, indicates that the reaction was first order in catechol and oxygen. The rate was significantly enhanced by an increase in pH. Assuming that catechol is the only subunit of the polymers isolated from the different condensate waters, calculations would indicate that the initial catechol concentration varies from 440 to 1700 ppM. An attempt is being made to account for all of the carbon that appears in the water from the gasification process. Presently, only 60% to 70% of the carbon-containing products have been identified. Part of the remaining total organic carbon can be accounted for by the catechol polymer. Studying the fate of catechol in the coal gasification condensate water will help to develop an environmentally and financially feasible treatment of the wastewater. 4 refs.

Uhrich, K.E.

1986-02-01T23:59:59.000Z

113

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

114

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

115

Environmental Permitting of a Low-BTU Coal Gasification Facility  

E-Print Network (OSTI)

The high price of natural gas and fuel oil for steam/power generation has alerted industry's decision makers to potentially more economical ways to provide the needed energy. Low-Btu fuel gas produced from coal appears to be an attractive alternate that merits serious consideration since only relatively small modifications to the existing oil or gas burner system may be required, and boiler derating can be minimized. The environmental permitting and planning process for a low-Btu coal gasification facility needs to address those items that are not only unique to the gasification process itself, but also items generic to conventional firing of coal. This paper will discuss the environmental data necessary for permitting a low-Btu gasification facility located in the State of Louisiana. An actual case study for a 500,000 lb/hr natural gas-fired process steam plant being converted to low Btu gas will be presented. Typical air, water and solid waste effluents that must be considered will also be described.

Murawczyk, C.; Stewart, J. T.

1983-01-01T23:59:59.000Z

116

Coal properties and system operating parameters for underground coal gasification  

Science Conference Proceedings (OSTI)

Through the model experiment for underground coal gasification, the influence of the properties for gasification agent and gasification methods on underground coal gasifier performance were studied. The results showed that pulsating gasification, to some extent, could improve gas quality, whereas steam gasification led to the production of high heating value gas. Oxygen-enriched air and backflow gasification failed to improve the quality of the outlet gas remarkably, but they could heighten the temperature of the gasifier quickly. According to the experiment data, the longitudinal average gasification rate along the direction of the channel in the gasifying seams was 1.212 m/d, with transverse average gasification rate 0.069 m/d. Experiment indicated that, for the oxygen-enriched steam gasification, when the steam/oxygen ratio was 2:1, gas compositions remained stable, with H{sub 2} + CO content virtually standing between 60% and 70% and O{sub 2} content below 0.5%. The general regularities of the development of the temperature field within the underground gasifier and the reasons for the changes of gas quality were also analyzed. The 'autopneumatolysis' and methanization reaction existing in the underground gasification process were first proposed.

Yang, L. [China University of Mining & Technology, Xuzhou (China)

2008-07-01T23:59:59.000Z

117

Theoretical investigation of selected trace elements in coal gasification plants. Final report Mar 78-Nov 79  

SciTech Connect

The report gives results of a theoretical investigation of the disposition of five volatile trace elements (arsenic, boron, lead, selenium, and mercury) in SNG-producing coal gasification plants. Three coal gasification processes (dry-bottom Lurgi, Koppers-Totzek, and HYGAS) were investigated to examine the possible effects of gasifier operation conditions on the speciation of the volatile trace elements. Results of this investigation suggest that none of the trace elements considered in this study will be present in the product SNG from a coal gasification plant, but will be removed from the fuel gas by various unit operations. Results also suggest that speciation of these volatile trace elements is not significantly affected by gasifier conditions.

Hill, A.H.; Anderson, G.L.; Fleming, D.K.

1983-08-01T23:59:59.000Z

118

Method and apparatus for the selective separation of gaseous coal gasification products by pressure swing adsorption  

DOE Patents (OSTI)

Bulk separation of the gaseous components of multi-component gases provided by the gasification of coal including hydrogen, carbon monoxide, methane, and acid gases (carbon dioxide plus hydrogen sulfide) are selectively adsorbed by a pressure swing adsorption technique using activated carbon zeolite or a combination thereof as the adsorbent. By charging a column containing the adsorbent with a gas mixture and pressurizing the column to a pressure sufficient to cause the adsorption of the gases and then reducing the partial pressure of the contents of the column, the gases are selectively and sequentially desorbed. Hydrogen, the least absorbable gas of the gaseous mixture, is the first gas to be desorbed and is removed from the column in a co-current direction followed by the carbon monoxide, hydrogen and methane. With the pressure in the column reduced to about atmospheric pressure the column is evacuated in a countercurrent direction to remove the acid gases from the column. The present invention is particularly advantageous as a producer of high purity hydrogen from gaseous products of coal gasification and as an acid gas scrubber. 2 figs., 2 tabs.

Ghate, M.R.; Yang, R.T.

1985-10-03T23:59:59.000Z

119

Method and apparatus for the selective separation of gaseous coal gasification products by pressure swing adsorption  

DOE Patents (OSTI)

Bulk separation of the gaseous components of multi-component gases provided by the gasification of coal including hydrogen, carbon monoxide, methane, and acid gases (carbon dioxide plus hydrogen sulfide) are selectively adsorbed by a pressure swing adsorption technique using activated carbon, zeolite or a combination thereof as the adsorbent. By charging a column containing the adsorbent with a gas mixture and pressurizing the column to a pressure sufficient to cause the adsorption of the gases and then reducing the partial pressure of the contents of the column, the gases are selectively and sequentially desorbed. Hydrogen, the least absorbable gas of the gaseous mixture, is the first gas to be desorbed and is removed from the column in a co-current direction followed by the carbon monoxide, hydrogen and methane. With the pressure in the column reduced to about atmospheric pressure the column is evacuated in a countercurrent direction to remove the acid gases from the column. The present invention is particularly advantageous as a producer of high parity hydrogen from gaseous products of coal gasification and as an acid gas scrubber.

Ghate, Madhav R. (Morgantown, WV); Yang, Ralph T. (Williamsville, NY)

1987-01-01T23:59:59.000Z

120

The suitability of coal gasification in India's energy sector  

E-Print Network (OSTI)

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

Simpson, Lori Allison

2006-01-01T23:59:59.000Z

Note: This page contains sample records for the topic "integrated coal-gasification combined" 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

Carbon formation and metal dusting in advanced coal gasification processes  

SciTech Connect

The product gases generated by coal gasification systems contain high concentrations of CO and, characteristically, have relatively high carbon activities. Accordingly, carbon deposition and metal dusting can potentially degrade the operation of such gasifier systems. Therefore, the product gas compositions of eight representative gasifier systems were examined with respect to the carbon activity of the gases at temperatures ranging from 480 to 1,090 C. Phase stability calculations indicated that Fe{sub 3}C is stable only under very limited thermodynamic conditions and with certain kinetic assumptions and that FeO and Fe{sub 0.877}S tend to form instead of the carbide. As formation of Fe{sub 3}C is a necessary step in the metal dusting of steels, there are numerous gasifier environments where this type of carbon-related degradation will not occur, particularly under conditions associated with higher oxygen and sulfur activities. These calculations also indicated that the removal of H{sub 2}S by a hot-gas cleanup system may have less effect on the formation of Fe{sub 3}C in air-blown gasifier environments, where the iron oxide phase can exist and is unaffected by the removal of sulfur, than in oxygen-blown systems, where iron sulfide provides the only potential barrier to Fe{sub 3}C formation. Use of carbon- and/or low-alloy steels dictates that the process gas composition be such that Fe{sub 3}C cannot form if the potential for metal dusting is to be eliminated. Alternatively, process modifications could include the reintroduction of hydrogen sulfide, cooling the gas to perhaps as low as 400 C and/or steam injection. If higher-alloy steels are used, a hydrogen sulfide-free gas may be processed without concern about carbon deposition and metal dusting.

DeVan, J.H.; Tortorelli, P.F.; Judkins, R.R.; Wright, I.G.

1997-02-01T23:59:59.000Z

122

Thermal-Hydrological Sensitivity Analysis of Underground Coal Gasification  

DOE Green Energy (OSTI)

This paper presents recent work from an ongoing project at Lawrence Livermore National Laboratory (LLNL) to develop a set of predictive tools for cavity/combustion-zone growth and to gain quantitative understanding of the processes and conditions (natural and engineered) affecting underground coal gasification (UCG). We discuss the application of coupled thermal-hydrologic simulation capabilities required for predicting UCG cavity growth, as well as for predicting potential environmental consequences of UCG operations. Simulation of UCG cavity evolution involves coupled thermal-hydrological-chemical-mechanical (THCM) processes in the host coal and adjoining rockmass (cap and bedrock). To represent these processes, the NUFT (Nonisothermal Unsaturated-saturated Flow and Transport) code is being customized to address the influence of coal combustion on the heating of the host coal and adjoining rock mass, and the resulting thermal-hydrological response in the host coal/rock. As described in a companion paper (Morris et al. 2009), the ability to model the influence of mechanical processes (spallation and cavity collapse) on UCG cavity evolution is being developed at LLNL with the use of the LDEC (Livermore Distinct Element Code) code. A methodology is also being developed (Morris et al. 2009) to interface the results of the NUFT and LDEC codes to simulate the interaction of mechanical and thermal-hydrological behavior in the host coal/rock, which influences UCG cavity growth. Conditions in the UCG cavity and combustion zone are strongly influenced by water influx, which is controlled by permeability of the host coal/rock and the difference between hydrostatic and cavity pressure. In this paper, we focus on thermal-hydrological processes, examining the relationship between combustion-driven heat generation, convective and conductive heat flow, and water influx, and examine how the thermal and hydrologic properties of the host coal/rock influence those relationships. Specifically, we conducted a parameter sensitivity analysis of the influence of thermal and hydrological properties of the host coal, caprock, and bedrock on cavity temperature and steam production.

Buscheck, T A; Hao, Y; Morris, J P; Burton, E A

2009-10-05T23:59:59.000Z

123

Opening New Avenues for High-Efficiency, Low-Emission Coal Gasification |  

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

Opening New Avenues for High-Efficiency, Low-Emission Coal Opening New Avenues for High-Efficiency, Low-Emission Coal Gasification Opening New Avenues for High-Efficiency, Low-Emission Coal Gasification April 10, 2012 - 1:00pm Addthis A rendering of the Pratt & Whitney Rocketdyne high pressure, dry-solids feed pump. A rendering of the Pratt & Whitney Rocketdyne high pressure, dry-solids feed pump. Washington, DC - Gasification. It's a versatile technology that uses coal to produce power, chemicals, and fuels. Inherently low in air emissions, solid byproducts, and wastewater, commercial gasification plants have proven capable of exceeding the most stringent regulations for air- and solids-emissions. However, capital and operational costs have prohibited the widespread adoption of gasification, especially for power

124

Steady-state model for estimating gas production from underground coal gasification  

Science Conference Proceedings (OSTI)

A pseudo-one-dimensional channel model has been developed to estimate gas production from underground coal gasification. The model incorporates a zero-dimensional steady-state cavity growth submodel and models mass transfer from the bulk gas to the coal wall using a correlation for natural convection. Simulations with the model reveal that the gas calorific value is sensitive to coal reactivity and the exposed reactive surface area per unit volume in the channel. A comparison of model results with several small-scale field trials conducted at Centralia in the U.S.A. show that the model can make good predictions of the gas production and composition under a range of different operating conditions, including operation with air and steam/oxygen mixtures. Further work is required to determine whether the model formulation is also suitable for simulating large-scale underground coal gasification field trials.

Greg Perkins; Veena Sahajwalla [University of New South Wales, Sydney, NSW (Australia). School of Materials Science and Engineering

2008-11-15T23:59:59.000Z

125

DIFFUSION COATINGS FOR CORROSION RESISTANT COMPONENTS IN COAL GASIFICATION SYSTEMS  

SciTech Connect

Advanced electric power generation systems use a coal gasifier to convert coal to a gas rich in fuels such as H{sub 2} and CO. The gas stream contains impurities such as H{sub 2}S and HCl, which attack metal components of the coal gas train, causing plant downtime and increasing the cost of power generation. Corrosion-resistant coatings would improve plant availability and decrease maintenance costs, thus allowing the environmentally superior integrated gasification combined cycle plants to be more competitive with standard power-generation technologies. A startup meeting was held at the National Energy Technology Center, Pittsburgh, PA site on July 28, 2003. SRI staff described the technical approach of the project.

Gopala N. Krishnan

2004-05-01T23:59:59.000Z

126

Coal gasification for the coproduction of electricity and fertilizer  

SciTech Connect

TVA is proposing to develop and commercially demonstrate the coproduction of electricity and fertilizer (urea) using integrated gasification/combined cycle (IGCC) technology. The coal-based coproduction demonstration project will show that the coproduction process can economically and environmentally enhance the production of both electric power and urea. As conceptualized, the proposed coproduction demonstration project facility would be designed for a nominal electrical capacity of about 250 megawatts (MW), Table I. During normal operation, the facility would produce about 150 MW of base-load electrical power and 1,000 tons per day of urea. Sulfur from the coal would be recovered as elemental sulfur. During peak power demand, the fertilizer capacity could be reduced or bypassed and the full 250 MW could be made available. This scheme would allow continuous operation of the gasifier at 100% of its rated capacity which would reduce the annual revenue requirements for power generation by permitting the production of fertilizer. As TVA's vision of this proposal matures (i.e., as consideration is given to alternative schemes, as TVA reviews its power demands, and as more detailed engineering estimates are developed), the nature and scope of cyclic-operation may be altered.

Kelly, D.A.; Nichols, D.E.; Faucett, H.L.

1992-01-01T23:59:59.000Z

127

Coal gasification for the coproduction of electricity and fertilizer  

SciTech Connect

TVA is proposing to develop and commercially demonstrate the coproduction of electricity and fertilizer (urea) using integrated gasification/combined cycle (IGCC) technology. The coal-based coproduction demonstration project will show that the coproduction process can economically and environmentally enhance the production of both electric power and urea. As conceptualized, the proposed coproduction demonstration project facility would be designed for a nominal electrical capacity of about 250 megawatts (MW), Table I. During normal operation, the facility would produce about 150 MW of base-load electrical power and 1,000 tons per day of urea. Sulfur from the coal would be recovered as elemental sulfur. During peak power demand, the fertilizer capacity could be reduced or bypassed and the full 250 MW could be made available. This scheme would allow continuous operation of the gasifier at 100% of its rated capacity which would reduce the annual revenue requirements for power generation by permitting the production of fertilizer. As TVA`s vision of this proposal matures (i.e., as consideration is given to alternative schemes, as TVA reviews its power demands, and as more detailed engineering estimates are developed), the nature and scope of cyclic-operation may be altered.

Kelly, D.A.; Nichols, D.E.; Faucett, H.L.

1992-12-01T23:59:59.000Z

128

Storing syngas lowers the carbon price for profitable coal gasification  

SciTech Connect

Integrated gasification combined cycle (IGCC) electric power generation systems with carbon capture and sequestration have desirable environmental qualities but are not profitable when the carbon dioxide price is less than approximately $50 per metric ton. We examine whether an IGCC facility that operates its gasifier continuously but stores the syngas and produces electricity only when daily prices are high may be profitable at significantly lower CO{sub 2} prices. Using a probabilistic analysis, we have calculated the plant-level return on investment (ROI) and the value of syngas storage for IGCC facilities located in the U.S. Midwest using a range of storage configurations. Adding a second turbine to use the stored syngas to generate electricity at peak hours and implementing 12 h of above-ground high-pressure syngas storage significantly increases the ROI and net present value. Storage lowers the carbon price at which IGCC enters the U.S. generation mix by approximately 25%. 36 refs., 7 figs., 1 tab.

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

2007-12-15T23:59:59.000Z

129

Sulfur emissions reduction at the Great Plains coal gasification facility: Technical and economic evaluations  

SciTech Connect

This report provides an in-depth technical and economic review of over 40 sulfur control technologies that were considered for use at the Great Plains coal gasification facility in Beulah, North Dakota. The review was based on the production of substitute natural gas at rates of 152.5 {times} 10{sup 6} and 160 {times} 10{sup 6} scf/d from lignite containing 1.7% sulfur. The factors considered in evaluating each technology included the reduction of SO{sub 2} emissions, capital and operating costs, incremental cost per unit of produced gas, cost-effectiveness, and probability of success. 21 figs., 37 tabs.

Doctor, R.D.; Wilzbach, K.E. (Argonne National Lab., IL (USA). Energy Systems Div.); Joseph, T.W. (USDOE Chicago Operations Office, Argonne, IL (USA))

1990-01-01T23:59:59.000Z

130

Estimates of the value of carbon dioxide from the Great Plains Coal Gasification Plant  

Science Conference Proceedings (OSTI)

This report develops a framework and methodology for estimating the value of carbon dioxide produced by the Great Plains Coal Gasification Plant. The petroleum industry could use this CO/sub 2/ as a solvent for enhanced oil recovery. The value of CO/sub 2/ is found to be a function of the geological characteristics of the petroleum reservoirs being flooded, the cost of transporting the CO/sub 2/, and the presence or absence of competitors selling CO/sub 2/. Carbon dioxide demand curves for oil fields in Montana and North Dakota are developed for various economic conditions, and sensitivity analyses are performed. 22 refs., 4 figs., 21 tabs.

Wolsky, A.M.; Nelson, S.H.; Jankowski, D.J.

1985-07-28T23:59:59.000Z

131

Great Plains Coal Gasification Project. Quarterly technical progress report, second quarter 1986. [Lurgi process  

SciTech Connect

The operations of the Great Plains coal gasification plant are reported for the second quarter of 1986. The following areas are covered: (1) lignite coal production; (2) SNG production; (3) SNG gas quality; (4) by-products production and inventories; (5) on-stream factors; (6) raw material, product and by-product consumption and energy consumption for plant operations; (7) plant modifications - 1986 budget; (8) plant maintenance; (9) safety; (10) industrial hygiene; (11) medical services; (12) environmental executive summary; and (13) quality assurance/quality control activities. (AT)

Not Available

1986-07-31T23:59:59.000Z

132

Great Plains coal gasification project: Quarterly technical progress report, Third quarter 1986. [Lurgi process  

Science Conference Proceedings (OSTI)

Accomplishments for the third quarter of 1986 are presented for the Great Plains coal gasification plant. The following areas are discussed: (1) lignite coal production; (2) SNG production; (3) SNG gas quality; (4) by-products production and inventories; (5) onstream factors; (6) raw material, product and by-product consumption and energy consumption for plant operations; (7) plant modifications - 1986 budget; (8) plant maintenance; (9) safety; (10) industrial hygiene; (11) medical services; (12) environmental executive summary; and (13) quality assurance/quality control activities.

Not Available

1986-10-31T23:59:59.000Z

133

Mathematical Modeling of Coal Gasification Processes in a Well-Stirred Reactor: Effects of Devolatilization and Moisture Content  

E-Print Network (OSTI)

Mathematical Modeling of Coal Gasification Processes in a Well- Stirred Reactor: Effects in coal and biomass play an important role on the gasification performance of these fuels on the syngas composition. The coal conversion time is most sensitive to the heat transfer rates including both

Qiao, Li

134

The Physical and Chemical Properties of Fly Ash from Coal Gasification and Study on Its Recycling Utilization  

Science Conference Proceedings (OSTI)

Aiming at the difficulties in utilization of fly ash from coal gasification, the physical and chemical properties of fly ash were investigated. This research studied recycling utilization on using fly ash as one of cement raw materials for cement clinker. ... Keywords: fly ash, X-ray diffraction (XRD), Scanning Electron Microscope (SEM), recycling utilization

Guohua Qiu; Weiqiang Zeng; Zhenglun Shi; Mengxiang Fang; Zhongyang Luo

2010-12-01T23:59:59.000Z

135

Low/medium-Btu coal-gasification assessment program for specific sites of two New York utilities  

SciTech Connect

The scope of this study is to investigate the technical and economic aspects of coal gasification to supply low- or medium-Btu gas to the two power plant boilers selected for study. This includes the following major studies (and others described in the text): investigate coals from different regions of the country, select a coal based on its availability, mode of transportation and delivered cost to each power plant site; investigate the effects of burning low- and medium-Btu gas in the selected power plant boilers based on efficiency, rating and cost of modifications and make recommendations for each; and review the technical feasibility of converting the power plant boilers to coal-derived gas. The following two coal gasification processes have been used as the basis for this Study: the Combustion Engineering coal gasification process produces a low-Btu gas at approximately 100 Btu/scf at near atmospheric pressure; and the Texaco coal gasification process produces a medium-Btu gas at 292 Btu/scf at 800 psig. The engineering design and economics of both plants are described. Both plants meet the federal, state, and local environmental requirements for air quality, wastewater, liquid disposal, and ground level disposal of byproduct solids. All of the synthetic gas alternatives result in bus bar cost savings on a yearly basis within a few years of start-up because the cost of gas is assumed to escalate at a lower rate than that of fuel oil, approximately 4 to 5%.

Not Available

1980-12-01T23:59:59.000Z

136

Coal gasification  

Science Conference Proceedings (OSTI)

A standard series of two staged gas generators (GG) has been developed in the United States for producing gas with a combustion heat from 4,700 to 7,600 kilojoules per cubic meter from coal (U). The diameter of the gas generators is from 1.4 to 3.65 meters and the thermal capacity based on purified cold gas is from 12.5 to 89 million kilojoules per hour. Certain standard sized gas generators have undergone experimental industrial tests which showed that it is most expedient to feed the coal into the gas generators pneumatically. This reduces the dimensions of the charging device, makes it possible to use more common grades of structural steels and reduces the cost of the gas. A double valve reliably prevents ejections of the gasification product and promotes the best distribution of the coal in the gas generator. The gas generators may successfully operate on high moisture (up to 36 percent) brown coal. Blasting with oxygen enriched to 38 percent made it possible to produce a gas with a combustion heat of 9,350 kilojoules per cubic meter. This supports a combustion temperature of 1,700C.

Rainey, D.L.

1983-01-01T23:59:59.000Z

137

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

138

Extractors manual for Integrated Gasification Combined Cycle Data Base System: Test Data 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 TDDB and MPDB 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 TDDB 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.

1986-11-01T23:59:59.000Z

139

DOE/NETL-2002/1164 Wabash River Coal Gasification Repowering Project: A DOE Assessment  

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

4 4 Wabash River Coal Gasification Repowering Project: A DOE Assessment January 2002 U.S. Department of Energy National Energy Technology Laboratory P.O. Box 880, 3610 Collins Ferry Road Morgantown, WV 26507-0880 and P.O. Box 10940, 626 Cochrans Mill Road Pittsburgh, PA 15236-0940 website: www.netl.doe.gov 2 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

140

DOEIJEA-1219 ENVIRONMENTAL ASSESSMENT HOE CREEK UNDERGROUND COAL GASIFICATION TEST SITE REMEDIATION  

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

DOEIJEA-1219 DOEIJEA-1219 ENVIRONMENTAL ASSESSMENT HOE CREEK UNDERGROUND COAL GASIFICATION TEST SITE REMEDIATION CAMPBELL COUNTY, WYOMING October 1997 U.S. DEPARTMENT OF ENERGY FEDERAL ENERGY TECHNOLOGY CENTER 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 use- fulness of any information, apparatus, product, or process disclosed, or represents that its use would not infringe privately owned rights. Reference herein to any spe- cific commercial product, process. or service by trade name, trademark, manufac-

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141

Status of the Great Plains coal gasification project, May 31, 1984. [Mercer County, North Dakota  

SciTech Connect

The Great Plains coal gasification project in North Dakota was 99 percent complete and essentially on schedule on May 31, 1984. Cumulative project costs were $164 million less than originally estimated for this date, primarily due to reduced material, interest, and subcontractor costs. On the basis of reduced energy price forecasts, Great Plains in September 1983 projected large after-tax losses and negative cash flows from plant operations. To alleviate these losses, Great Plains applied to the US Synthetic Fuels Corporation for additional financial assistance. On April 26, 1984, the Corporation outlined its intentions to award Great Plains up to $790 million in assistance. As of August 10, 1984, the Corporation had not finalized the Great Plains assistance agreement.

Not Available

1984-09-18T23:59:59.000Z

142

Analysis of pipe failure at the Great Plains Coal Gasification Plant  

SciTech Connect

The rupture of a carbon steel elbow in the methanation area of the Great Plains Coal Gasification Plant resulted in a fire and plant shutdown. Failure studies consisted of an on-site inspection and an extensive laboratory examination that included light metallography, X-ray fluorescence, X-ray diffraction, chemical analyses, and electron spectroscopy for chemical analysis. It was concluded that operation of a heat exchanger under off-specification conditions contributed to higher than design temperatures, lower than design pressures, and higher than design concentrations of carbon dioxide and water in the exit line from a condensate separator. Together, these conditions produced high levels of carbonic acid and higher than design velocities resulting in severe corrosion of the carbon steel.

Keiser, J.R.; Mayotte, J.R. (Oak Ridge National Lab., TN (United States)); Dias, O.C. (Amoco Oil Co., Texas City, TX (United States))

1994-09-01T23:59:59.000Z

143

Using rotating biological contactors for the treatment of coal gasification wastewaters  

Science Conference Proceedings (OSTI)

The objective of this research was to determine the treatability of University of North Dakota Energy Research Centers (UNDERC's) and Great Plains' coal gasification wastewaters using a bench scale four stage rotating biological contactor (RBC). The treatability testing included an evaluation of organic removal rates in the first stage and the overall rates in the last three stages using the Stover-Kincannon model. Nitrification was evaluated at various loading rates. Stage 1 accounted for most of the removal of alcohols, fatty acids, phenol, and thiocyanate from both UNDERC stripped gas liquor (SGL) and for alcohols and fatty acid removal from the Great Plains (GP) SGL. The 2, 3 and 4 stages accomplished very little additional organic removal in either system. Biodegradable organic removals remained high in the first stage of the GP SGL test run despite anaerobic conditions in the first stage. 5 refs., 12 figs., 6 tabs.

Turner, C.D.; Wernberg, K.

1986-01-01T23:59:59.000Z

144

Great Plains Coal Gasification Project will make 17. 5 tons/day of methanol  

SciTech Connect

The Great Plains Coal Gasification Project will make 17.5 tons/day of methanol in addition to 125 million cu ft/day of pipeline-quality substitute natural gas (SNG), making the facility the first commercial producer of methanol-from-coal in the United States, according to the consortium building the $1.5 billion facility in Beulah, North Dakota. As originally conceived, the plant would have used 17 tons/day of purchased methanol to clean the raw-gas product stream of impurities, primarily sulfur. But based on the cost of transporting methanol to the plant site and storing it for use, the consortium decided it was more economical to produce its own methanol from lignite. The construction started in July 1980, and the facility is to come on stream in 1984.

Not Available

1980-11-17T23:59:59.000Z

145

Analysis of pipe failure for the Great Plains Coal Gasification Plant  

Science Conference Proceedings (OSTI)

The rupture of a carbon steel elbow in the methanation area of the Great Plains Coal Gasification Plant resulted in a fire and plant shutdown. The failure was investigated by personnel from Oak Ridge National Laboratory and ANG Associates, the plant operators. These studies consisted of an on-site inspection and extensive laboratory examination that included optical metallography, x-ray fluorescence, x-ray diffraction, chemical analyses, and electron spectroscopy for chemical analysis (ESCA). It was concluded that operation of a heat exchanger under off-specification conditions contributed to higher than design temperatures, lower than design pressures, and higher than design concentrations of carbon dioxide and water in the exit line from a condensate separator. Together, these conditions produced high levels of carbonic acid and higher than design velocities resulting in severe corrosion of the carbon steel. 9 refs., 7 figs., 2 tabs.

Keiser, J.R.; Mayotte, J.R. (Oak Ridge National Lab., TN (USA)); Dias, O.C. (Amoco Research Center, Naperville, IL (USA))

1990-01-01T23:59:59.000Z

146

Underground coal gasification: Its potential for long-term supply of sng. Occasional pub  

Science Conference Proceedings (OSTI)

The paper examines the viability of underground coal gasification (UCU) as a future source of substitute natural gas (SNG). The economics of commercial scale UCG technology at a western site is estimated and compared with aboveground gasification and also with an extrapolation of GRI's Baseline Projection for natural gas prices. Although much technical and economic uncertainty exists regarding UCG, the potential reserve base for unmineable coals is very large, about four times that of currently mineable coals. Assuming that only 10 percent of the 1.8 trillion tons of marginal U.S. coal resources may be amendable to UCG, this represents 1000 trillion cubic feet of potential SNG production. The UCG economics of the paper are based on a techno-economic study conducted by Williams Brothers Engineering Company; the cosponsors included GRI, Amoco Production Company, Hunt Oil Company, and Williams Brothers Engineering Company.

Hill, V.L.; Burnham, K.B.; Barone, S.P.; Rosenberg, J.I.; Ashby, A.B.

1984-02-01T23:59:59.000Z

147

High Temperature Electrochemical Polishing of H(2)S from Coal Gasification Process Streams.  

DOE Green Energy (OSTI)

An advanced process for the separation of hydrogen sulfide from coal gasification streams through an electrochemical membrane is being perfected. H{sub 2}S is removed from a synthetic gas stream, split into hydrogen, which enriches the exiting syngas, and sulfur, which is condensed downstream from an inert sweep gas stream. The process allows for continuous removal of H{sub 2}S without cooling the gas stream while allowing negligible pressure loss through the separator. Moreover, the process is economically attractive due to the elimination of the need for a Claus process for sulfur recovery. To this extent the project presents a novel concept for improving utilization of coal for more efficient power generation.

Winnick, J.

1997-12-31T23:59:59.000Z

148

Underground coal gasification field experiment in the high-dipping coal seams  

Science Conference Proceedings (OSTI)

In this article the experimental conditions and process of the underground gasification in the Woniushan Mine, Xuzhou, Jiangsu Province are introduced, and the experimental results are analyzed. By adopting the new method of long-channel, big-section, and two-stage underground coal gasification, the daily gas production reaches about 36,000 m{sup 3}, with the maximum output of 103,700 m{sup 3}. The daily average heating value of air gas is 5.04 MJ/m{sup 3}, with 13.57 MJ/m{sup 3} for water gas. In combustible compositions of water gas, H{sub 2} contents stand at over 50%, with both CO and CH{sub 4} contents over 6%. Experimental results show that the counter gasification can form new temperature conditions and increase the gasification efficiency of coal seams.

Yang, L.H.; Liu, S.Q.; Yu, L.; Zhang, W. [China University of Mining & Technology, Xuzhou (China). College of Resources & Geoscience

2009-07-01T23:59:59.000Z

149

Analysis of industrial markets for low and medium Btu coal gasification. [Forecasting  

SciTech Connect

Low- and medium-Btu gases (LBG and MBG) can be produced from coal with a variety of 13 existing and 25 emerging processes. Historical experience and previous studies indicate a large potential market for LBG and MBG coal gasification in the manufacturing industries for fuel and feedstocks. However, present use in the US is limited, and industry has not been making substantial moves to invest in the technology. Near-term (1979-1985) market activity for LBG and MBG is highly uncertain and is complicated by a myriad of pressures on industry for energy-related investments. To assist in planning its program to accelerate the commercialization of LBG and MBG, the Department of Energy (DOE) contracted with Booz, Allen and Hamilton to characterize and forecast the 1985 industrial market for LBG and MBG coal gasification. The study draws five major conclusions: (1) There is a large technically feasible market potential in industry for commercially available equipment - exceeding 3 quadrillion Btu per year. (2) Early adopters will be principally steel, chemical, and brick companies in described areas. (3) With no additional Federal initiatives, industry commitments to LBG and MBG will increase only moderately. (4) The major barriers to further market penetration are lack of economic advantage, absence of significant operating experience in the US, uncertainty on government environmental policy, and limited credible engineering data for retrofitting industrial plants. (5) Within the context of generally accepted energy supply and price forecasts, selected government action can be a principal factor in accelerating market penetration. Each major conclusion is discussed briefly and key implications for DOE planning are identified.

1979-07-30T23:59:59.000Z

150

Synthetic fuels. Status of the Great Plains Coal Gasification Project, August 1, 1985  

Science Conference Proceedings (OSTI)

In December 1984, the Great Plains Gasification Associates had essentially finished constructing the nation's first commercial-scale coal gasification plant. As of July 31, 1985, Great Plains had contributed about $537 million in equity to the project and had borrowed $1.54 billion against a federal load guarantee made available by the Department of Energy (DOE). Since 1984 the project has faced deteriorating financial projections in the wake of declining energy prices. This is GAO's eighth semiannual report on Great Plains and covers the project's progress from January through August 1, 1985. GAO's objectives were to report on (1) the status of Great Plains' attempt to obtain additional federal financial assistance and (2) the status of the project's operational startup activities as of August 1, 1985. The Department of Energy Act of 1978 requires GAO to report on the status of the loan guarantee. Even though the Synthetic Fuels Corporation approved price guarantees in principle for Great Plains, DOE announced, on July 30, 1985, that it would not agree to restructuring its guaranteed loan. DOE rejected the proposed agreement, saying that it would not assure long-term plant operation at a reasonable cost to the taxpayers. The Great Plains sponsors then terminated their participation in the project on August 1, 1985, and defaulted on the $1.54 billion DOE-guaranteed loan. DOE directed the project administrator, ANG Coal Gasification Company, to continue plant operations pending a DOE decision about the project's future. DOE is assessing options including operating, leasing, selling, shutting down, mothballing, and scrapping the plant.

Bowsher, C.A.

1985-12-01T23:59:59.000Z

151

Environmental assessment for the Hoe Creek underground, Coal Gasification Test Site Remediation, Campbell County, Wyoming  

SciTech Connect

The U.S. Department of Energy (DOE) has prepared this EA to assess environmental and human health Issues and to determine potential impacts associated with the proposed Hoe Creek Underground Coal Gasification Test Site Remediation that would be performed at the Hoe Creek site in Campbell County, Wyoming. The Hoe Creek site is located south-southwest of the town of Gillette, Wyoming, and encompasses 71 acres of public land under the stewardship of the Bureau of Land Management. The proposed action identified in the EA is for the DOE to perform air sparging with bioremediation at the Hoe Creek site to remove contaminants resulting from underground coal gasification (UCG) experiments performed there by the DOE in the late 1970s. The proposed action would involve drilling additional wells at two of the UCG test sites to apply oxygen or hydrogen peroxide to the subsurface to volatilize benzene dissolved in the groundwater and enhance bioremediation of non-aqueous phase liquids present in the subsurface. Other alternatives considered are site excavation to remove contaminants, continuation of the annual pump and treat actions that have been used at the site over the last ten years to limit contaminant migration, and the no action alternative. Issues examined in detail in the EA are air quality, geology, human health and safety, noise, soils, solid and hazardous waste, threatened and endangered species, vegetation, water resources, and wildlife. Details of mitigative measures that could be used to limit any detrimental effects resulting from the proposed action or any of the alternatives are discussed, and information on anticipated effects identified by other government agencies is provided.

1997-10-01T23:59:59.000Z

152

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

153

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

154

A review of the factors influencing the physicochemical characteristics of underground coal gasification  

Science Conference Proceedings (OSTI)

In this article, the physicochemical characteristics of the oxidation zone, the reduction zone, and the destructive distillation and dry zone in the process of underground coal gasification (UCG) were explained. The effect of such major factors as temperature, coal type, water-inrush or -intake rate, the quantity and quality of wind blasting, the thickness of coal seams, operational pressure, the length, and the section of gasification gallery on the quality of the underground gas and their interrelationship were discussed. Research showed that the temperature conditions determined the underground gas compositions; the appropriate water-inrush or -intake rate was conducive to the improvement in gas heat value; the properties of the gasification agent had an obvious effect on the compositions and heat value of the product gas. Under the cyclically changing pressure, heat losses decreased by 60%, with the heat efficiency and gasification efficiency being 1.4 times and 2 times those of constant pressure, respectively. The test research further proved that the underground gasifier with a long channel and a big cross-section, to a large extent, improved the combustion-gasification conditions.

Yang, L.H. [China University of Mining and Technology, Jiangsu (China)

2008-07-01T23:59:59.000Z

155

Status of the Great Plains Coal Gasification Project, December 31, 1984  

Science Conference Proceedings (OSTI)

The Department of Energy (DOE)-sponsored construction of the Great Plains coal gasification project - designed to produce synthetic natural gas from coal in North Dakota - was completed in December 1984 on schedule. However, technical problems prevented Great Plains from meeting the inservice (commercial operation) target date of December 1, 1984. DOE believes the in-service date could occur in June 1985. Faced with deteriorating financial projections in the wake of declining energy prices, Great Plains applied to the US Synthetic Fuels Corporation (SFC) for additional assistance. In April 1984 SFC tentatively agreed to provide Great Plains up to $790 million in price guarantee assistance. In return, the Great Plains partners would contribute more equity, and Great Plains would repay the DOE-guaranteed loan faster and make profit-sharing payments to SFC. However, since SFC's tentative agreement for price guarantees, several events that could affect the project's financial outlook have occurred. For example, SFC and DOE have revised their energy price forecasts downward. In addition, Great Plains and SFC are negotiating a final agreement that could change some conditions of the tentative agreement.

Bowsher, C.A.

1985-05-28T23:59:59.000Z

156

Impact of the Great Plains coal gasification decision on a coal gas industry  

SciTech Connect

In approving the special tariff and financing features of the Great Plains coal-gasification project, the Federal Energy Regulatory Commission took the first major federal action toward encouraging the construction of a commercial-sized synthetic-fuels facility, asserts the law firm of Morley, Caskin and Generelly. Owned by Great Plains Gasification Associates - a partnership of five pipeline companies - the commercial-sized plant qualifies for FERC approval under the commission's RD and D regulations. The special financing terms for the project will require customers of existing natural gas companies to bear the costs incurred by the project regardless of its success in operation or the amount of gas produced for the customer's utilization. This RD and D rate treatment serves to mitigate market forces and thus operates as an effective subsidy for the pipeline industry. If this or a similar regulatory subsidy is extended to other coal-gas projects, the pipeline industry could take the lead in the nation's synfuels program.

Zipp, J.F.

1980-05-08T23:59:59.000Z

157

Refractory Materials based on Magnesia-Alumina Spinel for Improved Performance in Coal Gasification Environments  

SciTech Connect

As part of a larger project to develop novel refractory systems and techniques to reduce energy consumption of refractory lined vessels, a team composed of Oak Ridge National Laboratory, refractory manufacturer Minteq International, Inc., and academic partner Missouri University of Science and Technology have developed new refractory materials and coating systems specifically for application in coal gasification environments. Materials were developed under this U.S. DOE funded project to address the need for innovative refractory compositions by developing MgO-Al2O3 spinel gunnable refractory compositions utilizing new aggregate materials, bond systems, protective coatings, and phase formation techniques. Work was conducted to develop and deploy these new materials and to develop and apply low cost coatings using a colloidal approach for protection against attack of the refractory brick by the serviced environment. Additionally, a light-weight back-up refractory system was developed to help offset the high thermal conductivity inherent in spinel materials. This paper discusses the efforts involved in the development of these materials, along with the laboratory testing and evaluation of these materials leading to relevant results achieved toward the reduction of chemical reactions and mechanical degradation by the service environment though compositional and processing modifications.

Hemrick, James Gordon [ORNL; Armstrong, Beth L [ORNL; Rodrigues-Schroer, Angela [Minteq International, Inc.; Colavito, [Minteq International, Inc.; Smith, Jeffrey D [ORNL; O'Hara, Kelley [University of Missouri, Rolla

2013-01-01T23:59:59.000Z

158

SPINEL-BASED REFRACTORIES FOR IMPROVED PERFORMANCE IN COAL GASIFICATION ENVIRONMENTS  

Science Conference Proceedings (OSTI)

Oak Ridge National Laboratory, in collaboration with refractory manufacturer Minteq International, Inc., academic partner Missouri University of Science and Technology and refractory end users have developed novel refractory systems and techniques to reduce energy consumption of refractory lined vessels. The objective of this U.S. DOE funded project was to address the need for innovative refractory compositions by developing MgO-Al 2O3 spinel gunnable refractory compositions utilizing new aggregate materials, bond systems, protective coatings, and phase formation techniques. Materials have been developed specifically for coal gasification environments and work has been performed to develop and apply low cost coatings using a colloidal approach for protection against attack of the refractory brick by the service environment and to develop a light-weight back-up refractory system to help offset the high thermal conductivity inherent in spinel materials. This paper discusses the systematic development of these materials, laboratory testing and evaluation of these materials, and relevant results achieved toward the reduction of chemical reactions and mechanical degradation by the service environment though compositional and processing modifications.

Hemrick, James Gordon [ORNL; Armstrong, Beth L [ORNL; Rodrigues-Schroer, Angela [Minteq International, Inc.; Colavito, [Minteq International, Inc.; Smith, Jeffrey D [ORNL; O'Hara, Kelley [University of Missouri, Rolla

2013-01-01T23:59:59.000Z

159

Advanced coal-gasification technical analyses. Project summary. Final report, December 1982-September 1985  

SciTech Connect

This report summarizes the work performed by KRSI to support the GRI Fossil Fuels Gasification Program in identification and development of the most economical and technically feasible process(es) for production of SNG from coal. The work was performed under several tasks that fall under three topical categories: (1) Technology Review and Evaluations, (2) Coal Fines Disposal and (3) Technical/Economic Evaluations. The final task reports appear in the three appendices of the report. The Technology Review studies provide an overview of the coal gasification, shift/methanation, acid-gas removal, and sulfur-recovery technologies for use in coal-to-SNG plant design; Side-by-side comparisons of selected processes in each category provide background for process selection. The studies relating to Coal Fines Disposal allow comparison and guidance with regard to feedstock-management options when fixed-bed gasifiers are to be used. The first-pass designs and cost estimates prepared under Technical/Economic Evaluations compare and assess North Dakota lignite-to-SNG plants based on Lurgi, Westinghouse (now KRW) and Direct Methanation processes. A plant size vs. cost study provides an insight to selection of an economical plant size.

Cover, A.E.; Hubbard, D.A.; Jain, S.K.; Shah, K.V.

1986-01-01T23:59:59.000Z

160

Novel hydrogen separation device development for coal gasification system applications. Final report  

DOE Green Energy (OSTI)

This study was undertaken for the development of a novel Electrochemical Hydrogen Separator (EHS) technology for low-cost hydrogen separation from coal derived gases. Design and operating parameter testing was performed using subscale cells (25 cm{sup 2}). High H{sub 2} purity, >99% is one of the main features of the EHS. It was found that N{sub 2}, CO{sub 2} and CH{sub 4} behave as equivalent inerts; EHS performance is not affected by the balance of feed gas containing these components. This product purity level is not sacrificed by increased H{sub 2} recovery. CO, however, does adversely affect EHS performance and therefore feed stream pretreatment is recommended. Low levels of H{sub 2}S and NH{sub 3} were added to the feed gas stream and it was verified that these impurities did not affect EHS performance. Task 2 demonstrated the scale-up to full size multi-cell module operation while maintaining a stable energy requirement. A 10-cell full-size module (1050 cm{sup 2} cell active area) was operated for over 3,800 hours and gave a stable baseline performance. Several applications for the EHS were investigated. The most economically attractive systems incorporating an EHS contain low pressure, dilute hydrogen streams, such as coal gasification carbonate fuel cell systems, hydrogen plant purification and fluid catalytic cracker units. In addition, secondary hydrogen recovery from PSA or membrane tailstreams using an EHS may increase overall system efficiency.

Not Available

1993-08-01T23:59:59.000Z

Note: This page contains sample records for the topic "integrated coal-gasification combined" 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

Lawrence Livermore National Laboratory underground coal gasification data base. [US DOE-supported field tests; data  

SciTech Connect

The Department of Energy has sponsored a number of field projects to determine the feasibility of converting the nation's vast coal reserves into a clean efficient energy source via underground coal gasification (UCG). Due to these tests, a significant data base of process information has developed covering a range of coal seams (flat subbituminous, deep flat bituminous and steeply dipping subbituminous) and processing techniques. A summary of all DOE-sponsored tests to data is shown. The development of UCG on a commercial scale requires involvement from both the public and private sectors. However, without detailed process information, accurate assessments of the commercial viability of UCG cannot be determined. To help overcome this problem the DOE has directed the Lawrence Livermore National Laboratory (LLNL) to develop a UCG data base containing raw and reduced process data from all DOE-sponsored field tests. It is our intent to make the data base available upon request to interested parties, to help them assess the true potential of UCG.

Cena, R. J.; Thorsness, C. B.

1981-08-21T23:59:59.000Z

162

Modeling of the coal gasification processes in a hybrid plasma torch  

Science Conference Proceedings (OSTI)

The major advantages of plasma treatment systems are cost effectiveness and technical efficiency. A new efficient electrodeless 1-MW hybrid plasma torch for waste disposal and coal gasification is proposed. This product merges several solutions such as the known inductive-type plasma torch, innovative reverse-vortex (RV) reactor and the recently developed nonequilibrium plasma pilot and plasma chemical reactor. With the use of the computational-fluid-dynamics-computational method, preliminary 3-D calculations of heat exchange in a 1-MW plasma generator operating with direct vortex and RV have been conducted at the air flow rate of 100 g/s. For the investigated mode and designed parameters, reduction of the total wall heat transfer for the reverse scheme is about 65 kW, which corresponds to an increase of the plasma generator efficiency by approximately 6.5%. This new hybrid plasma torch operates as a multimode, high power plasma system with a wide range of plasma feedstock gases and turn down ratio, and offers convenient and simultaneous feeding of several additional reagents into the discharge zone.

Matveev, I.B.; Serbin, S.I. [Applied Plasma Technology, Mclean, VA (USA)

2007-12-15T23:59:59.000Z

163

Hanna, Wyoming underground coal gasification data base. Volume 2. The Hanna I field test  

SciTech Connect

This report is part of a seven-volume series on the Hanna, Wyoming, underground coal gasification field tests. Volume 1 is a summary of the project, and each of Volumes 2 through 6 describes a particular test. Volume 7 is a compilation of all the data for the tests in Volumes 2 through 6. Based on the recommendations of A.D. Little, Inc. in a 1971 report prepared for the US Bureau of Mines, the Hanna I test represented the first field test in reestablishing a field program by the US Bureau of Mines. The test was directed toward comparing results from a thick subbitiminous coal seam with those obtained during the field test series conducted at Gorgas, AL, in the 1940's and 1950's. Hanna I was conducted from March 1973 through February 1974. This report covers: (1) site selection and characteristics; (2) test objectives; (3) facility description; (4) pre-operation tests; (5) test operations summary; and (6) post-test activity. 9 refs., 10 figs., 4 tabs.

Bartke, T.C.; Fischer, D.D.; King, S.B.; Boyd, R.M.; Humphrey, A.E.

1985-08-01T23:59:59.000Z

164

Decision-analytic framework for portfolio selection: choosing among supplemental environmental research projects proposed for the Great Plains Coal Gasification Facility  

Science Conference Proceedings (OSTI)

This report describes the development and application of a hierarchical decision-analytic framework for selecting a portfolio of research and development projects. A US Department of Energy steering committee used the framework to develop a comprehensive and defensible $12 million Supplemental Environmental Program (SEP) for the Great Plains Coal Gasification Facility. This decision problem was characterized by: (1) five technical subcommittees that proposed detailed studies addressing different environmental and health issues; (2) many combinations of proposed studies that satisfied the $12 million budgetary constraint; (3) multiple objectives that required value tradeoffs at both the committee and subcommittee levels; and (4) uncertainties about research needs, data availability, and costs. The framework for determining funding (study) priorities used the principles of decision analysis to divide the overall SEP problem into a series of smaller subproblems tailored to the specific organizational structure of the steering committee and its five subcommittees. A dynamic optimization procedure was used to compare alternative funding strategies; the strategies were ranked on the basis of their expected utility, as calculated with a multiattribute utility function. Each subcommittee chairman was directly responsible for ranking the studies proposed by his subcommittee and, on the basis of that ranking, quantifying the degree to which the proposed research plan met objectives established for the entire SEP by the steering committee chairman. The approach is applicable to similar portfolio selection problems in both the public and private sectors.

Peerenboom, J.P.; Buehring, W.A.; Joseph, T.W.

1984-09-01T23:59:59.000Z

165

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

E-Print Network (OSTI)

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

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

2011-01-01T23:59:59.000Z

166

Evaluation of cooling tower and wastewater treatment operations at the Great Plains Coal Gasification Plant  

Science Conference Proceedings (OSTI)

The objective of this study was to provide a technical assessment of the Great Plains Coal Gasification Plant Wastewater Treatment System. This Scope of Work consisted of five primary tasks described as follows: Task 1 - Determine the quantity of hydantoins in the stripped gas liquor (SGL), their precursors, and the kinetics of their formation in condensed liquor for the Great Plains Gasification Associates (GPGA) gasification facility. The University of North Dakota Energy Research Center (UNDERC) has measured a high concentration of hydantoins in the gas liquor from their slagging gasifier. UNDERC has tested the use of SGL in a pilot cooling tower and they witnessed some adverse effects in the cooling tower and heat exchanger systems. Task 2 - Investigate the adverse Department of Energy (DOE) findings at UNDERC with regard to corrosion, foaming, biological and organic fouling, chemical attack on concrete and organic emissions resulting from the use of SGL in a pilot plant cooling tower. Task 3 - Validate the heat load on the cooling tower for both summer and winter operation and determine the adequacy of the surge pond to store the maximum predicted amount of excess water accumulated during winter operation. Task 4 - Assess potential fouling, foaming and organic carry-over problems associated with operability of the multiple-effect evaporator and develop recommendations on possible alternate use of evaporator condensate to alleviate possible problems in disposing of excess wastewater. Task 5 - Provide DOE with recommendations on the wastewater treatment backup design and test program already committed to by GPGA. This paper presents Fluor's findings regarding the five primary tasks. 12 refs., 4 figs., 15 tabs.

Lang, R.A.

1984-12-01T23:59:59.000Z

167

Zero-order trace element distribution model for the Great Plains Coal Gasification Plant: Topical report  

SciTech Connect

The Morgantown Energy Technology Center of the US DOE is developing a series for models of environmental systems. Both zero-order and detailed models are being developed. Detailed models are based on fundamental engineering principles and the use of detailed physical and chemical property data; reliance on empirical relationships and correlations is minimized. The key advantage of detailed models is their predictive capabilities and utility in performing valid comparative analyses. An important prerequisite to the development of detailed models in the availability of representative, long-term process and environmental data. These data are needed both to develop the models as well as to validate them. Zero-order models are less rigorous and have less predictive capability than detailed models since they are based on empirical estimates and simple correlations. However, they can be developed relatively quickly and are significantly less expensive to develop and use compared to detailed models. Zero-order models are useful in identifying potential environmental or control technology problems. As such, they can help direct future research and development efforts. They can provide useful information when comprehensive data are unavailable for detailed modeling, and can be used as a screening tool to identify process alternatives which appear to warrant more detailed modeling. This report describes a zero-order trace element distribution model for the Great Plains Coal Gasification Plant located near Beulah, North Dakota. The model estimates how trace elements entering the plant in the feed coal are distributed to the plant's process and waste streams. Elements that may be introduced to the plant's waste streams from sorbents and/or catalysts (e.g., Vanadium in makeup Stretford solution) are not considered in the model. 13 refs.

Thomas, W.C.; Page, G.C.; Magee, R.A.

1987-04-01T23:59:59.000Z

168

Southern cone energy network coal gasification for SNG production and pipeline system feasibility study (Brazil). Volume 2. Export trade information  

Science Conference Proceedings (OSTI)

Part I of the volume reports on the coal gasification plant study performed by the Advanced Technology Division of Fluor Engineers and Constructors, Inc., together with information on coal resources and markets, gas demand, and by-product markets provided by Jaakko Poyry. Jaakko Poyry also supported the study with site, cost, economic, and other required local Brazilian data. Part II of the volume presents the results of Fluor's study of an SNG gas transport and gas distribution system. Also included are the results of an alternate study into barging coal north to a gasification plant located in the Santos area.

Not Available

1992-08-01T23:59:59.000Z

169

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

170

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

171

Duke Energy's Edwardsport Integrated Gasification Combined Cycle...  

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

Duke Energy's Edwardsport Integrated Gasification Combined Cycle (IGCC) Station presently under construction in Knox County, Indiana. (Photos courtesy of Duke Energy.) Gasification...

172

Great Plains Coal Gasification Project. Technical quarterly report, 1st quarter, 1984. [Great Plains, Mercer County, North Dakota  

Science Conference Proceedings (OSTI)

Activities remain on schedule to meet the Great Plains Coal Gasification project's full gas production date. Detailed engineering is complete for the gasification plant. The remaining engineering tasks, which include field support activities and special projects, will be performed by the Contractors' Field Engineering Group. A substantial amount of construction progress was achieved during the first quarter. It is currently projected that construction will be complete at the end of September, 1984. Start-Up operations are continuing at a rapid pace. Commissioning activities are proceeding very well. The only remaining plant permit is the Permit to Operate, which will be issued in late 1985. Quality Assurance/Quality Control activities included the development of welding procedures for Operations personnel, safety relief valve testing, and equipment turnover inspections. Mine development activities remain on schedule. Initial coal deliveries to GPGA commenced this quarter.

Not Available

1984-05-01T23:59:59.000Z

173

ASPEN physical property evaluation for Great Plains simulation. Great Plains ASPEN model development. [Great Plains Coal Gasification Plant  

Science Conference Proceedings (OSTI)

This report documents the steps taken to evaluate the pure component properties in the ASPEN data bank for those compounds required to simulate the Great Plains Coal Gasification Plant where the compounds are also available in the DIPPR (Design Institute for Physical Property Data) data bank. DIPPR is a cooperative effort of industry, institutes and federal agencies interested in the compilation, measurement and evaluation of physical property data for industrially important compounds. It has been found that the ASPEN data bank is for the most part reliable, its main problem being lack of documentation. In the few instances where values were found to be either missing or to be unacceptable, recommended constants or equation parameters are presented in this report along with associated literature citations. In the cases where temperature dependent data were regressed to obtain new equation parameters, the detailed methods employed are also presented.

Millman, M.C.

1983-08-04T23:59:59.000Z

174

High Temperature Electrochemical Polishing of H(2)S from Coal Gasification. Quarterly progress report, April 1-June 30, 1997  

DOE Green Energy (OSTI)

An advanced process for the separation of hydrogen sulfide from coal gasification streams through an electrochemical membrane is being perfected. H{sub 2}S is removed from a synthetic gas stream, split into hydrogen, which enriches the exiting syngas, and sulfur, which is condensed downstream from an inert sweep gas stream. The process allows for continuous removal of H{sub 2}S without cooling the gas stream while allowing negligible pressure loss through the separator. Moreover, the process is economically attractive due to the elimination of the need for a Claus process for sulfur recovery. To this extent the project presents a novel concept for improving utilization of coal for more efficient power generation.

Winnick, J.

1997-12-31T23:59:59.000Z

175

Optimal Design of a Fossil Fuel-Based Hydrogen Infrastructure with Carbon Capture and Sequestration: Case Study in Ohio  

E-Print Network (OSTI)

of hydrogen using coal gasification and distributed hydrogena more modern integrated gasification combined cycle (IGCC)and efficient integrated gasification combined cycle (IGCC)

Johnson, Nils; Yang, Christopher; Ni, Jason; Johnson, Joshua; Lin, Zhenhong; Ogden, Joan M

2005-01-01T23:59:59.000Z

176

Conceptual Design of a Fossil Hydrogen Infrastructure with Capture and Sequestration of Carbon Dioxide: Case Study in Ohio  

E-Print Network (OSTI)

production of H 2 using coal gasification and 2) distributeda more modern integrated gasification combined cycle (IGCC)and efficient integrated gasification combined cycle (IGCC)

2005-01-01T23:59:59.000Z

177

Program on Technology Innovation: Advanced Concepts in Slurry Fed Low Rank Coal Gasification  

Science Conference Proceedings (OSTI)

This document reports on experimental and theoretical analyses of low rank coal/liquid CO2 slurries (LRC/CO2(l)). The results showed that viscosities of LRC/CO2(l) were much lower than for LRC/water slurries of similar coal concentrations and higher coal concentrations could be obtained for liquid CO2 slurries than for water-based slurries at flow conditions typical of industrial scale gasification systems. ASPENplus analyses of a typical integrated gasification combined cycle (IGCC) system showed no del...

2009-04-17T23:59:59.000Z

178

Feasibility study for underground coal gasification at the Krabi coal mine site, Thailand: Volume 1. Progress report, December 1--31, 1995; Export trade information  

SciTech Connect

The report, conducted by Energy and Environmental Research Center, was funded by the US Trade and Development Agency. The objective of this report was to determine the technical, environmental and economic feasibility of developing, demonstrating, and commercializing underground coal gasification (UCG) at the Krabi coal mine site in Southern Thailand. This is Volume 1, the Progress Report for the period December 1, 1995, through December 31, 1995.

Young, B.C.; Schmit, C.R.

1996-01-01T23:59:59.000Z

179

Hot Gas Cleaning with Gas-Solid Reactions and Related Materials ...  

Science Conference Proceedings (OSTI)

In an integrated coal gasification combined cycle power generation (IGCC) and an integrated ... Preparation of Biomass Char for Ironmaking and Its Reactivity.

180

Wabash inside  

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

0 0 SEPTEMBER 2000 The Wabash River Coal Gasification Repowering Project An Update TOPICAL REPORT NUMBER 20 SEPTEMBER 2000 The Wabash River Coal Gasification Repowering Project A report on a project conducted jointly under a cooperative agreement between: The U.S. Department of Energy and Wabash River Coal Gasification Project Joint Venture A 262 MWe Commercial Scale Integrated Gasification Combined Cycle Power Plant An Update View of the Wabash River Coal Gasification Repowering project with the Wabash River and the flat terrain of west central Indiana in the background. Cover image: The Wabash River Coal Gasification Repowering Project Executive Summary ........................................................................................... 1 Background ........................................................................................................

Note: This page contains sample records for the topic "integrated coal-gasification combined" 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

Advanced coal-gasification technical analyses. Appendix 3: technical/economic evaluations. Final report, December 1982-September 1985  

Science Conference Proceedings (OSTI)

This document contains the final report on four tasks performed by KRSI as part of the Advanced Coal Gasification Technical Analysis contract with GRI. It provides extensive, consistent technical and economic information regarding application of (1) Lurgi gasification, (2) Westinghouse (now KRW) gasification, and (3) Direct Methanation (with Lurgi gasifiers) processes to produce SNG from North Dakota lignite. The results of Lurgi and Westinghouse studies were used to develop a plant size vs. cost-of-SNG relationship. The report on each task consists of a block flow diagram, component material balance, process flow sheets showing operating conditions and principal equipment in each major process area, a narrative process description, utility balances, plant efficiency calculations, documentation of design and cost-estimation basis and an economic analysis performed in accordance with the GRI Guidelines. Economic analysis consisted of capital-cost breakdown according to plant areas, variable operating and maintenance costs, and calculation of levelized, constant-dollar cost-of-gas with and without process development allowances (PDA). The sensitivities of the gas cost to major variables are presented in graphical form. For the plant size vs. cost-of-SNG task, similar information is provided at eight different plant capacities based on both Lurgi or Westinghouse gasifiers.

Cover, A.E.; Hubbard, D.A.; Jain, S.K.; Shah, K.V.

1986-01-01T23:59:59.000Z

182

Advanced coal-gasification technical analyses. Appendix 2: coal fines disposal. Final report, December 1982-September 1985  

Science Conference Proceedings (OSTI)

This report is a compilation of several studies conducted by KRSI under the Advanced Coal Gasification Technical Analyses contract with GRI. It addresses the issue of disposal and/or utilization of the coal fines that cannot be used as feedstock for fixed-bed (i.e. Lurgi) gasifiers. Specific items addressed are: (1) Technical, legal and economic aspects of fines burial, (2) Estimation of the premium for fines-free coal delivered to an SNG plant and resulting reduction in SNG production costs, (3) Comparison of the relative advantages and limitations of Winkler and GKT gasifiers to consuming fines, (4) Review of coal-size consist curves in the GRI Guidelines to assess the fines content of ROM coals, (5) a first-pass design and cost estimate using GKT gasifiers in tandem with Lurgi gasifiers in an North Dakota lignite-to-SNG plant to consume full range of coal-size consist, (6) Evaluation of the General Electric technology for extrusion of coal fines and testing of the extrudates in a fixed-bed gasifier, and (7) Investigation of equipment and variables involved in briquetting of coal fines, such that fines could be fed to the gasifiers along with the lump coal.

Cover, A.E.; Hubbard, D.A.; Jain, S.K.; Shah, K.V.

1986-01-01T23:59:59.000Z

183

Hanna, Wyoming underground coal gasification data base. Volume 4. Hanna II, Phases II and III field test research report  

SciTech Connect

This report is part of a seven-volume series on the Hanna, Wyoming, underground coal gasification field tests. Volume 1 is a summary of the project and each of Volumes 2 through 6 describes a particular test. Volume 7 is a compilation of all the data for the tests in Volumes 2 through 6. Hanna II, Phases II and III, were conducted during the winter of 1975 and the summer of 1976. The two phases refer to linking and gasification operations conducted between two adjacent well pairs as shown in Figure 1 with Phase II denoting operations between Wells 5 and 6 and Phase III operations between Wells 7 and 8. All of the other wells shown were instrumentation wells. Wells 7 and 8 were linked in November and December 1975. This report covers: (1) specific site selection and characteristics; (2) test objectives; (3) facilities description; (4) pre-operation tests; (5) test operations summary; and (6) post-test activity. 16 refs., 21 figs., 17 tabs.

Bartke, T.C.; Fischer, D.D.; King, S.B.; Boyd, R.M.; Humphrey, A.E.

1985-08-01T23:59:59.000Z

184

Hydrometallurgical recovery of germanium from coal gasification fly ash. Solvent extraction method  

Science Conference Proceedings (OSTI)

This article is concerned with a simple hydrometallurgical method for the selective recovery of germanium from fly ash (FA) generated in an integrated gasification with combined cycle (IGCC) process. The method is based on the leaching of FA with water and a subsequent concentration and selective separation of germanium by a solvent method. Regarding the leaching step, the different operational conditions studied were liquid/solid (L/S) ratio and time of contact. The solvent extraction method was based on germanium complexation with catechol (CAT) in an aqueous solution followed by the extraction of the Ge-CAT complex with an extracting organic reagent diluted in an organic solvent. The main factors examined during the extraction tests were aqueous phase/organic phase (AP/OP) volumetric ratio, aqueous phase pH, amounts of reagents, and time of contact. Germanium extraction yields were higher than 90%. Alkaline and acid stripping of organic extracts were studied obtaining the best results with 1M NaOH (85%). A high-purity germanium solution was obtained. Experimental data presented in this work show that the extraction of germanium by the solvent method designed can be selective toward germanium, and this element can be effectively separated from arsenic, molybdenum, nickel, antimony, vanadium, and zinc.

Arroyo, F.; Fernandez-Pereira, C. [University of Seville, Seville (Spain)

2008-05-15T23:59:59.000Z

185

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 solvent extraction method was based on Ge complexation with catechol in an aqueous solution followed by the extraction of the Ge-catechol complex (Ge(C{sub 6}H{sub 4}O{sub 2}){sub 3}{sup 2-}) with an extracting organic reagent (trioctylamine) diluted in an organic solvent (kerosene), followed by the subsequent stripping of the organic extract. The process has been tested on a FA generated in an integrated gasification with combined cycle (IGCC) process. The paper describes the designed 5 kg/h pilot plant and the tests performed on it. Under the operational conditions tested, approximately 50% of germanium could be recovered from FA after a water extraction at room temperature. Regarding the solvent extraction method, the best operational conditions for obtaining a concentrated germanium-bearing solution practically free of impurities were as follows: extraction time equal to 20 min; aqueous phase/organic phase volumetric ratio equal to 5; stripping with 1 M NaOH, stripping time equal to 30 min, and stripping phase/organic phase volumetric ratio equal to 5. 95% of germanium were recovered from water leachates using those conditions.

Arroyo, F.; Fernandez-Pereira, C.; Olivares, J.; Coca, P. [University of Seville, Seville (Spain)

2009-04-15T23:59:59.000Z

186

Integrated production of fuel gas and oxygenated organic compounds from synthesis gas  

DOE Patents (OSTI)

An oxygenated organic liquid product and a fuel gas are produced from a portion of synthesis gas comprising hydrogen, carbon monoxide, carbon dioxide, and sulfur-containing compounds in a integrated feed treatment and catalytic reaction system. To prevent catalyst poisoning, the sulfur-containing compounds in the reactor feed are absorbed in a liquid comprising the reactor product, and the resulting sulfur-containing liquid is regenerated by stripping with untreated synthesis gas from the reactor. Stripping offgas is combined with the remaining synthesis gas to provide a fuel gas product. A portion of the regenerated liquid is used as makeup to the absorber and the remainder is withdrawn as a liquid product. The method is particularly useful for integration with a combined cycle coal gasification system utilizing a gas turbine for electric power generation.

Moore, Robert B. (Allentown, PA); Hegarty, William P. (State College, PA); Studer, David W. (Wescosville, PA); Tirados, Edward J. (Easton, PA)

1995-01-01T23:59:59.000Z

187

A Physicochemical Evaluation of the HQ-1 Core from the Pricetown I, Underground Coal Gasification Test Site  

SciTech Connect

Core samples of coal and rock were obtained from the HQ-1 environmental test well at the Pricetown I, Underground Coal Gasification Test Site. A comprehensive analytical program was performed to characterize the coal samples. The rocks associated with the coals are composed of clay size material containing low amounts of organic matter and hydrocarbon gas relative to the coal seams. The fine grained sediment above and below the coal seams appear to be an effective gas seal. The coals were encountered in two intervals of 1 foot and 6 feet thickness separated by 2 feet of shale. The coals are classified as high volatile A or B bituminous based on vitrinite reflectance, fixed carbon, and calorific value. Coal maceral analysis shows that the coal is heterogeneous in petrographic properties. The vitrinite group is the predominant maceral constituent. Fusinite, semi-fusinite, massive micrinite, and sporinite are present in varying amounts. The distribution of porous fusinite layers within the coal seams may be important in the reverse linkage stage of the gasification process. The coal in the bottom seam contains an average of 45.6 standard cubic feet of free methane per ton of coal. This methane may assist in initiating the gasification process. Thermal Conductivity and Laser Thermal Diffusivity experiments were also performed on selected coal samples as well as on samples of the grout used in the instrumentation wells. While the thermal conductivity values were influenced by the tars and oils generated during the heating of the coal, the laser thermal diffusivity values were obtained at sufficiently low temperatures to minimize the influence of the tars and oils.

Zielinski, R. E.; Larson, R. J.

1978-09-20T23:59:59.000Z

188

A Low-Carbon Fuel Standard for California, Part 1: Technical Analysis  

E-Print Network (OSTI)

and power via biomass gasification. Biomass and Bioenergyrenewables Integrated coal gasification combined cycle withLubricants Waxes Naptha Gasification Ethane, Benzene, and

Farrell, Alexander; Sperling, Daniel

2007-01-01T23:59:59.000Z

189

A Low-Carbon Fuel Standard for California Part 1: Technical Analysis  

E-Print Network (OSTI)

and power via biomass gasification. Biomass and Bioenergyrenewables Integrated coal gasification combined cycle withLubricants Waxes Naptha Gasification Ethane, Benzene, and

2007-01-01T23:59:59.000Z

190

The coal char-CO2 reaction at high temperature and pressure.  

E-Print Network (OSTI)

??Integrated gasification combined cycle is an advanced electricity generation technology, based on coal gasification. Wider deployment requires further research into the components of the process,… (more)

Hodge, Elizabeth Marjorie

2009-01-01T23:59:59.000Z

191

Great Plains coal gasification project. Hearing before the Committee on Energy and Natural Resources, United States Senate, One Hundredth Congress, Second Session, September 12, 1988  

Science Conference Proceedings (OSTI)

The hearing was called to review the announcement by the Department of Energy that it has selected Basin Electric Power Cooperative of Bismarck, North Dakota, as the preferred buyer for the Great Plains Coal Gasification Plant. The plant produces 142 billion standard cubic feet of synthetic natural gas per day from lignite coal plus several byproducts which are marketed. The hearing examines the bids of the finalists, the composition of the trust funds, the status of the siting permits, questions of air quality, employee retirement funds and employee benefits, and the ability of the successful bidder to pursue byproduct development and marketing. Testimony was heard from 7 witnesses.

Not Available

1989-01-01T23:59:59.000Z

192

Advanced Concepts in Slurry-Fed Low-Rank Coal Gasification  

Science Conference Proceedings (OSTI)

After an initial scouting study (described in Electric Power Research Institute [EPRI] Technical Update 1014432) revealed that using liquid CO2 in place of water in coal slurries could have several beneficial effects on integrated-gasificationcombined-cycles (IGCCs) employing CO2 capture, EPRI's Program on Technology Innovation funded additional work on this subject. This report summarizes the results of rheological testing performed with slurries made from liquid CO2 and two types of subbituminous coal ...

2008-09-14T23:59:59.000Z

193

Numerical study on convection diffusion for gasification agent in underground coal gasification. Part I: establishment of mathematical models and solving method  

SciTech Connect

The aim of this article is to discuss the distribution law of the gasification agent concentration in a deep-going way during underground coal gasification and the new method of solving the problem for the convection diffusion of the gas. In this paper, the basic features of convection diffusion for the gas produced in underground coal gasification are studied. On the basis of the model experiment, through the analysis of the distribution and patterns of variation for the fluid concentration field in the process of the combustion and gasification of the coal seams within the gasifier, the 3-D non-linear unstable mathematical models on the convection diffusion for oxygen are established. In order to curb such pseudo-physical effects as numerical oscillation and surfeit which frequently occurred in the solution of the complex mathematical models, the novel finite unit algorithm, the upstream weighted multi-cell balance method is advanced in this article, and its main derivation process is introduced.

Yang, L.H.; Ding, Y.M. [China University of Mining & Technology, Xuzhou (China). College of Resources and Geoscience

2009-07-01T23:59:59.000Z

194

Program on Technology Innovation: Advanced Concepts in Slurry-Fed Low-Rank Coal Gasification  

Science Conference Proceedings (OSTI)

This report documents the results of a Technology Innovation screening study of concepts for improving the performance of slurry-fed gasification combined cycle power plants on low rank coals by using two innovative coal preparation technologies: coal slurries with liquid CO2 as the fluid, and hot water drying. Slurry-fed gasification technologies have a cost advantage over dry-fed systems, but they suffer a large performance penalty when used on low rank coals because of the large fraction of water and ...

2006-12-01T23:59:59.000Z

195

Coal gasification system with a modulated on/off control system  

DOE Patents (OSTI)

A modulated control system is provided for improving regulation of the bed level in a fixed-bed coal gasifier into which coal is fed from a rotary coal feeder. A nuclear bed level gauge using a cobalt source and an ion chamber detector is used to detect the coal bed level in the gasifier. The detector signal is compared to a bed level set point signal in a primary controller which operates in proportional/integral modes to produce an error signal. The error signal is modulated by the injection of a triangular wave signal of a frequency of about 0.0004 Hz and an amplitude of about 80% of the primary deadband. The modulated error signal is fed to a triple-deadband secondary controller which jogs the coal feeder speed up or down by on/off control of a feeder speed change driver such that the gasifier bed level is driven toward the set point while preventing excessive cycling (oscillation) common in on/off mode automatic controllers of this type. Regulation of the bed level is achieved without excessive feeder speed control jogging.

Fasching, George E. (Morgantown, WV)

1984-01-01T23:59:59.000Z

196

Coal gasification apparatus  

DOE Patents (OSTI)

Coal hydrogenation vessel has hydrogen heating passages extending vertically through its wall and opening into its interior.

Nagy, Charles K. (Monaca, PA)

1982-01-01T23:59:59.000Z

197

Integrated low emissions cleanup system for direct coal fueled turbines. Twenty-eighth quarterly report, July--September 1994  

SciTech Connect

The United States Department of Energy, Morgantown Energy Research Center (DOE/METC), is sponsoring the development of advanced, coal-fueled turbine power plants such as pressurized fluid bed combustion and coal gasification combined cycles. A major technical challenge remaining for the development of the coal-fueled turbine is high-temperature gas cleaning to meet environmental standards for sulfur oxides and particulate emissions, as well as to provide acceptable turbine life. The Westinghouse Electric Corporation, Science & Technology Center, is evaluating Integrated Low Emissions Cleanup (ILEC) concepts that have been configured to meet this technical challenge. These ILEC concepts simultaneously control sulfur, particulate, and alkali contaminants in the high-pressure process gases. This document reports the status of a program in the twenty-seventh quarter to develop this ILEC technology.

Newby, R.A.; Alvin, M.A.; Bachovchin, D.M. [and others

1996-02-01T23:59:59.000Z

198

High temperature electrochemical polishing of H{sub 2}S from coal gasification process streams. Quarterly progress report, October 1, 1995--December 31, 1995  

DOE Green Energy (OSTI)

An advanced process for the separation of hydrogen sulfide (H{sub 2}S) from coal gasification product streams through an electrochemical membrane is being developed. H{sub 2}S is removed from the syn-gas stream, split into hydrogen, which enriches the exiting syn-gas, and sulfur, which is condensed from an inert sweep gas stream. The process allows removal of H{sub 2}S without cooling the gas stream and with negligible pressure loss through the separator. The process is made economically attractive by the lack of need for a Claus process for sulfur recovery. Membrane manufacturing coupled with full-cell experimentation was the primary focus this quarter. A tape-casted zirconia membrane was developed and utilized in one full-cell experiment (run 25); run 24 utilized a fabricated membrane purchased from Zircar Corporation. Results are discussed.

Winnick, J.

1995-12-31T23:59:59.000Z

199

Advanced development of a pressurized ash agglomerating fluidized-bed coal gasification system. Fourth quarter progress report, July 1-September 30, 1982  

Science Conference Proceedings (OSTI)

The overall objective of the Westinghouse coal gasification program is to demonstrate the viability of the Westinghouse pressurized, fluidized bed, gasification system for the production of medium-Btu fuel gas for syngas, electrical power generation, chemical feedstocks, or industrial fuels and to obtain performance and scaleup data for the process and hardware. Technical progress summaries and reports are presented for the following tasks: (1) process development unit (PDU) test operations and results (gasifier test TP-033-1 and maintenance and modifications); (2) process analysis (environmental characterization results, coal gas combustion results, and fines elutriation and consumption results); (3) cold flow scaleup (modifications and maintenance, operations, and data analysis); (4) process and component engineering and design (hot fines recycle modifications, and hot recycled fines); (5) laboratory support studies (gas-solids flow modeling and coal/ash behavior). 23 figures, 23 tables.

None

1983-02-17T23:59:59.000Z

200

An Integrated Assessment of the Impacts of Hydrogen Economy on Transportation, Energy Use, and Air Emissions  

E-Print Network (OSTI)

Energy Outlook coal gasification compressed natural gastechnologies, including gasification and water electrolysis.of natural gas, coal gasification was the preferred method

Yeh, Sonia; Loughlin, Daniel H.; Shay, Carol; Gage, Cynthia

2007-01-01T23:59:59.000Z

Note: This page contains sample records for the topic "integrated coal-gasification combined" 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

Integrated low emissions cleanup system for direct coal fueled turbines (moving bed, fluid bed contactor/ceramic filter). Twenty-ninth quarterly status report, October--December 1994  

SciTech Connect

The United States Department of Energy, Morgantown Energy Research Center (DOE/METC), is sponsoring the development of advanced, coal-fueled turbine power plants such as pressurized fluid bed combustion and coal gasification combined cycles. A major technical challenge remaining for the development of the coal-fueled turbine is high-temperature gas cleaning to meet environmental standards for sulfur oxides and particulate emissions, as well as to provide acceptable turbine life. The Westinghouse Electric Corporation, Science & Technology Center, is evaluating Integrated Low Emissions Cleanup (ILEC) concepts that have been configured to meet this technical challenge. These ILEC concepts simultaneously control sulfur, particulate, and alkali contaminants in the high-pressure process gases. This document reports the status of a program in the twenty-seventh quarter to develop this ILEC technology.

Newby, R.A.; Alvin, M.A.; Bachovchin, D.M. [and others

1996-02-01T23:59:59.000Z

202

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:

203

2009 Integrated Gasification Combined Cycle Engineering Economic Evaluation  

Science Conference Proceedings (OSTI)

The 2009 Electric Power Research Institute (EPRI) report Integrated Gasification Combined Cycle (IGCC) Design Considerations for Carbon Dioxide (CO2) Capture (1015690) contains engineering and economic evaluations of state-of-the-art integrated gasification combined cycle (IGCC) power plant designs available for near-term deployment. The study assessed the expected performance and costs of coal-fed IGCC power plants before and after retrofit for carbon dioxide (CO2) capture. The study evaluated paired ca...

2009-09-30T23:59:59.000Z

204

EIS-0431: Hydrogen Energy California's Integrated Gasification Combined  

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

1: Hydrogen Energy California's Integrated Gasification 1: Hydrogen Energy California's Integrated Gasification Combined Cycle and Carbon Capture and Sequestration Project, California EIS-0431: Hydrogen Energy California's Integrated Gasification Combined Cycle and Carbon Capture and Sequestration Project, California Summary This EIS evaluates the potential environmental impacts of a proposal to provide financial assistance for the construction and operation of Hydrogen Energy California LLC (HECA's) project, which would produce and sell electricity, carbon dioxide and fertilizer. DOE selected this project for an award of financial assistance through a competitive process under the Clean Coal Power Initiative program. Public Comment Opportunities None available at this time. Documents Available for Download September 5, 2013

205

Novel single stripper with side-draw to remove ammonia and sour gas simultaneously for coal-gasification wastewater treatment and the industrial implementation  

SciTech Connect

A large amount of wastewater is produced in the Lurgi coal-gasification process with the complex compounds carbon dioxide, ammonia, phenol, etc., which cause a serious environmental problem. In this paper, a novel stripper operated at elevated pressure is designed to improve the pretreatment process. In this technology, two noticeable improvements were established. First, the carbon dioxide and ammonia were removed simultaneously in a single stripper where sour gas (mainly carbon dioxide) is removed from the tower top and the ammonia vapor is drawn from the side and recovered by partial condensation. Second, the ammonia is removed before the phenol recovery to reduce the pH value of the subsequent extraction units, so as the phenol removal performance of the extraction is greatly improved. To ensure the operational efficiency, some key operational parameters are analyzed and optimized though simulation. It is shown that when the top temperature is kept at 40 C and the weight ratio of the side draw to the feed is above 9%, the elevated pressures can ensure the removal efficiency of NH{sub 3} and carbon dioxide and the desired purified water as the bottom product of the unit is obtained. A real industrial application demonstrates the attractiveness of the new technique: it removes 99.9% CO{sub 2} and 99.6% ammonia, compared to known techniques which remove 66.5% and 94.4%, respectively. As a result, the pH value of the wastewater is reduced from above 9 to below 7. This ensures that the phenol removal ratio is above 93% in the following extraction units. The operating cost is lower than that of known techniques, and the operation is simplified.

Feng, D.C.; Yu, Z.J.; Chen, Y.; Qian, Y. [South China University of Technology, Ghangzhou (China). School of Chemical Engineering

2009-06-15T23:59:59.000Z

206

Medical Image Integrity Control Combining Digital Signature and Lossless Watermarking  

E-Print Network (OSTI)

Medical Image Integrity Control Combining Digital Signature and Lossless Watermarking W. Pan1,3 , G protection of medical content becomes a major issue of computer security. Since medical contents are more proposed as a com- plementary mechanism for medical data protection. In this paper, we focus

Paris-Sud XI, Université de

207

Integrated gasification combined cycle - a view to the future  

SciTech Connect

DOE is involved in research, development, and demonstration of Integrated Gasification Combined Cycle because of a strong belief that it will result in widespread commercialization that will be of great benefit to this nation. METC`s long-range vision comprises (1) product goals that require improvements to known technical advantages, and (2) market goals that are based on expectations of market pull.

Schmidt, D.K.

1994-10-01T23:59:59.000Z

208

Development of an Integrated Multicontaminant Removal Process Applied to Warm Syngas Cleanup for Coal-Based Advanced Gasification Systems  

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

an Integrated an Integrated Multicontaminant Removal Process Applied to Warm Syngas Cleanup for Coal-Based Advanced Gasification Systems Background The U.S. has more coal than any other country, and it can be converted through gasification into electricity, liquid fuels, chemicals, or hydrogen. However, for coal gasification to become sufficiently competitive to benefit the U.S. economy and help reduce our dependence on foreign fuels, gasification costs must be reduced

209

"Integrated Gasification Combined Cycle"  

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

Status of technologies and components modeled by EIA" Status of technologies and components modeled by EIA" ,"Revolutionary","Evolutionary","Mature" "Pulverized Coal",,,"X" "Pulverized Coal with CCS" " - Non-CCS portion of Pulverized Coal Plant",,,"X" " - CCS","X" "Integrated Gasification Combined Cycle" " - Advanced Combustion Turbine",,"X" " - Heat Recovery Steam Generator",,,"X" " - Gasifier",,"X" " - Balance of Plant",,,"X" "Conventional Natural Gas Combined Cycle" " - Conventional Combustion Turbine",,,"X" " - Heat Recovery Steam Generator",,,"X" " - Balance of Plant",,,"X"

210

NOVEL GAS CLEANING/CONDITIONING FOR INTEGRATED GASIFICATION COMBINED CYCLE  

SciTech Connect

The objective of this program is to develop and evaluate novel sorbents for the Siemens Westinghouse Power Company's (SWPC's) ''Ultra-Clean Gas Cleaning Process'' for reducing to near-zero levels the sulfur- and chlorine-containing gas emissions and fine particulate matter (PM2.5) caused by fuel bound constituents found in carbonaceous materials, which are processed in Integrated Gasification Combined Cycle (IGCC) technologies.

Javad Abbasian

2001-07-01T23:59:59.000Z

211

Integrated gasification combined-cycle research development and demonstration activities  

Science Conference Proceedings (OSTI)

The United States Department of Energy (DOE) has selected six integrated gasification combined-cycle (IGCC) advanced power systems for demonstration in the Clean Coal Technology (CCT) Program. DOE`s Office of Fossil Energy, Morgantown Energy Technology Center, is managing a research development and demonstration (RD&D) program that supports the CCT program, and addresses long-term improvements in support of IGCC technology. This overview briefly describes the CCT projects and the supporting RD&D activities.

Ness, H.M.; Reuther, R.B.

1995-12-01T23:59:59.000Z

212

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

213

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

214

Available at: http://publications.ictp.it IC/2010/077 United Nations Educational, Scientific and Cultural Organization  

E-Print Network (OSTI)

technology facility in service. Sec. 413. Western integrated coal gasification demonstration project. Sec. 414. Coal gasification. Sec. 415. Petroleum coke gasification. Sec. 416. Electron scrubbing

215

Assessment of underground coal gasification in bituminous coals: potential UCG products and markets. Final report, Phase I  

Science Conference Proceedings (OSTI)

The following conclusions were drawn from the study: (1) The US will continue to require new sources of energy fuels and substitutes for petrochemical feedstocks into the foreseeable future. Most of this requirement will be met using coal. However, the cost of mining, transporting, cleaning, and preparing coal, disposing of ash or slag and scrubbing stack gases continues to rise; particularly, in the Eastern US where the need is greatest. UCG avoids these pitfalls and, as such, should be considered a viable alternative to the mining of deeper coals. (2) Of the two possible product gases LBG and MBG, MBG is the most versatile. (3) The most logical use for UCG product in the Eastern US is to generate power on-site using a combined-cycle or co-generation system. Either low or medium Btu gas (LBG or MBG) can be used. (4) UCG should be an option whenever surface gasification is considered; particularly, in areas where deeper, higher sulfur coal is located. (5) There are environmental and social benefits to use of UCG over surface gasification in the Eastern US. (6) A site could be chosen almost anywhere in the Illinois and Ohio area where amenable UCG coal has been determined due to the existence of existing transportation or transmission systems. (7) The technology needs to be demonstrated and the potential economic viability determined at a site in the East-North-Central US which has commercial quantities of amenable bituminous coal before utilities will show significant interest.

None

1982-01-31T23:59:59.000Z

216

Enhanced Hydrogen Production Integrated with CO2 Separation in a Single-Stage Reactor  

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

EnhancEd hydrogEn Production EnhancEd hydrogEn Production intEgratEd with co 2 SEParation in a SinglE-StagE rEactor Description One alternative for the United States to establish independence from foreign energy sources is to utilize the nation's abundant domestic reserves of coal. Gasification provides a route to produce liquid fuels, chemical feedstocks, and hydrogen from coal. Coal continues to be viewed as the fuel source for the 21st century. Products from coal gasification, however, contain other gases, particularly carbon dioxide, as well as other contaminants that must be removed to produce the pure stream of hydrogen needed to operate fuel cells and other devices. This project seeks to demonstrate a technology to efficiently produce a pure hydrogen stream from

217

Integration of Ion Transport Membrane Technology with Integrated Gasification Combined Cycle Power Generation Systems  

Science Conference Proceedings (OSTI)

EPRI, in conjunction with Air Products and Chemicals, Inc. (AP), has reviewed the integrated gasification combined cycle (IGCC) process, whereby coal (or some other hydrocarbon such as petroleum coke or heavy oil) is broken down into its constituent volatile and nonvolatile components through the process of oxidative-pyrolysis. Combustible synthetic gas created in the process can be used in a traditional combined cycle. IGCC is particularly appealing for its potentially higher efficiencies compared ...

2013-10-30T23:59:59.000Z

218

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

219

INTEGRATED PYROLYSIS COMBINED CYCLE BIOMASS POWER SYSTEM CONCEPT DEFINITION  

DOE Green Energy (OSTI)

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

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

2003-03-01T23:59:59.000Z

220

Coal Gasification Report.indb  

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

Booz Allen Hamilton Booz Allen Hamilton Final Report, September 3, 2004 list of acronyms List of Acronyms AEO Annual Energy Outlook ASU Air Separation Unit BACT Best Available Control Technology BTU British Thermal Unit CCPI Clean Coal Power Initiative CFB Circulating Fluidized Bed CO Carbon Monoxide CO 2 Carbon Dioxide COE Cost of Electricity Co-Op Co-Operative CRS Congressional Research Service DG Distributed Generation

Note: This page contains sample records for the topic "integrated coal-gasification combined" 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

Coal gasification apparatus. [Patent application  

DOE Patents (OSTI)

Coal hydrogenation vessel has hydrogen heating passages extending vertically through its wall and opening into its interior.

Nagy, C.K.

1981-04-24T23:59:59.000Z

222

Apparatus for solar coal gasification  

DOE Patents (OSTI)

Apparatus for using focused solar radiation to gasify coal and other carbonaceous materials is described. Incident solar radiation is focused from an array of heliostats through a window onto the surface of a moving bed of coal, contained within a gasification reactor. The reactor is designed to minimize contact between the window and solids in the reactor. Steam introduced into the gasification reactor reacts with the heated coal to produce gas consisting mainly of carbon monoxide and hydrogen, commonly called synthesis gas, which can be converted to methane, methanol, gasoline, and other useful products. One of the novel features of the invention is the generation of process steam in one embodiment at the rear surface of a secondary mirror used to redirect the focused sunlight. Another novel feature of the invention is the location and arrangement of the array of mirrors on an inclined surface (e.g., a hillside) to provide for direct optical communication of said mirrors and the carbonaceous feed without a secondary redirecting mirror.

Gregg, D.W.

1980-08-04T23:59:59.000Z

223

ENCOAL Mild Coal Gasification Project  

DOE Green Energy (OSTI)

ENCOAL Corporation, a wholly-owned subsidiary of Shell Mining Company, is constructing a mild gasification demonstration plant at Triton Coal Company's Buckskin Mine near Gillette, Wyoming. The process, using Liquids From Coal (LFC) technology developed by Shell and SGI International, utilizes low-sulfur Powder River Basin Coal to produce two new fuels, Process Derived Fuel (PDF) and Coal Derived Liquids (CDL). The products, as alternative fuels sources, are expected to significantly reduce current sulfur emissions at industrial and utility boiler sites throughout the nation, thereby reducing pollutants causing acid rain.

Not Available

1992-02-01T23:59:59.000Z

224

Coal Gasification Report.indb  

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

Act of 2003, and S. 843, the Clean Air Planning Act of 2003. (September 2003). U.S. Energy Information Administration, EIA Report SROIAF2003-03. http:www.eia.doe.govoiaf...

225

Coal Gasification Report.indb  

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

of facilities being identified as limits to transfers, and market- based congestion management procedures and TLR transmission loading relief procedures are required in areas...

226

WORKING PAPER SERIES MIT-IPC-Energy Innovation Working Paper 08-001  

E-Print Network (OSTI)

to biofuels plants; carbon sequestration; integrated coal gasification-combined cycle plants with carbon Congressional appropriation. It has been estimated that more than $15 billion of revenues would be generated

227

NOVEL GAS CLEANING/ CONDITIONING FOR INTEGRATED GASIFICATION COMBINED CYCLE  

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

INTEGRATED GASIFICATION COMBINED CYCLE VOLUME I - CONCEPTUAL COMMERCIAL EVALUATION OPTIONAL PROGRAM FINAL REPORT September 1, 2001 - December 31, 2005 By Dennis A. Horazak (Siemens), Program Manager Richard A. Newby (Siemens) Eugene E. Smeltzer (Siemens) Rachid B. Slimane (GTI) P. Vann Bush (GTI) James L. Aderhold, Jr. (GTI) Bruce G. Bryan (GTI) December 2005 DOE Award Number: DE-AC26-99FT40674 Prepared for U.S. Department of Energy National Energy Technology Laboratory Prepared by Siemens Power Generation, Inc. 4400 Alafaya Trail Orlando, FL 32826 & Gas Technology Institute 1700 S. Mt. Prospect Rd. Des Plaines, Illinois 60018 DISCLAIMER This report was prepared as an account of work sponsored by an agency of the United States Government.

228

Integrated gasifier combined cycle polygeneration system to produce liquid hydrogen  

SciTech Connect

An integrated gasifier combined cycle (IGCC) system which simultaneously produces electricity, process steam, and liquid hydrogen was evaluated and compared to IGCC systems which cogenerate electricity and process steam. A number of IGCC plants, all employing a 15 MW gas turbine and producing from 0 to 20 tons per day of liquid hydrogen and from 0 to 20 MW of process steam were considered. The annual revenue required to own and operate such plants was estimated to be significantly lower than the potential market value of the products. The results indicate a significant potential economic benefit to configuring IGCC systems to produce a clean fuel in addition to electricity and process steam in relatively small industrial applications.

Burns, R.K.; Staiger, P.J.; Donovan, R.M.

1982-07-01T23:59:59.000Z

229

A review of biomass integrated-gasifier/gas turbine combined cycle technology and its  

E-Print Network (OSTI)

A review of biomass integrated-gasifier/gas turbine combined cycle technology and its application Copersucar, CP 162, Piracicaba, SP ­ Brazil ­ 13400-970 Biomass integrated-gasifier/gas turbine combined-from-sugarcane program. 1. Introduction The biomass integrated-gasifier/gas turbine combined cy- cle (BIG

230

Integrated gasification combined cycle overview of FETC--S program  

Science Conference Proceedings (OSTI)

Changing market conditions, brought about by utility deregulation and increased environmental regulations, have encouraged the Department of Energy/Federal Energy Technology Center (DOE/FETC) to restructure its Integrated Gasification Combined Cycle (IGCC) program. The program emphasis, which had focused on baseload electricity production from coal, is now expanded to more broadly address the production of a suite of energy and chemical products. The near-term market barrier for baseload power applications for conventional IGCC systems combines with increasing opportunities to process a range of low- and negative-value opportunity feedstocks. The new program is developing a broader range of technology options that will increase the versatility and the technology base for commercialization of gasification-based technologies. This new strategy supports gasification in niche markets where, due to its ability to coproduce a wide variety of commodity and premium products to meet market requirements, it is an attractive alternative. By obtaining operating experience in industrial coproduction applications today, gasification system modules can be refined and improved leading to commercial guarantees and acceptance of gasification technology as a cost-effective technology for baseload power generation and coproduction as these markets begin to open.

Stiegel, G.J.; Maxwell, R.C.

1999-07-01T23:59:59.000Z

231

Model Predictive Control of Integrated Gasification Combined Cycle Power Plants  

SciTech Connect

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

B. Wayne Bequette; Priyadarshi Mahapatra

2010-08-31T23:59:59.000Z

232

Modeling the Performance, Emissions, and Costs of Texaco Gasifier-Based Integrated Gasification Combined Cycle Systems.  

E-Print Network (OSTI)

??Integrated Gasification Combined Cycle (IGCC) systems are an advanced power generation concept with the flexibility to use coal, heavy oils, petroleum coke, biomass, and waste… (more)

Akunuri, Naveen

1999-01-01T23:59:59.000Z

233

Coal Gasification - section in Kirk-Othmer Concise Encyclopedia of Chemical Technology, 5th Edition, 2-vol. set, July 2007, ISBN 978-0-470-04748-4, pp. 580-587  

Science Conference Proceedings (OSTI)

Coal gasification is the process of reacting coal with oxygen, steam, and carbon dioxide to form a product gas containing hydrogen and carbon monoxide. Gasification is essentially incomplete combustion. The chemical and physical processes are quite similar, the main difference being the nature of the final products. From a processing point of view the main operating difference is that gasification consumes heat evolved during combustion. Under the reducing environment of gasification the sulfur in the coal is released as hydrogen sulfide rather than sulfur dioxide and the coal's nitrogen is converted mostly to ammonia rather than nitrogen oxides. These reduced forms of sulfur and nitrogen are easily isolated, captured, and utilized, and thus gasification is a clean coal technology with better environmental performance than coal combustion. Depending on the type of gasifier and the operating conditions, gasification can be used to produce a fuel gas suitable for any number of applications. A low heating value fuel gas is produced from an air blown gasifier for use as an industrial fuel and for power production. A medium heating value fuel gas is produced from enriched oxygen blown gasification for use as a synthesis gas in the production of chemicals such as ammonia, methanol, and transportation fuels. A high heating value gas can be produced from shifting the medium heating value product gas over catalysts to produce a substitute or synthetic natural gas (SNG).

Shadle, L.J.; Berry, D.A.; Syamlal, Madhava

2007-07-01T23:59:59.000Z

234

Integrated low emissions cleanup system for coal fueled turbines Phase III bench-scale testing and evaluation  

SciTech Connect

The United States Department of Energy, Morgantown Energy Research Center (DOE/METC), is sponsoring the development of coal-fired turbine technologies such as Pressurized Fluidized Bed Combustion (PFBC), coal Gasification Combined Cycles (GCC), and Direct Coal-Fired Turbines (DCFT). A major technical development challenge remaining for coal-fired turbine systems is high-temperature gas cleaning to meet environmental emissions standards, as well as to ensure acceptable turbine life. The Westinghouse Electric Corporation, Science & Technology Center, has evaluated an Integrated Low Emissions Cleanup (ILEC) concept that has been configured to meet this technical challenge. This ceramic hot gas filter (HGF), ILEC concept controls particulate emissions, while simultaneously contributing to the control of sulfur and alkali vapor contaminants in high-temperature, high-pressure, fuel gases or combustion gases. This document reports on the results of Phase III of the ILEC evaluation program, the final phase of the program. In Phase III, a bench-scale ILEC facility has been tested to (1) confirm the feasibility of the ILEC concept, and (2) to resolve some major filter cake behavior issues identified in PFBC, HGF applications.

Newby, R.A.; Alvin, M.A.; Bachovchin, D.M. [and others

1995-08-01T23:59:59.000Z

235

Combining Path Integration and Remembered Landmarks When Navigating without Vision  

E-Print Network (OSTI)

This study investigated the interaction between remembered landmark and path integration strategies for estimating current location when walking in an environment without vision. We asked whether observers navigating without ...

Schrater, Paul R.

236

Combined Penalty Multiplier Optimization Methods to Enforce Integral Invariants Conservation  

Science Conference Proceedings (OSTI)

An augmented Lagrangian multiplier-penalty method is applied for the first time to solving the problem of enforcing simultaneous conservation of the nonlinear integral invariants of the shallow water equations on a limited-area domain. The method ...

I. M. Navon; R. de Villiers

1983-06-01T23:59:59.000Z

237

INTEGRATED GASIFICATION COMBINED CYCLE PROJECT 2 MW FUEL CELL DEMONSTRATION  

DOE Green Energy (OSTI)

With about 50% of power generation in the United States derived from coal and projections indicating that coal will continue to be the primary fuel for power generation in the next two decades, the Department of Energy (DOE) Clean Coal Technology Demonstration Program (CCTDP) has been conducted since 1985 to develop innovative, environmentally friendly processes for the world energy market place. The 2 MW Fuel Cell Demonstration was part of the Kentucky Pioneer Energy (KPE) Integrated Gasification Combined Cycle (IGCC) project selected by DOE under Round Five of the Clean Coal Technology Demonstration Program. The participant in the CCTDP V Project was Kentucky Pioneer Energy for the IGCC plant. FuelCell Energy, Inc. (FCE), under subcontract to KPE, was responsible for the design, construction and operation of the 2 MW fuel cell power plant. Duke Fluor Daniel provided engineering design and procurement support for the balance-of-plant skids. Colt Engineering Corporation provided engineering design, fabrication and procurement of the syngas processing skids. Jacobs Applied Technology provided the fabrication of the fuel cell module vessels. Wabash River Energy Ltd (WREL) provided the test site. The 2 MW fuel cell power plant utilizes FuelCell Energy's Direct Fuel Cell (DFC) technology, which is based on the internally reforming carbonate fuel cell. This plant is capable of operating on coal-derived syngas as well as natural gas. Prior testing (1992) of a subscale 20 kW carbonate fuel cell stack at the Louisiana Gasification Technology Inc. (LGTI) site using the Dow/Destec gasification plant indicated that operation on coal derived gas provided normal performance and stable operation. Duke Fluor Daniel and FuelCell Energy developed a commercial plant design for the 2 MW fuel cell. The plant was designed to be modular, factory assembled and truck shippable to the site. Five balance-of-plant skids incorporating fuel processing, anode gas oxidation, heat recovery, water treatment/instrument air, and power conditioning/controls were built and shipped to the site. The two fuel cell modules, each rated at 1 MW on natural gas, were fabricated by FuelCell Energy in its Torrington, CT manufacturing facility. The fuel cell modules were conditioned and tested at FuelCell Energy in Danbury and shipped to the site. Installation of the power plant and connection to all required utilities and syngas was completed. Pre-operation checkout of the entire power plant was conducted and the plant was ready to operate in July 2004. However, fuel gas (natural gas or syngas) was not available at the WREL site due to technical difficulties with the gasifier and other issues. The fuel cell power plant was therefore not operated, and subsequently removed by October of 2005. The WREL fuel cell site was restored to the satisfaction of WREL. FuelCell Energy continues to market carbonate fuel cells for natural gas and digester gas applications. A fuel cell/turbine hybrid is being developed and tested that provides higher efficiency with potential to reach the DOE goal of 60% HHV on coal gas. A system study was conducted for a 40 MW direct fuel cell/turbine hybrid (DFC/T) with potential for future coal gas applications. In addition, FCE is developing Solid Oxide Fuel Cell (SOFC) power plants with Versa Power Systems (VPS) as part of the Solid State Energy Conversion Alliance (SECA) program and has an on-going program for co-production of hydrogen. Future development in these technologies can lead to future coal gas fuel cell applications.

FuelCell Energy

2005-05-16T23:59:59.000Z

238

An Integrated Hydrogen Vision for California  

E-Print Network (OSTI)

of $2.00-2.50 per kilogram. Gasification of Coal and Othermore generally as “gasification,” hydrogen can be producedproduced from coal gasification POx processes at delivered

2004-01-01T23:59:59.000Z

239

Computational Modeling of Combined Steam Pyrolysis and Hydrogasification of Ethanol  

E-Print Network (OSTI)

JL, Kinetics of Coal Gasification, New York, John Wiley &applications to technical gasification processes- A review.kinetics of steam gasification for a transport gasifier.

Singh, S; Park, C S; Norbeck, J N

2005-01-01T23:59:59.000Z

240

Catalytic combustor for integrated gasification combined cycle power plant  

DOE Patents (OSTI)

A gasification power plant 10 includes a compressor 32 producing a compressed air flow 36, an air separation unit 22 producing a nitrogen flow 44, a gasifier 14 producing a primary fuel flow 28 and a secondary fuel source 60 providing a secondary fuel flow 62 The plant also includes a catalytic combustor 12 combining the nitrogen flow and a combustor portion 38 of the compressed air flow to form a diluted air flow 39 and combining at least one of the primary fuel flow and secondary fuel flow and a mixer portion 78 of the diluted air flow to produce a combustible mixture 80. A catalytic element 64 of the combustor 12 separately receives the combustible mixture and a backside cooling portion 84 of the diluted air flow and allows the mixture and the heated flow to produce a hot combustion gas 46 provided to a turbine 48. When fueled with the secondary fuel flow, nitrogen is not combined with the combustor portion.

Bachovchin, Dennis M. (Mauldin, SC); Lippert, Thomas E. (Murrysville, PA)

2008-12-16T23:59:59.000Z

Note: This page contains sample records for the topic "integrated coal-gasification combined" 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

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

242

Containment integrity of SEP plants under combined loads. [PWR; BWR  

Science Conference Proceedings (OSTI)

Because the containment structure is the last barrier against the release of radioactivity, an assessment was undertaken to identify the design weaknesses and estimate the margins of safety for the SEP containments under the postulated, combined loading conditions of a safe shutdown earthquake (SSE) and a design basis accident (DBA). The design basis accident is either a loss-of-coolant accident (LOCA) or a main steam line break (MSLB). The containment designs analyzed consisted of three inverted light-bulb shaped drywells used in boiling water reactor (BWR) systems, and three steel-lined concrete containments and a spherical steel shell used in pressurized water reactor (PWR) systems. These designs cover a majority of the containment types used in domestic operating plants. The results indicate that five of the seven designs are adequate even under current design standards. For the remaining two designs, the possible design weaknesses identified were buckling of the spherical steel shell and over-stress in both the radial and tangential directions in one of the concrete containments near its base.

Lo, T.; Nelson, T.A.; Chen, P.Y.; Persinko, D.; Grimes, C.

1984-06-01T23:59:59.000Z

243

The importance of combined cycle generating plants in integrating large levels of wind power generation  

Science Conference Proceedings (OSTI)

Integration of high wind penetration levels will require fast-ramping combined cycle and steam cycles that, due to higher operating costs, will require proper pricing of ancillary services or other forms of compensation to remain viable. Several technical and policy recommendations are presented to help realign the generation mix to properly integrate the wind. (author)

Puga, J. Nicolas

2010-08-15T23:59:59.000Z

244

Tampa Electric Company Integrated Gasification Combined Cycle Project  

SciTech Connect

The proposed project will utilize commercially available gasification technology as provided by Texaco in their licensed oxygen-blown entrained-flow gasifier. In this arrangement, coal is ground to specification and slurried in water to the desired concentration (60--70% solids) in rod mills. This coal slurry and an oxidant (95 % pure oxygen) are then mixed in the gasifier burner where the coal partially combusts, in an oxygen deficient environment, to produce syngas with a heat content of about 250 BTU/SCF (LHV) at a temperature in excess of 2500{degrees}F. The oxygen will be produced from an Air Separation Unit (ASU). The gasifier is expected to achieve greater than 95% carbon conversion in a single pass. It is currently planned for the gasifier to be a single vessel feeding into one radiant syngas cooler where the temperature will be reduced from about 2500{degrees}F to about 1300{degrees}F. After the radiant cooler, the gas will then be split into two (2) parallel convective coolers, where the temperature will be cooled further to about 900{degrees}F. One stream will go to the 50% HGCU system and the other stream to the traditional CGCU system with 100% capacity. This flow arrangement was selected to provide assurance to Tampa Electric that the IGCC capability would not be restricted due to the demonstration of the HGCU system. A traditional amine scrubber type system with conventional sulfur recovery will be used. Sulfur from the HGCU and CGCU systems will be recovered in the form of H{sub 2}SO{sub 4} and elemental sulfur respectively.The key components of the combined cycle are the advanced combustion.turbine (CT), heat recovery steam generator (HRSG), and steam turbine (ST), and generators. The advanced CT will be a GE 7F operating with a firing temperature of about 2300{degrees}F.

Pless, D.E.; Black, C.R.

1992-11-01T23:59:59.000Z

245

Tampa Electric Company Integrated Gasification Combined Cycle Project  

SciTech Connect

The proposed project will utilize commercially available gasification technology as provided by Texaco in their licensed oxygen-blown entrained-flow gasifier. In this arrangement, coal is ground to specification and slurried in water to the desired concentration (60--70% solids) in rod mills. This coal slurry and an oxidant (95 % pure oxygen) are then mixed in the gasifier burner where the coal partially combusts, in an oxygen deficient environment, to produce syngas with a heat content of about 250 BTU/SCF (LHV) at a temperature in excess of 2500[degrees]F. The oxygen will be produced from an Air Separation Unit (ASU). The gasifier is expected to achieve greater than 95% carbon conversion in a single pass. It is currently planned for the gasifier to be a single vessel feeding into one radiant syngas cooler where the temperature will be reduced from about 2500[degrees]F to about 1300[degrees]F. After the radiant cooler, the gas will then be split into two (2) parallel convective coolers, where the temperature will be cooled further to about 900[degrees]F. One stream will go to the 50% HGCU system and the other stream to the traditional CGCU system with 100% capacity. This flow arrangement was selected to provide assurance to Tampa Electric that the IGCC capability would not be restricted due to the demonstration of the HGCU system. A traditional amine scrubber type system with conventional sulfur recovery will be used. Sulfur from the HGCU and CGCU systems will be recovered in the form of H[sub 2]SO[sub 4] and elemental sulfur respectively.The key components of the combined cycle are the advanced combustion.turbine (CT), heat recovery steam generator (HRSG), and steam turbine (ST), and generators. The advanced CT will be a GE 7F operating with a firing temperature of about 2300[degrees]F.

Pless, D.E.; Black, C.R.

1992-01-01T23:59:59.000Z

246

NOVEL GAS CLEANING/CONDITIONING FOR INTEGRATED GASIFICATION COMBINED CYCLE  

DOE Green Energy (OSTI)

Development efforts have been underway for decades to replace dry-gas cleaning technology with humid-gas cleaning technology that would maintain the water vapor content in the raw gas by conducting cleaning at sufficiently high temperature to avoid water vapor condensation and would thus significantly simplify the plant and improve its thermal efficiency. Siemens Power Generation, Inc. conducted a program with the Gas Technology Institute (GTI) to develop a Novel Gas Cleaning process that uses a new type of gas-sorbent contactor, the ''filter-reactor''. The Filter-Reactor Novel Gas Cleaning process described and evaluated here is in its early stages of development and this evaluation is classified as conceptual. The commercial evaluations have been coupled with integrated Process Development Unit testing performed at a GTI coal gasifier test facility to demonstrate, at sub-scale the process performance capabilities. The commercial evaluations and Process Development Unit test results are presented in Volumes 1 and 2 of this report, respectively. Two gas cleaning applications with significantly differing gas cleaning requirements were considered in the evaluation: IGCC power generation, and Methanol Synthesis with electric power co-production. For the IGCC power generation application, two sets of gas cleaning requirements were applied, one representing the most stringent ''current'' gas cleaning requirements, and a second set representing possible, very stringent ''future'' gas cleaning requirements. Current gas cleaning requirements were used for Methanol Synthesis in the evaluation because these cleaning requirements represent the most stringent of cleaning requirements and the most challenging for the Filter-Reactor Novel Gas Cleaning process. The scope of the evaluation for each application was: (1) Select the configuration for the Filter-Reactor Novel Gas Cleaning Process, the arrangement of the individual gas cleaning stages, and the probable operating conditions of the gas cleaning stages to conceptually satisfy the gas cleaning requirements; (2) Estimate process material & energy balances for the major plant sections and for each gas cleaning stage; (3) Conceptually size and specify the major gas cleaning process equipment; (4) Determine the resulting overall performance of the application; and (5) Estimate the investment cost and operating cost for each application. Analogous evaluation steps were applied for each application using conventional gas cleaning technology, and comparison was made to extract the potential benefits, issues, and development needs of the Filter-Reactor Novel Gas Cleaning technology. The gas cleaning process and related gas conditioning steps were also required to meet specifications that address plant environmental emissions, the protection of the gas turbine and other Power Island components, and the protection of the methanol synthesis reactor. Detailed material & energy balances for the gas cleaning applications, coupled with preliminary thermodynamic modeling and laboratory testing of candidate sorbents, identified the probable sorbent types that should be used, their needed operating conditions in each stage, and their required levels of performance. The study showed that Filter-Reactor Novel Gas Cleaning technology can be configured to address and conceptually meet all of the gas cleaning requirements for IGCC, and that it can potentially overcome several of the conventional IGCC power plant availability issues, resulting in improved power plant thermal efficiency and cost. For IGCC application, Filter-Reactor Novel Gas Cleaning yields 6% greater generating capacity and 2.3 percentage-points greater efficiency under the Current Standards case, and more than 9% generating capacity increase and 3.6 percentage-points higher efficiency in the Future Standards case. While the conceptual equipment costs are estimated to be only slightly lower for the Filter-Reactor Novel Gas Cleaning processes than for the conventional processes, the improved power plant capacity results in the potentia

Dennis A. Horazak; Richard A. Newby; Eugene E. Smeltzer; Rachid B. Slimane; P. Vann Bush; James L. Aderhold Jr; Bruce G. Bryan

2005-12-01T23:59:59.000Z

247

Tampa Electric Company Polk Integrated Gasification Combined Cycle Plant Carbon Capture Retrofit Study  

Science Conference Proceedings (OSTI)

In support of the Industry Technology Demonstration Program on Integrated Gasification Combined Cycle (IGCC) with carbon capture and storage (CCS), an engineering study was conducted to evaluate the cost and performance impacts of various CCS schemes at the Tampa Electric Polk Power Station. The portion of the work presented here was funded by the Electric Power Research Institute (EPRI) IGCC with CCS demonstration program collaborative and focuses on novel CO2 capture and purification systems integrated...

2010-03-30T23:59:59.000Z

248

Kentucky Pioneer Integrated Gasification Combined Cycle Demonstration Project, Final Environmental Impact Statement  

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

8 8 U.S. Department of Energy Kentucky Pioneer Integrated Gasification Combined Cycle Demonstration Project Final Environmental Impact Statement November 2002 U.S. Department of Energy National Energy Technology Laboratory COVER SHEET Responsible Agency: U.S. Department of Energy (DOE) Title: Kentucky Pioneer Integrated Gasification Combined Cycle (IGCC) Demonstration Project Final Environmental Impact Statement (EIS) (DOE/EIS-0318) Location: Clark County, Kentucky Contacts: For further information on this environmental For further information on the DOE National impact statement (EIS), call: Environmental Policy Act (NEPA) process, call: 1-800-432-8330 ext. 5460 1-800-472-2756 or contact: or contact: Mr. Roy Spears Ms. Carol Borgstrom

249

Development and application of optimal design capability for coal gasification systems - Task 1 (Volume 1, 2 and 3). Topical report, July 1995  

SciTech Connect

Selective catalytic reduction (SCR) is a process for the post-combustion removal of NO{sub x} from the flue gas of fossil-fuel-fired power plants. SCR is capable of NO{sub x} reduction efficiencies of up to 80 or 90 percent. SCR technology has been applied for treatment of flue gases from a variety of emission sources, including natural gas- and oil-fired gas turbines, process steam boilers in refineries, and coal-fired power plants. SCR applications to coal-fired power plants have occurred in Japan and Germany. Full-scale SCR systems have not been applied to coal-fired power plants in the U.S., although there have been small-scale demonstration projects. SCR has become increasingly widely applied in the U.S. to natural-gas fired gas turbine combined cycle systems. In the remainder of this section, we review the applicability of SCR, as well as the need for post-combustion NO{sub x} control, for several power generation systems.

1995-09-01T23:59:59.000Z

250

Westinghouse to launch coal gasifier with combined cycle unit  

Science Conference Proceedings (OSTI)

Westinghouse has designed a prototype coal gasifier which can be intergrated with a combined cycle unit and enable power plants to use coal in an efficient and environmentally acceptable way. Coal Gasification Combined Cycle (CGCC) technology burns gas made from coal in a gas turbine to generate power and then collects the hot exhaust gases to produce steam for further power generation. The commercialization of this process would meet the public's need for an economical and clean way to use coal, the utitities' need to meet electric power demands, and the nation's need to reduce dependence on imported oil. The Westinghouse process is described along with the company's plans for a demonstration plant and the option of a phased introduction to allow utilities to continue the use of existing equipment and generate revenue while adding to capacity. (DCK)

Stavsky, R.M.; Margaritis, P.J.

1980-03-01T23:59:59.000Z

251

Cost and performance analysis of biomass-based integrated gasification combined-cycle (BIGCC) power systems  

DOE Green Energy (OSTI)

To make a significant contribution to the power mix in the United States biomass power systems must be competitive on a cost and efficiency basis. We describe the cost and performance of three biomass-based integrated gasification combined cycle (IGCC) systems. The economic viability and efficiency performance of the IGCC generation technology appear to be quite attractive.

Craig, K. R.; Mann, M. K.

1996-10-01T23:59:59.000Z

252

Benefits of Integrating PWR and RTI Advanced Gasification Technologies for  

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

Syngas Processing Systems Syngas Processing Systems Benefits of Integrating PWR and RTI Advanced Gasification Technologies for Hydrogen-Rich Syngas Production Research Triangle Institute (RTI) Project Number: FE0012066 Project Description The project will assess the potential for integrated advanced technologies to substantially reduce capital and production costs for hydrogen-rich syngas with near-zero emissions from coal gasification for power production with carbon capture and for coal-to-liquids (specifically methanol) with carbon capture. These integrated technologies include those already tested successfully at pilot-scale with a new and innovative water-gas-shift technology, to show how multiple advanced technologies will leverage each other for significant cost and efficiency gains.

253

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

254

Fluidized bed catalytic coal gasification process  

DOE Patents (OSTI)

Coal or similar carbonaceous solids impregnated with gasification catalyst constituents (16) are oxidized by contact with a gas containing between 2 volume percent and 21 volume percent oxygen at a temperature between 50.degree. C. and 250.degree. C. in an oxidation zone (24) and the resultant oxidized, catalyst impregnated solids are then gasified in a fluidized bed gasification zone (44) at an elevated pressure. The oxidation of the catalyst impregnated solids under these conditions insures that the bed density in the fluidized bed gasification zone will be relatively high even though the solids are gasified at elevated pressure and temperature.

Euker, Jr., Charles A. (15163 Dianna La., Houston, TX 77062); Wesselhoft, Robert D. (120 Caldwell, Baytown, TX 77520); Dunkleman, John J. (3704 Autumn La., Baytown, TX 77520); Aquino, Dolores C. (15142 McConn, Webster, TX 77598); Gouker, Toby R. (5413 Rocksprings Dr., LaPorte, TX 77571)

1984-01-01T23:59:59.000Z

255

The Great Plains coal gasification project status  

SciTech Connect

The Great Plains Gasification Project is the first commercial-sized plant to produce substitute natural gas from coal in the United States. The plant is designed to convert 14,000 tons/D of North Dakota lignite into 137.5 million standard cubic feet of gas per day. The plant construction has been successfully completed per original design, on schedule and on budget. The plant has also been successfully turned over from construction to operations, as per the original plan. With the completion of the capital projects being implemented at the plant, plans are to achieve 70 percent stream factor in the first year of production (1985). The DOE-Chicago Operations Office has been assigned the responsibility for monitoring the project's performance against baselines of cost, schedule, and technical criteria. During the startup phase of the project, significant technological advancements have been made and considerable knowledge has been gained, both by the operators and DOE (considering this to be a first of a kind plant built in the U.S.).

Bodnaruk, B.J.

1986-07-01T23:59:59.000Z

256

Catalysts for carbon and coal gasification  

DOE Patents (OSTI)

Catalyst for the production of methane from carbon and/or coal by means of catalytic gasification. The catalyst compostion containing at least two alkali metal salts. A particulate carbonaceous substrate or carrier is used.

McKee, Douglas W. (Burnt Hills, NY); Spiro, Clifford L. (Scotia, NY); Kosky, Philip G. (Schenectady, NY)

1985-01-01T23:59:59.000Z

257

Heat exchanger for coal gasification process  

DOE Patents (OSTI)

This invention provides a heat exchanger, particularly useful for systems requiring cooling of hot particulate solids, such as the separated fines from the product gas of a carbonaceous material gasification system. The invention allows effective cooling of a hot particulate in a particle stream (made up of hot particulate and a gas), using gravity as the motive source of the hot particulate. In a preferred form, the invention substitutes a tube structure for the single wall tube of a heat exchanger. The tube structure comprises a tube with a core disposed within, forming a cavity between the tube and the core, and vanes in the cavity which form a flow path through which the hot particulate falls. The outside of the tube is in contact with the cooling fluid of the heat exchanger.

Blasiole, George A. (Greensburg, PA)

1984-06-19T23:59:59.000Z

258

Apparatus and method for solar coal gasification  

DOE Patents (OSTI)

Apparatus for using focused solar radiation to gasify coal and other carbonaceous materials. Incident solar radiation is focused from an array of heliostats onto a tower-mounted secondary mirror which redirects the focused solar radiation down through a window onto the surface of a vertically-moving bed of coal, or a fluidized bed of coal, contained within a gasification reactor. The reactor is designed to minimize contact between the window and solids in the reactor. Steam introduced into the gasification reactor reacts with the heated coal to produce gas consisting mainly of carbon monoxide and hydrogen, commonly called "synthesis gas", which can be converted to methane, methanol, gasoline, and other useful products. One of the novel features of the invention is the generation of process steam at the rear surface of the secondary mirror.

Gregg, David W. (Moraga, CA)

1980-01-01T23:59:59.000Z

259

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

260

Integrated gasification combined-cycle research development and demonstration activities in the US  

Science Conference Proceedings (OSTI)

The United States Department of Energy (DOE)`s Office of Fossil Energy, Morgantown Energy Technology Center, is managing a research development and demonstration (RD&D) program that supports the commercialization of integrated gasification combined-cycle (IGCC) advanced power systems. This overview briefly describes the supporting RD&D activities and the IGCC projects selected for demonstration in the Clean Coal Technology (CCT) Program.

Ness, H.M.; Brdar, R.D.

1996-09-01T23:59:59.000Z

Note: This page contains sample records for the topic "integrated coal-gasification combined" 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

Integrated gasification combined-cycle research development and demonstration activities in the U.S.  

Science Conference Proceedings (OSTI)

The United States Department of Energy (DOE) has selected seven integrated gasification combined-cycle (IGCC) advanced power systems for demonstration in the Clean Coal Technology (CCT) Program. DOE`s Office of Fossil Energy, Morgantown Energy Technology Center, is managing a research development and demonstration (RD&D)program that supports the CCT program, and addresses long-term improvements in support of IGCC technology. This overview briefly describes the CCT projects and the supporting RD&D activities.

Ness, H.M.

1994-12-31T23:59:59.000Z

262

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

263

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

264

Integrated Vehicle Thermal Management - Combining Fluid Loops in Electric Drive Vehicles (Presentation)  

SciTech Connect

Plug-in hybrid electric vehicles and electric vehicles have increased vehicle thermal management complexity, using separate coolant loop for advanced power electronics and electric motors. Additional thermal components result in higher costs. Multiple cooling loops lead to reduced range due to increased weight. Energy is required to meet thermal requirements. This presentation for the 2013 Annual Merit Review discusses integrated vehicle thermal management by combining fluid loops in electric drive vehicles.

Rugh, J. P.

2013-07-01T23:59:59.000Z

265

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

266

Conceptual design and techno-economic assessment of integrated solar combined cycle system with DSG technology  

SciTech Connect

Direct steam generation (DSG) in parabolic trough collectors causes an increase to competitiveness of solar thermal power plants (STPP) by substitution of oil with direct steam generation that results in lower investment and operating costs. In this study the integrated solar combined cycle system with DSG technology is introduced and techno-economic assessment of this plant is reported compared with two conventional cases. Three considered cases are: an integrated solar combined cycle system with DSG technology (ISCCS-DSG), a solar electric generating system (SEGS), and an integrated solar combined cycle system with HTF (heat transfer fluid) technology (ISCCS-HTF). This study shows that levelized energy cost (LEC) for the ISCCS-DSG is lower than the two other cases due to reducing O and M costs and also due to increasing the heat to electricity net efficiency of the power plant. Among the three STPPs, SEGS has the lowest CO{sub 2} emissions, but it will operate during daytime only. (author)

Nezammahalleh, H.; Farhadi, F.; Tanhaemami, M. [Chemical and Petroleum Engineering Department, Sharif University of Technology, No 593 Azadi Ave., Tehran (Iran)

2010-09-15T23:59:59.000Z

267

Sei Vojany Station repowering reconstruction assessment feasibility study. Volume 2. Export trade information  

Science Conference Proceedings (OSTI)

Six technologies are considered for application to the proposed Vojany Power Station EVO III. These technologies are: Conventional pulverized coal (PC) with SOx and NOx control; Atmospheric circulating fluidized bed (CFB); Atmospheric bubbling fluidized bed (BFB); Pressurized fluidized bed combustion combined cycle (PFBC-CC); Integrated coal gasification combined cycle (IGCC); and Gas fired combustion turbine combined cycle (CTCC).

Not Available

1992-01-01T23:59:59.000Z

268

Chemical Science and Engineering Annual Report 2006  

E-Print Network (OSTI)

, coal gasification, fuel synthesis, high-efficiency turbines, fuel cells, high-temperature materials, including: - coal gasification systems with feedstock flexibility - hybrid technologies that combine coal combustion and coal gasification - combined-cycle gas turbines and high temperature (>1700°C) gas turbine

Lagergren, Jens

269

Energy impacts of controlling carbon dioxide emissions from an integrated gasification/combined-cycle system  

SciTech Connect

This paper presents results from a study of the impacts associated with CO{sub 2} recovery in integrated gasification/combined-cycle (IGCC) systems which is being conducted for the Morgantown Energy Technology Center by Argonne National Laboratory. The objective of the study is to compare, on a consistent systems-oriented basis, the energy and economic impacts of adding CO{sub 2} capture and sequestration to an IGCC system. The research reported here has emphasized commercial technologies for capturing CO{sub 2}, but ongoing work is also addressing advanced technologies under development and alternate power-system configurations that may enhance system efficiency.

Livengood, C.D.; Doctor, R.D.; Molburg, J.C.; Thimmapuram, P.

1994-08-01T23:59:59.000Z

270

Feasibility Study for an Integrated Gasification Combined Cycle Facility at a Texas Site  

Science Conference Proceedings (OSTI)

Interest in integrated gasification combined-cycle technology (IGCC) has grown sharply since the passage of the Energy Policy Act in 2005. Many new projects are being planned since the AEP and Duke 600-MW IGCC plants were announced nearly two years ago. This report compares the cost and performance of IGCC with a supercritical pulverized coal plant (SCPC) based on lower-rank Powder River Basin (PRB) coal. IGCC options included 100% PRB and 50/50 PRB/petcoke cases. The addition of CO2 capture equipment al...

2006-10-23T23:59:59.000Z

271

What Energy ModelersWhat Energy Modelers Need to Know AboutNeed to Know About  

E-Print Network (OSTI)

$4­7/GJ; 90% capture; aquifer storage Current Coal Plants PC NGCC Natural Gas Plants Plants with CCS combustion (PC) Natural gas combined cycle (NGCC) Integrated coal gasification combined cycle (IGCC.S. Rubin, Carnegie Mellon Post-Combustion Technology for Industrial CO2 Capture BP Natural Gas Processing

272

Modeling and optimization of a combined cycle Stirling-ORC system and design of an integrated microchannel Stirling heat rejector.  

E-Print Network (OSTI)

??The performance of a combined Stirling-ORC power cycle is evaluated, and an integrated microchannel heat exchanger is designed as an annular cold-side heat rejector for… (more)

[No author

2010-01-01T23:59:59.000Z

273

New Projects Set to Target Efficiency, Environmental Gains at Advanced Coal  

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

Projects Set to Target Efficiency, Environmental Gains at Projects Set to Target Efficiency, Environmental Gains at Advanced Coal Gasification Facilities New Projects Set to Target Efficiency, Environmental Gains at Advanced Coal Gasification Facilities July 27, 2010 - 1:00pm Addthis Washington, D.C. -- Four projects that will demonstrate an innovative technology that could eventually enhance hydrogen fuel production, lower greenhouse gas (GHG) emissions, improve efficiencies and lower consumer electricity costs from advanced coal gasification power systems have been selected by the U.S. Department of Energy (DOE). The projects will test membrane technology to separate hydrogen and carbon dioxide (CO2) from coal or coal/biomass-derived synthesis gas (syngas), such as from Integrated Gasification Combined Cycle (IGCC) power systems.

274

Tr7-cover.jpg:Corel PHOTO-PAINT  

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

7 7 The Wabash River Coal Gasification Repowering Project A 262 MWe Commercial Scale Integrated Gasification Combined Cycle Power Plant A report on a project conducted jointly under a cooperative agreement between: The United States Department of Energy and Wabash River Coal Gasification Project Joint Venture NOVEMBER 1996 Cover Image: View of the Wabash River Coal Gasification Repowering project with the Wabash River and the flat terrain of west central Indiana in the background. Preparation and printing of this document con- forms to the general funding provisions of a cooperative agreement between Destec En- ergy Inc., PSI Energy, Inc., and the U.S. De- partment of Energy. The funding contribution of the industrial participant permitted inclusion of multicolored artwork and photographs at no

275

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

276

Kentucky Pioneer Integrated Gasification Combined Cycle Demonstration Project, Final Environmental Impact Statement  

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

S-1 S-1 SUMMARY The U.S. Department of Energy (DOE) prepared this environmental impact statement (EIS) on the proposed Kentucky Pioneer Integrated Gasification Combined Cycle (IGCC) Demonstration Project in compliance with the National Environmental Policy Act (NEPA). The National Environmental Policy Act Process NEPA is a federal law that serves as the basic national charter for protection of the environment. For major federal actions that may significantly affect the quality of the environment, NEPA requires federal agencies to prepare a detailed statement that includes the potential environmental impacts of the Proposed Action and reasonable alternatives. A fundamental objective of NEPA is to foster better decisionmaking by ensuring that high quality environmental information is available to public officials and members of the

277

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

278

Analysis of potential benefits of integrated-gasifier combined cycles for a utility system  

SciTech Connect

Potential benefits of integrated gasifier combined cycle (IGCC) units were evaluated for a reference utility system by comparing long range expansion plans using IGCC units and gas turbine peakers with a plan using only state of the art steam turbine units and gas turbine peakers. Also evaluated was the importance of the benefits of individual IGCC unit characteristics, particularly unit efficiency, unit equivalent forced outage rate, and unit size. A range of IGCC units was analyzed, including cases achievable with state of the art gas turbines and cases assuming advanced gas turbine technology. All utility system expansion plans that used IGCC units showed substantial savings compared with the base expansion plan using the steam turbine units.

Choo, Y.K.

1983-10-01T23:59:59.000Z

279

Model predictive control system and method for integrated gasification combined cycle power generation  

DOE Patents (OSTI)

Control system and method for controlling an integrated gasification combined cycle (IGCC) plant are provided. The system may include a controller coupled to a dynamic model of the plant to process a prediction of plant performance and determine a control strategy for the IGCC plant over a time horizon subject to plant constraints. The control strategy may include control functionality to meet a tracking objective and control functionality to meet an optimization objective. The control strategy may be configured to prioritize the tracking objective over the optimization objective based on a coordinate transformation, such as an orthogonal or quasi-orthogonal projection. A plurality of plant control knobs may be set in accordance with the control strategy to generate a sequence of coordinated multivariable control inputs to meet the tracking objective and the optimization objective subject to the prioritization resulting from the coordinate transformation.

Kumar, Aditya; Shi, Ruijie; Kumar, Rajeeva; Dokucu, Mustafa

2013-04-09T23:59:59.000Z

280

Computational Modeling of Combined Steam Pyrolysis and Hydrogasification of Ethanol  

E-Print Network (OSTI)

H. (1981). Reactivities of carbon to steam and hydrogen andreaction kinetics of steam gasification for a transportof coal gasification with steam and CO2. Fuel, 77(15), 17.

Singh, S; Park, C S; Norbeck, J N

2005-01-01T23:59:59.000Z

Note: This page contains sample records for the topic "integrated coal-gasification combined" 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

Final Report Environmental Footprints and Costs of Coal-Based Integrated Gasification Combined Cycle and  

E-Print Network (OSTI)

Currently, over 50 percent of electricity in the U.S. is generated from coal. Given that coal reserves in the U.S. are estimated to meet our energy needs over the next 250 years, coal is expected to continue to play a major role in the generation of electricity in this country. With dwindling supplies and high prices of natural gas and oil, a large proportion of the new power generation facilities built in the U.S. can be expected to use coal as the main fuel. The environmental impact of these facilities can only be minimized by innovations in technology that allow for efficient burning of coal, along with an increased capture of the air pollutants that are an inherent part of coal combustion. EPA considers integrated gasification combined cycle (IGCC) as one of the most promising technologies in reducing environmental consequences of generating electricity from coal. EPA has undertaken several initiatives to facilitate and incentivize development and deployment of this technology. This report is the result of one of these initiatives and it represents the combined efforts of a joint EPA/DOE team formed to advance the IGCC technology. The various offices within DOE that participated in the development/review of this report were the Office of Fossil Energy, including the Clean Coal Office and the National Energy Technology Laboratory.

Pulverized Coal; Technologies Foreword

2006-01-01T23:59:59.000Z

282

Carbon Dioxide Capture from Coal-Fired  

E-Print Network (OSTI)

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

283

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

284

December 9, 2008 Conservation  

E-Print Network (OSTI)

expensive Gasification Integrated coal gasification combined-cycle (IGCC) - Very early commercial IGCC w and Conservation Council Capital cost estimate: Supercritical PC coal plant (no CSS) $0 $500 $1,000 $1,500 $2 of Estimate OvernightCapitalCost(2006$/kW) Generic Supercritical w/o CSS Rankine Projects Supercritical 6th

285

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

286

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

287

Carbon Dioxide Capture from Integrated Gasification Combined Cycle Gas Streams Using the Ammonium Carbonate-Ammonium Bicarbonate Process  

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

Integrated Integrated Gasification Combined Cycle Gas Streams Using the Ammonium Carbonate- Ammonium Bicarbonate Process Description Current commercial processes to remove carbon dioxide (CO 2 ) from conventional power plants are expensive and energy intensive. The objective of this project is to reduce the cost associated with the capture of CO 2 from coal based gasification processes, which convert coal and other carbon based feedstocks to synthesis gas.

288

Kentucky Pioneer Integrated Gasification Combined Cycle Demonstration Project Final Environmental Impact Statement  

Science Conference Proceedings (OSTI)

The abundance of coal in the United States makes it one of our Nation's most important strategic resources in building a secure energy future. With today's prices and technology, recoverable reserves located in the United States could supply the Nation's coal consumption for approximately 250 years at current usage rates. However, if coal is to reach its full potential as an environmentally acceptable source of energy, an expanded menu of advanced clean coal technologies must be developed to provide substantially improved options both for the consumer and private industry. Before any technology can be seriously considered for commercialization, it must be demonstrated at a sufficiently large-scale to develop industry confidence in its technical and economic feasibility. The implementation of a federal technology demonstration program is the established means of accelerating the development of technology to meet national energy strategy and environmental policy goals, to reduce the risk to human health and the environment to an acceptable level, to accelerate commercialization, and to provide the incentives required for continued activity in research and development directed at providing solutions to long-range energy problems. The U.S. Department of Energy (DOE) prepared this environmental impact statement (EIS) on the proposed Kentucky Pioneer Integrated Gasification Combined Cycle (IGCC) Demonstration Project in compliance with the National Environmental Policy Act (NEPA).

N /A

2002-12-13T23:59:59.000Z

289

Gas turbine effects on integrated-gasification-combined-cycle power plant operations  

SciTech Connect

This study used detailed thermodynamic modeling procedures to assess the influence of different gas turbine characteristics and steam cycle conditions on the design and off-design performance of integrated gasification-combined-cycle (IGCC) power plants. IGCC plant simulation models for a base case plant with Texaco gasifiers and both radiant and convective syngas coolers were developed, and three different types of gas turbines were evaluated as well as non-reheat and reheat steam systems. Results indicated that improving the gas turbine heat rate significantly improves the heat rate of the IGCC power plant. In addition results indicated that using a reheat steam system with current gas turbines improves IGCC performance, though as gas turbine efficiency increases, the impact of using a reheat steam system decreases. Increasing gas turbine temperatures from 1985{degree}F to 2500{degree}F was also found to have the potential to reduce overall IGCC system heat rates by approximately 700 BTU/kWh. The methodologies and models developed for this work are extremely useful tools for investigating the impact of specific gas turbine and steam cycle conditions on the overall performance of IGCC power plants. Moreover, they can assist utilities during the preliminary engineering phase of an IGCC project in evaluating the cost effectiveness of using specific gas turbines and steam cycles in the overall plant design. 45 refs., 20 figs., 10 tabs.

Eustis, F.H. (Stanford Univ., CA (USA). High Temperature Gasdynamics Lab.)

1990-03-01T23:59:59.000Z

290

The potential for control of carbon dioxide emissions from integrated gasification/combined-cycle systems  

SciTech Connect

Initiatives to limit carbon dioxide (CO{sub 2}) emissions have drawn considerable interest to integrated gasification/combined-cycle (IGCC) power generation, a process that reduces CO{sub 2} production through efficient fuel used is amenable to CO{sub 2} capture. This paper presents a comparison of energy systems that encompass fuel supply, an IGCC system, CO{sub 2} recovery using commercial technologies, CO{sub 2} transport by pipeline, and land-based sequestering in geological reservoirs. The intent is to evaluate the energy-efficiency impacts of controlling CO{sub 2} in such systems and to provide the CO{sub 2} budget, or an to equivalent CO{sub 2}`` budget, associated with each of the individual energy-cycle steps. The value used for the ``equivalent CO{sub 2}`` budget is 1 kg/kWh CO{sub 2}. The base case for the comparison is a 457-MW IGCC system that uses an air-blown Kellogg-Rust-Westinghouse (KRW) agglomerating fluidized-bed gasifier, Illinois No. 6 bituminous coal, and in-bed sulfur removal. Mining, preparation, and transportation of the coal and limestone result in a net system electric power production of 454 MW with a 0.835 kg/kwh CO{sub 2} release rate. For comparison, the gasifier output is taken through a water-gas shift to convert CO to CO{sub 2} and then processed in a glycol-based absorber unit to recover CO{sub 2} Prior to the combustion turbine. A 500-km pipeline then transports the CO{sub 2} for geological sequestering. The net electric power production for the system with CO{sub 2} recovery is 381 MW with a 0.156 kg/kwh CO{sub 2} release rate.

Livengood, C.D.; Doctor, R.D.; Molburg, J.C.; Thimmapuram, P.; Berry, G.F.

1994-06-01T23:59:59.000Z

291

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

292

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

293

AN INTEGRATED MODELING FRAMEWORK FOR CARBON MANAGEMENT TECHNOLOGIES  

Science Conference Proceedings (OSTI)

CO{sub 2} capture and storage (CCS) is gaining widespread interest as a potential method to control greenhouse gas emissions from fossil fuel sources, especially electric power plants. Commercial applications of CO{sub 2} separation and capture technologies are found in a number of industrial process operations worldwide. Many of these capture technologies also are applicable to fossil fuel power plants, although applications to large-scale power generation remain to be demonstrated. This report describes the development of a generalized modeling framework to assess alternative CO{sub 2} capture and storage options in the context of multi-pollutant control requirements for fossil fuel power plants. The focus of the report is on post-combustion CO{sub 2} capture using amine-based absorption systems at pulverized coal-fired plants, which are the most prevalent technology used for power generation today. The modeling framework builds on the previously developed Integrated Environmental Control Model (IECM). The expanded version with carbon sequestration is designated as IECM-cs. The expanded modeling capability also includes natural gas combined cycle (NGCC) power plants and integrated coal gasification combined cycle (IGCC) systems as well as pulverized coal (PC) plants. This report presents details of the performance and cost models developed for an amine-based CO{sub 2} capture system, representing the baseline of current commercial technology. The key uncertainties and variability in process design, performance and cost parameters which influence the overall cost of carbon mitigation also are characterized. The new performance and cost models for CO{sub 2} capture systems have been integrated into the IECM-cs, along with models to estimate CO{sub 2} transport and storage costs. The CO{sub 2} control system also interacts with other emission control technologies such as flue gas desulfurization (FGD) systems for SO{sub 2} control. The integrated model is applied to study the feasibility and cost of carbon capture and sequestration at both new and existing PC plants as well as new NGCC plants. The cost of CO{sub 2} avoidance using amine-based CO{sub 2} capture technology is found to be sensitive to assumptions about the reference plant design and operation, as well as assumptions about the CO{sub 2} capture system design. The case studies also reveal multi-pollutant interactions and potential tradeoffs in the capture of CO{sub 2}, SO{sub 2}, NO{sub 2} and NH{sub 3}. The potential for targeted R&D to reduce the cost of CO{sub 2} capture also is explored using the IECM-cs in conjunction with expert elicitations regarding potential improvements in key performance and cost parameters of amine-based systems. The results indicate that the performance of amine-based CO{sub 2} capture systems can be improved significantly, and the cost of CO{sub 2} capture reduced substantially over the next decade or two, via innovations such as new or improved sorbents with lower regeneration heat requirements, and improvements in power plant heat integration to reduce the (currently large) energy penalty of CO{sub 2} capture. Future work will explore in more detail a broader set of advanced technology options to lower the costs of CO{sub 2} capture and storage. Volume 2 of this report presents a detailed User's Manual for the IECM-cs computer model as a companion to the technical documentation in Volume 1.

Anand B. Rao; Edward S. Rubin; Michael B. Berkenpas

2004-03-01T23:59:59.000Z

294

Integration of Combined Heat and Power Generators into Small Buildings - A Transient Analysis Approach.  

E-Print Network (OSTI)

??Small combined heat and power generators have the potential to reduce energy consumption and greenhouse gas emissions of residential buildings. Recently, much attention has been… (more)

DeBruyn, Adrian Bryan

2007-01-01T23:59:59.000Z

295

Feasibility Studies to Improve Plant Availability and Reduce Total Installed Cost in Integrated Gasification Combined Cycle Plants  

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

Feasibility Studies to Improve Plant Feasibility Studies to Improve Plant Availability and Reduce Total Installed Cost in Integrated Gasification Combined Cycle Plants Background Gasification provides the means to turn coal and other carbonaceous solid, liquid and gaseous feedstocks as diverse as refinery residues, biomass, and black liquor into synthesis gas and valuable byproducts that can be used to produce low-emissions power, clean-burning fuels and a wide range of commercial products to support

296

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

297

Program on Technology Innovation: Tampa Electric Company Polk Integrated Gasification Combined Cycle Plant Carbon Capture Retrofit Study  

Science Conference Proceedings (OSTI)

In support of the Industry Technology Demonstration Program on Integrated Gasification Combined Cycle (IGCC) with carbon capture and storage (CCS), an engineering study was conducted to evaluate the cost and performance impacts of various CCS schemes at the Tampa Electric Polk Power Station. The portion of the work presented here was funded by the Electric Power Research Institute (EPRI) Technology Innovation Program and focuses on a comparison of chemical and physical solvent-based CO2 capture systems i...

2010-03-30T23:59:59.000Z

298

A Low-Carbon Fuel Standard for California, Part 1: Technical Analysis  

E-Print Network (OSTI)

natural gas price volatility has engendered a resurgence in coal-coal gasification combined cycle with carbon capture and storage Natural gas combined cycle Price

Farrell, Alexander; Sperling, Daniel

2007-01-01T23:59:59.000Z

299

A Low-Carbon Fuel Standard for California Part 1: Technical Analysis  

E-Print Network (OSTI)

natural gas price volatility has engendered a resurgence in coal-coal gasification combined cycle with carbon capture and storage Natural gas combined cycle Price

2007-01-01T23:59:59.000Z

300

Rainfall Parameter Estimation from Dual-Radar Measurements Combining Reflectivity Profile and Path-integrated Attenuation  

Science Conference Proceedings (OSTI)

Rain rate estimation properties of multiparameter radar measurements combining radar reflectivity and microwave attenuations are studied through simulations using a two-year disdrometer dataset. In the first simulation, properties of “complete” ...

Toshiaki Kozu; Kenji Nakamura

1991-04-01T23:59:59.000Z

Note: This page contains sample records for the topic "integrated coal-gasification combined" 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

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

SciTech Connect

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

NONE

1995-05-01T23:59:59.000Z

302

Analysis of Carbon Dioxide Capture Retrofit Options: Duke Edwardsport Integrated-Gasification Combined-Cycle Plant  

Science Conference Proceedings (OSTI)

This report summarizes the results of a project supported by Duke Energy using tailored collaboration funds to study the potential impact to plant performance of retrofitted carbon dioxide (CO2) capture on the Duke Edwardsport integrated-gasificationcombined-cycle (IGCC) plant. The Duke Edwardsport IGCC plant is under construction and scheduled to begin operation in September 2012. Details on the project have been published in a 2010 Electric Power Research Institute (EPRI) report, Duke Edwardsport Gener...

2011-09-27T23:59:59.000Z

303

Program on Technology Innovation: Development of an Integrated Gasification Combined Cycle Performance and Cost Modeling Tool  

Science Conference Proceedings (OSTI)

This report describes the development of an integrated performance and cost model for advanced coal power plant undertaken to enable users to screen technologies prior to engaging in more extensive studies of their preferred choice. Such screening activities generally require utilities to contract with outside engineering firms with access to sophisticated engineering modeling software and experienced staff to perform the studies, thus costing significant time and investment.

2010-12-31T23:59:59.000Z

304

Economic Rationale for Safety Investment in Integrated Gasification Combined-Cycle Gas Turbine Membrane Reactor Modules  

E-Print Network (OSTI)

utilized in the petrochemical,, chemical processing industries as well as natural gas?based power generation, However, their integration represents a fairly recently conceived technology option to produce commercial electricity... . Please notice that after the condensation of steam and given the fact that CO2 is at a high pressure (~25 atm), a significant reduction in the compression costs associated with the operation of the sequestration units downstream...

Koc, Reyyan; Kazantzis, Nikolaos K.; Nuttall, William J.; Ma, Yi Hua

2012-05-09T23:59:59.000Z

305

Integrated gasification combined cycle and steam injection gas turbine powered by biomass joint-venture evaluation  

DOE Green Energy (OSTI)

This report analyzes the economic and environmental potential of biomass integrated gasifier/gas turbine technology including its market applications. The mature technology promises to produce electricity at $55--60/MWh and to be competitive for market applications conservatively estimated at 2000 MW. The report reviews the competitiveness of the technology of a stand-alone, mature basis and finds it to be substantial and recognized by DOE, EPRI, and the World Bank Global Environmental Facility.

Sterzinger, G J [Economics, Environment and Regulation, Washington, DC (United States)

1994-05-01T23:59:59.000Z

306

California's Energy Future - The View to 2050  

E-Print Network (OSTI)

CCS with combustion or gasification of fossil fuels, each ofHigh-efficiency coal gasification, high-efficiency Injectionefficiency, integrated gasification injection systems with

2011-01-01T23:59:59.000Z

307

California’s Energy Future: The View to 2050 - Summary Report  

E-Print Network (OSTI)

CCS with combustion or gasification of fossil fuels, each ofHigh-efficiency coal gasification, high-efficiency Injectionefficiency, integrated gasification injection systems with

Yang, Christopher

2011-01-01T23:59:59.000Z

308

SOFC II  

Science Conference Proceedings (OSTI)

Oct 18, 2010 ... In this presentation, we will report our recent progress in ... The integration of coal gasification with SOFCs is potentially an efficient technology ...

309

Corporate Design PowerPoint-Templates  

Science Conference Proceedings (OSTI)

... All rights reserved Siemens PG/SFC DOE Integrated Coal Gasification Fuel Cell ... Coal Syngas fueled, 100 MWe class fuel cell central station ...

2013-10-27T23:59:59.000Z

310

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

311

A combined reaction class approach with integrated molecular orbital+molecular orbital (IMOMO) methodology: A practical tool for kinetic modeling  

SciTech Connect

We present a new practical computational methodology for predicting thermal rate constants of reactions involving large molecules or a large number of elementary reactions in the same class. This methodology combines the integrated molecular orbital+molecular orbital (IMOMO) approach with our recently proposed reaction class models for tunneling. With the new methodology, we show that it is possible to significantly reduce the computational cost by several orders of magnitude while compromising the accuracy in the predicted rate constants by less than 40% over a wide range of temperatures. Another important result is that the computational cost increases only slightly as the system size increases. (c) 2000 American Institute of Physics.

Truong, Thanh N. [Henry Eyring Center for Theoretical Chemistry, Department of Chemistry, University of Utah, 315 S 1400 E, Room Dock, Salt Lake City, Utah 84112 (United States); Maity, Dilip K. [Henry Eyring Center for Theoretical Chemistry, Department of Chemistry, University of Utah, 315 S 1400 E, Room Dock, Salt Lake City, Utah 84112 (United States); Truong, Thanh-Thai T. [Henry Eyring Center for Theoretical Chemistry, Department of Chemistry, University of Utah, 315 S 1400 E, Room Dock, Salt Lake City, Utah 84112 (United States)

2000-01-01T23:59:59.000Z

312

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

DOE Green Energy (OSTI)

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

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

1982-01-01T23:59:59.000Z

313

Kentucky Pioneer Integrated Gasification Combined Cycle Demonstration Project Draft Environmental Impact Statement  

DOE Green Energy (OSTI)

The Kentucky Pioneer IGCC Demonstration Project DEIS assesses the potential environmental impacts that would result from a proposed DOE action to provide cost-shared financial support for construction and operation of an electrical power station demonstrating use of a Clean Coal Technology in Clark County, Kentucky. Under the Proposed Action, DOE would provide financial assistance, through a Cooperative Agreement with Kentucky Pioneer Energy, LLC, for design, construction, and operation of a 540 megawatt demonstration power station comprised of two synthesis gas-fired combined cycle units in Clark County, Kentucky. The station would also be comprised of a British Gas Lurgi (BGL) gasifier to produce synthesis gas from a co-feed of coal and refuse-derived fuel pellets and a high temperature molten carbonate fuel cell. The facility would be powered by the synthesis gas feed. The proposed project would consist of the following major components: (1) refuse-derived fuel pellets and coal receipt and storage facilities; (2) a gasification plant; (3) sulfur removal and recovery facilities; (4) an air separation plant; (5) a high-temperature molten carbonate fuel cell; and (6) two combined cycle generation units. The IGCC facility would be built to provide needed power capacity to central and eastern Kentucky. At a minimum, 50 percent of the high sulfur coal used would be from the Kentucky region. Two No Action Alternatives are analyzed in the DEIS. Under the No Action Alternative 1, DOE would not provide cost-shared funding for construction and operation of the proposed facility and no new facility would be built. Under the No Action Alternative 2, DOE would not provide any funding and, instead of the proposed demonstration project, Kentucky Pioneer Energy, LLC, a subsidiary of Global Energy, Inc., would construct and operate, a 540 megawatt natural gas-fired power station. Evaluation of impacts on land use, socioeconomics, cultural resources, aesthetic and scenic resources, geology, air resources, water resources, ecological resources, noise, traffic and transportation, occupational and public health and safety, and environmental justice were included in the assessment.

N /A

2001-11-16T23:59:59.000Z

314

Uncertainty analysis of integrated gasification combined cycle systems based on Frame 7H versus 7F gas turbines  

SciTech Connect

Integrated gasification combined cycle (IGCC) technology is a promising alternative for clean generation of power and coproduction of chemicals from coal and other feedstocks. Advanced concepts for IGCC systems that incorporate state-of-the-art gas turbine systems, however, are not commercially demonstrated. Therefore, there is uncertainty regarding the future commercial-scale performance, emissions, and cost of such technologies. The Frame 7F gas turbine represents current state-of-practice, whereas the Frame 7H is the most recently introduced advanced commercial gas turbine. The objective of this study was to evaluate the risks and potential payoffs of IGCC technology based on different gas turbine combined cycle designs. Models of entrained-flow gasifier-based IGCC systems with Frame 7F (IGCC-7F) and 7H gas turbine combined cycles (IGCC-7H) were developed in ASPEN Plus. An uncertainty analysis was conducted. Gasifier carbon conversion and project cost uncertainty are identified as the most important uncertain inputs with respect to system performance and cost. The uncertainties in the difference of the efficiencies and costs for the two systems are characterized. Despite uncertainty, the IGCC-7H system is robustly preferred to the IGCC-7F system. Advances in gas turbine design will improve the performance, emissions, and cost of IGCC systems. The implications of this study for decision-making regarding technology selection, research planning, and plant operation are discussed. 38 refs., 11 figs., 5 tabs.

Yunhua Zhu; H. Christopher Frey [Pacific Northwest National Laboratory, Richland, WA (United States)

2006-12-15T23:59:59.000Z

315

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

316

The U.S. Department of Energy`s integrated gasification combined cycle research, development and demonstration program  

SciTech Connect

Historically, coal has played a major role as a fuel source for power generation both domestically and abroad. Despite increasingly stringent environmental constraints and affordable natural gas, coal will remain one of the primary fuels for producing electricity. This is due to its abundance throughout the world, low price, ease of transport an export, decreasing capital cost for coal-based systems, and the need to maintain fuel diversity. Recognizing the role coal will continue to play, the US Department of Energy (DOE) is working in partnership with industry to develop ways to use this abundant fuel resource in a manner that is more economical, more efficient and environmentally superior to conventional means to burn coal. The most promising of these technologies is integrated gasification combined cycle (IGCC) systems. Although IGCC systems offer many advantages, there are still several hurdles that must be overcome before the technology achieves widespread commercial acceptance. The major hurdles to commercialization include reducing capital and operating costs, reducing technical risk, demonstrating environmental and technical performance at commercial scale, and demonstrating system reliability and operability. Overcoming these hurdles, as well as continued progress in improving system efficiency, are the goals of the DOE IGCC research, development and demonstrate (RD and D) program. This paper provides an overview of this integrated RD and D program and describes fundamental areas of technology development, key research projects and their related demonstration scale activities.

Brdar, R.D.; Cicero, D.C.

1996-07-01T23:59:59.000Z

317

Hydrogen separation by ceramic membranes in coal gasification. Final report  

SciTech Connect

The general objective of this project was to develop hydrogen permselective membranes for hydrogen production from coal gas. The project consisted of the following tasks: (i) membrane preparation and characterization, (ii) membrane stability testing, and (iii) analysis and economic evaluation of a membrane-assisted ammonia from coal process. Several oxides (SiO{sub 2}, TiO{sub 2}, Al{sub 2}O{sub 3}, B{sub 2}O{sub 3}) in dense (or nonporous) form were identified to be permselective to hydrogen at elevated temperatures. To obtain reasonable permeance it is necessary that the membrane consists of a thin selective layer of the dense oxide supported on or within the pores of a porous support tube (or plate). Early in the project we chose porous Vycor tubes (5mm ID, 7 mm OD, 40 {Angstrom} mean pore diameter) supplied by Corning Inc. as the membrane support. To form the permselective layer (SiO{sub 2}, TiO{sub 2}, Al{sub 2}O{sub 3}, B{sub 2}O{sub 3}) we employed chemical vapor deposition using the reaction of the chloride (SiCl{sub 4}, etc.) vapor and water vapor at high temperatures. Deposition of the selective layer was carried out in a simple concentric tube reactor comprising the porous support tube surrounded by a wider concentric quartz tube and placed in an electrically heated split tube furnace. In one deposition geometry (the opposing reactants or two-sided geometry) the chloride vapor in nitrogen carrier was passed through the inner tube while the water vapor also in nitrogen carrier was passed in the same direction through the annulus between the two tubes. In the other (two-sided) geometry the chloride-containing stream and the water-containing stream were both passed through the inner tube or both through the annulus.

Gavalas, G.R.

1993-08-01T23:59:59.000Z

318

High pressure rotary piston coal feeder for coal gasification applications  

DOE Patents (OSTI)

The subject development is directed to an apparatus for feeding pulverized coal into a coal gasifier operating at relatively high pressures and elevated temperatures. This apparatus is a rotary piston feeder which comprises a circular casing having a coal loading opening therein diametrically opposed from a coal discharge and contains a rotatable discoid rotor having a cylinder in which a reciprocateable piston is disposed. The reciprocation of the piston within the cylinder is provided by a stationary conjugate cam arrangement whereby the pulverized coal from a coal hopper at atmospheric pressure can be introduced into the cylinder cavity and then discharged therefrom into the high-pressure gasifier without the loss of high pressure gases from within the latter.

Gencsoy, Hasan T. (Morgantown, WV)

1977-05-24T23:59:59.000Z

319

The ENCOAL Mild Coal Gasification Project, A DOE Assessment  

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

to pursue the higher value CDL (tm) fractions such as crude cresylic acid, petroleum refinery feedstock similar to a petroleum gas oil, oxygenated middle distillate usable as...

320

Solar coal gasification reactor with pyrolysis gas recycle  

DOE Patents (OSTI)

Coal (or other carbonaceous matter, such as biomass) is converted into a duct gas that is substantially free from hydrocarbons. The coal is fed into a solar reactor (10), and solar energy (20) is directed into the reactor onto coal char, creating a gasification front (16) and a pyrolysis front (12). A gasification zone (32) is produced well above the coal level within the reactor. A pyrolysis zone (34) is produced immediately above the coal level. Steam (18), injected into the reactor adjacent to the gasification zone (32), reacts with char to generate product gases. Solar energy supplies the energy for the endothermic steam-char reaction. The hot product gases (38) flow from the gasification zone (32) to the pyrolysis zone (34) to generate hot char. Gases (38) are withdrawn from the pyrolysis zone (34) and reinjected into the region of the reactor adjacent the gasification zone (32). This eliminates hydrocarbons in the gas by steam reformation on the hot char. The product gas (14) is withdrawn from a region of the reactor between the gasification zone (32) and the pyrolysis zone (34). The product gas will be free of tar and other hydrocarbons, and thus be suitable for use in many processes.

Aiman, William R. (Livermore, CA); Gregg, David W. (Morago, CA)

1983-01-01T23:59:59.000Z

Note: This page contains sample records for the topic "integrated coal-gasification combined" 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

Method for increasing steam decomposition in a coal gasification process  

SciTech Connect

The gasification of coal in the presence of steam and oxygen is significantly enhanced by introducing a thermochemical water-splitting agent such as sulfuric acid, into the gasifier for decomposing the steam to provide additional oxygen and hydrogen usable in the gasification process for the combustion of the coal and enrichment of the gaseous gasification products. The addition of the water-splitting agent into the gasifier also allows for the operation of the reactor at a lower temperature.

Wilson, Marvin W. (Fairview, WV)

1988-01-01T23:59:59.000Z

322

Great plains coal gasification plant: Technical lessons learned report  

SciTech Connect

In a first of a kind, grass roots plant of the complexity of the Great Plains Gasification Plant the lessons learned are numerous and encompass a wide range of items. This report documents the lessons learned from all phases of the project from preliminary design through the most recent operation of the plant. Based on these lessons learned, suggestions are made for changes and/or process improvements to future synfuel plants. In addition, recommendations are made for research and development in selected areas. 46 refs., 31 figs., 33 tabs.

Delaney, R.C.; Mako, P.F.

1988-11-01T23:59:59.000Z

323

Financial status of the Great Plains coal gasification project  

Science Conference Proceedings (OSTI)

Great Plains Gasification Associates and the Department of Energy (DOE) signed a loan guarantee agreement in January 1982 for up to $2.02 billion of the estimated $2.76 billion needed to construct a plant producing synthetic gas from coal. Faced with deteriorating financial projections in the wake of declining energy prices, Great Plains applied to the US Synthetic Fuels Corporation (SFC) for additional project assistance. In April 1984 SFC tentatively agreed to provide Great Plains up to $790 million in price guarantee assistance. In return, the Great Plains partners would contribute more equity and Great Plains would repay the DOE-guaranteed loan faster and share profits with SFC. According to GAO's assessment of SFC's proposed assistance, a lower amount of assistance could achieve the same results if Great Plains' partners could fully use certain tax credits and if energy prices and other assumptions remained the same as those SFC used in April 1984. Since April 1984, however, several changes have occurred, such as a continued decline in energy prices. An August 1984 SFC analysis indicated that the decline in energy price offset the effect of the increase tax credits. Other changes have also occurred, but SFC analyses subsequent to August 1984 showing the impact of these changes were not available to GAO. If all changes since April 1984 were incorporated into GAO's analyses, the results could be different.

Not Available

1985-02-21T23:59:59.000Z

324

Economics of the Great Plains coal gasification project  

Science Conference Proceedings (OSTI)

the Great Plains project will be the Nation's first commercial-scale plant producing synthetic gas from coal. The project's first annual economic report, released in March 1983, was much less optimistic than a similar analysis prepared in January 1982 to justify construction. GAO found that: the main reason for the changed economic outlook was that the assumed synthetic gas prices used in the March analysis were significantly lower than those used previously. Great Plains did not, nor was it required to, consider tax implications to the parent companies of the project's partners. If these implications are considered, the economics could be more optimistic than the March 1983 report indicates. Should the partners end their participation, some tax benefits would have to be repaid. Although the project is a potentially attractive investment, its financial viability is extremely sensitive to the future prices of synthetic gas. Even a small deviation in prices could significantly affect its economics.

Not Available

1983-08-24T23:59:59.000Z

325

Status of the Great Plains coal gasification project  

SciTech Connect

ANG has extensive policies and procedures for overseeing the construction of the Great Plains project. Additional management comes from a computerized information system, various audit groups, and staff located at the project site. Neither we nor any other audit group identified significant deficiencies in ANG's computer system or the individual systems which feed into it. Overall, the system contains both automated and manual controls which ensure that the data generated from the system is reliable and accurate. The various audit and evaluation groups provide management continuous and significant information concerning major project components. Great Plains management recognized the usefulness of the information and acted on recommendations made which enhanced its overall effectiveness. ANG established and implemented comprehensive procedures to oversee the project's construction. These procedures appear adequate for managing and controlling all construction activities. For example, ANG's onsite managers have identified problems and suggested actions which ANG believes minimized the effect of these problems on the construction schedule. The Department of Energy has extensive procedures for monitoring this project. With few exceptions, the Department followed the procedures established. It has not, however, completed its audit of incurred costs to determine that loan guarantee funds are spent only for eligible project costs. Such an audit was underway and the Department expected to complete it in 1983.

Not Available

1983-04-08T23:59:59.000Z

326

Financial situation of the Great Plains Coal Gasification Project  

Science Conference Proceedings (OSTI)

GAO reviewed drafts of DOE's National Energy Policy Plan IV, calculated synthetic gas prices using Great Plains methodology, converted those prices to current year dollars, and used DOE's computer model of the project's economics to analyze the cash flow forecast. GAO found both the model and the data produced to be reliable. (PSB)

Not Available

1983-10-17T23:59:59.000Z

327

Synthetic fuels. Status of the Great Plains Coal Gasification Project  

Science Conference Proceedings (OSTI)

This report includes updated information obtained through February 14, 1986, on the loan-default, Great Plains loan and gas pricing formula, legal matters and agreements, the Department of Energy's options and actions, and Great Plains operations. The new information highlights changes in the gas pricing calculations; legal action concerning gas purchase agreements and mortgage foreclosure; the Department's determination of the project sponsors' outstanding liability; the Department's progress in evaluating its options; revenue, expense, production, and plant employment data; capital improvement projects; and plant maintenance issues. Our November fact sheet included information on socioeconomic issues. We have not obtained any additional information on these issues and are, therefore, not repeating the socioeconomic information in this fact sheet.

Not Available

1986-02-01T23:59:59.000Z

328

Hydrogen separation by ceramic membranes in coal gasification  

DOE Green Energy (OSTI)

Project objectives are to develop hydrogen-permselective ceramic membranes for water-gas shift membrane-reactor suitable for hydrogen production from coal gas, and to evaluate the technical and economic potential of the membrane-reactor. Work performed during reporting period included membrane deposition and stability testing.

Gavalas, G.R.

1992-07-08T23:59:59.000Z

329

Hydrogen separation by ceramic membranes in coal gasification  

DOE Green Energy (OSTI)

Project Objectives are to develop hydrogen-permselective ceramic membranes for water-gas shift membrane-reactor suitable for hydrogen production from coal gas and evaluate the technical and economic potential of the membrane-reactor. During the reporting period exploratory experiments begun on a membrane preparation technique aimed at providing higher membrane permeance. The new preparation technique involves two stages. The first stage is the formation of a layer of silica gel by a two-phase interfacial reaction within the pores of the substrate. The gel is then dried and calcined yielding a microporous (pore diameter below 10 [Angstrom]) silica layer within the pores of the substrate tube. The second stage involves one-sided chemical vapor deposition using the SiCl[sub 4]-H[sub 2]O reaction to close up the micropores of the gel layer and produce the final hydrogen permselective membrane. Chemical reactions involved are described.

Gavalas, G.R.

1992-04-30T23:59:59.000Z

330

Coal gasification in China : policies, innovation, and technology transfer.  

E-Print Network (OSTI)

??With its burgeoning energy consumption and emissions of greenhouse gases (GHGs), China is central to addressing the problem of climate change. As the world leader… (more)

Dai, Yue

2013-01-01T23:59:59.000Z

331

DOE/NETL-2002/1164 Wabash River Coal Gasification  

E-Print Network (OSTI)

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 views and opinions of authors expressed therein do not necessarily state or reflect those of the United States Government or any agency

unknown authors

2002-01-01T23:59:59.000Z

332

Subtask 4.2 - Coal Gasification Short Course  

SciTech Connect

Major utilities, independent power producers, and petroleum and chemical companies are intent on developing a fleet of gasification plants primarily because of high natural gas prices and the implementation of state carbon standards, with federal standards looming. Currently, many projects are being proposed to utilize gasification technologies to produce a synthesis gas or fuel gas stream for the production of hydrogen, liquid fuels, chemicals, and electricity. Financing these projects is challenging because of the complexity, diverse nature of gasification technologies, and the risk associated with certain applications of the technology. The Energy & Environmental Research Center has developed a gasification short course that is designed to provide technical personnel with a broad understanding of gasification technologies and issues, thus mitigating the real or perceived risk associated with the technology. Based on a review of research literature, tutorial presentations, and Web sites on gasification, a short course presentation was prepared. The presentation, consisting of about 500 PowerPoint slides, provides at least 7 hours of instruction tailored to an audience's interests and needs. The initial short course is scheduled to be presented September 9 and 10, 2009, in Grand Forks, North Dakota.

Kevin Galbreath

2009-06-30T23:59:59.000Z

333

Method for using fast fluidized bed dry bottom coal gasification  

DOE Patents (OSTI)

Carbonaceous solid material such as coal is gasified in a fast fluidized bed gasification system utilizing dual fluidized beds of hot char. The coal in particulate form is introduced along with oxygen-containing gas and steam into the fast fluidized bed gasification zone of a gasifier assembly wherein the upward superficial gas velocity exceeds about 5.0 ft/sec and temperature is 1500.degree.-1850.degree. F. The resulting effluent gas and substantial char are passed through a primary cyclone separator, from which char solids are returned to the fluidized bed. Gas from the primary cyclone separator is passed to a secondary cyclone separator, from which remaining fine char solids are returned through an injection nozzle together with additional steam and oxygen-containing gas to an oxidation zone located at the bottom of the gasifier, wherein the upward gas velocity ranges from about 3-15 ft/sec and is maintained at 1600.degree.-200.degree. F. temperature. This gasification arrangement provides for increased utilization of the secondary char material to produce higher overall carbon conversion and product yields in the process.

Snell, George J. (Fords, NJ); Kydd, Paul H. (Lawrenceville, NJ)

1983-01-01T23:59:59.000Z

334

Coal Gasification Research, Development and Demonstration- Needs and Opportunities  

E-Print Network (OSTI)

The resolution of the carbon/energy/environment conflict is the key issue for future coalbased power generation. Concern over CO2 emissions and their effect on global climate may lead to a more carbon constrained world and possible CO2 emissions related legislation. This adds another dimension to natural gas/coal strategic planning. Since

unknown authors

2001-01-01T23:59:59.000Z

335

Improving heat capture for power generation in coal gasification plants  

E-Print Network (OSTI)

Improving the steam cycle design to maximize power generation is demonstrated using pinch analysis targeting techniques. Previous work models the steam pressure level in composite curves based on its saturation temperature ...

Botros, Barbara Brenda

2011-01-01T23:59:59.000Z

336

Method for increasing steam decomposition in a coal gasification process  

DOE Patents (OSTI)

The gasification of coal in the presence of steam and oxygen is significantly enhanced by introducing a thermochemical water- splitting agent such as sulfuric acid, into the gasifier for decomposing the steam to provide additional oxygen and hydrogen usable in the gasification process for the combustion of the coal and enrichment of the gaseous gasification products. The addition of the water-splitting agent into the gasifier also allows for the operation of the reactor at a lower temperature.

Wilson, M.W.

1987-03-23T23:59:59.000Z

337

REMOVAL AND RECOVERY OF DEPOSITS FROM COAL GASIFICATION ...  

A method is provided for on-line removal and recovery of deposits from fossil fuel gasification systems to improve plant performance and recover a valuable metalloid.

338

Great Plains Coal Gasification Project. Quarterly technical progress report  

Science Conference Proceedings (OSTI)

Overall, the GPGA facility has performed well, as shown by the production figures. Methanation, product gas compression, oxygen production, phenol recovery, ammonia recovery and the gasifiers are noteworthy examples of units which have been started up and operated with few problems. In other units, significant deficiencies have been uncovered which have required modification. Some of these items had a negative impact on SNG production. Additionally, GPGA undertook a program to improve reliability, safety and reduce odor emissions. Reliable high pressure steam generation is essential for maintaining acceptable plant on-stream factors. Consequently, several projects were undertaken which will improve the safety of operation and firefighting capabilities at the main boiler units. Also, a significant upgrade of the boiler instrumentation was started to ensure good control and operating flexibility. The cooling water system was designed to meet both plant cooling needs and provide treatment of wastewater streams. Plugging of tower packing and heat exchanger tubes, as well as odor emissions resulted from the heavy biological activity in this system. Fine mesh traveling screens, wind wall louvers, ceramic packing, mist eliminators, and exchanger chemical cleaning connections are the notable modifications begun during the period. Due to condensate problems and the greater than expected production of gas liquor, wastewater treatment systems were operated at near capacity. Additional pumping capability, a second deepwell, additional storage ponds, modifications to the evaporator distillate system and the vacuum deaerator are several projects undertaken to reduce loading on the system. The on-stream factor of ash handling has been low due to pluggage problems.

Not Available

1984-12-31T23:59:59.000Z

339

Hydrogen separation by ceramic membranes in coal gasification  

DOE Green Energy (OSTI)

Table 1 lists the support tubes and the deposition reactants and other conditions used to prepare seven membranes. The permeances of these membranes immediately after deposition, after twelve hours of thermal treatment at 700--750{degrees}C, and after thirteen days of additional hydrothermal treatment at 550{degrees}C under 3 atm of water vapor are listed in Table 2. Figure 1 is an Arrhenius plot of the hydrogen permeance of membrane D25 (dimer reactant, 25 A pore support) before and after the hydrothermal treatment. The following conclusions can be drawn from the results of Tables 1 and 2. All membranes prepared in this series underwent hydrothermal treatment with the expected decrease of hydrogen permeance. Using the dimer and trimer precursors resulted in a slight improvement in hydrogen permeance and had no consistent effect on the H{sub 2}:N{sub 2} selectivity. Using the 25 {Angstrom} pore tubes improved moderately the hydrogen permeance but seemingly reduced the selectivity from about 500--1000 to about 200--300. The best permeance was obtained with membrane D25 made with 25 {Angstrom} pore size tubes using the dimer precursor. This tube had hydrogen permeance 0.13 Cm{sup 3}/Cm{sup 2}-min-atm and H{sub 2}:N{sub 2} selectivity of 200 at 500{degrees}C, after the thirteen-day hydrothermal treatment. It must be noted that the measurement of the very small nitrogen permeance is subject to considerable error, especially if there is some small leak in the system. Hence the true N{sub 2} permeances may be considerably lower than the measurements indicate, and the reported selectivities probably significantly underestimate the true selectivities. Figure 1 shows a sharp increase in the activation energy of hydrogen permeance following deposition and hydrothermal treatment.

Gavalas, G.R.

1992-11-01T23:59:59.000Z

340

Development of biological coal gasification (MicGAS Process)  

Science Conference Proceedings (OSTI)

The overall goal of the project is to develop an advanced, clean coal biogasification (MicGAS) Process. The objectives of the research during FY 1993--94 were to: (1) enhance kinetics of methane production (biogasification, biomethanation) from Texas lignite (TxL) by the Mic-1 consortium isolated and developed at ARCTECH, (2) increase coal solids loading, (3) optimize medium composition, and (4) reduce retention time. A closer analysis of the results described here indicate that biomethanation of TxL at >5% solids loading is feasible through appropriate development of nutrient medium and further adaptation of the microorganisms involved in this process. Further understanding of the inhibitory factors and some biochemical manipulations to overcome those inhibitions will hasten the process considerably. Results are discussed on the following: products of biomethanation and enhance of methane production including: bacterial adaptation; effect of nutrient amendment substitutes; effects of solids loading; effect of initial pH of the culture medium; effect of hydrogen donors and carbon balance.

Walia, D.S.; Srivastava, K.C.

1994-10-01T23:59:59.000Z

Note: This page contains sample records for the topic "integrated coal-gasification combined" 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

Mass Balance Results for Pricetown I Underground Coal Gasification  

SciTech Connect

A mass balance model was applied to the Pricetown I test data. This model gave the values of various parameters such as water influx, percent devolatilization, percent gasification, amount of coal affected, thermal efficiency, etc., for the various phases of the test. Both hourly and daily values of the test data were used. At certain times, there was air loss to the coal seam or air gain from the coal seam as related to the underground reactor. Mass balances are modified accordingly. Realistic pyrolysis temperatures have been chosen for the different phases of the test based on the thermocouple responses. The nitrogen and argon balances gave similar results. The mass balance results showed that approximately 702 tons of coal was affected during the test. Approximately 232 tons of coal was completely gasified. The reverse combustion linkage through the virgin coal seam was dominated by the devolatilization and accounted for approximately 80% devoltilization whereas the same accounted for only 26% devolatilization during the gasification phase. During the enhanced linkage phase, the percent devolatilization ranged between that observed for the RCL and gasification phase. There was net influx of water and amounted to 0.59 barrels per ton of coal affected. The percent energy recovery for the gasification phase was 72% based on gas chromatographic data, and accounting the sensible heat of the gas and the latent heat of the water vapor in the gas.

Agarwal, A. K.; Seabaugh, P. W.; Zielinski, R. E.

1979-10-01T23:59:59.000Z

342

Agglomerating combustor-gasifier method and apparatus for coal gasification  

DOE Patents (OSTI)

A method and apparatus for gasifying coal wherein the gasification takes place in a spout fluid bed at a pressure of about 10 to 30 atmospheres and a temperature of about 1800.degree. to 2200.degree.F and wherein the configuration of the apparatus and the manner of introduction of gases for combustion and fluidization is such that agglomerated ash can be withdrawn from the bottom of the apparatus and gas containing very low dust loading is produced. The gasification reaction is self-sustaining through the burning of a stoichiometric amount of coal with air in the lower part of the apparatus to form the spout within the fluid bed. The method and apparatus are particularly suitable for gasifying coarse coal particles.

Chen, Joseph L. P. (Murrysville, PA); Archer, David H. (Pittsburgh, PA)

1976-09-21T23:59:59.000Z

343

NETL: News Release - Another Milestone Reached in Coal Gasification...  

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

Dynamics Geological & Env. Systems Materials Science Contacts TECHNOLOGIES Oil & Natural Gas Supply Deepwater Technology Enhanced Oil Recovery Gas Hydrates Natural Gas Resources...

344

Integrated Gasification Combined Cycle  

E-Print Network (OSTI)

This presentation 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 views and opinions of authors expressed therein do not necessarily state or reflect those of the United States Government or any agency thereof.

Pulverized Coal

2007-01-01T23:59:59.000Z

345

A case history of a coal gasification wastewater cooling tower at the Great Plains coal gasification project  

SciTech Connect

This paper describes the conceptual process design of the Great Plains cooling water system, the fouling history of the cooling tower, and the results of the design modifications. In addition, general design guidelines for future wastewater reuse cooling towers are recommended. By following these guidelines, design engineers can minimize the risk of fouling that could impair a wastewater cooling tower's thermal performance.

Crocker, B.R.; Bromel, M.C.; Pontbriand, M.W.

1987-01-01T23:59:59.000Z

346

Major Demonstrations | Department of Energy  

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

Major Demonstrations Major Demonstrations Major Demonstrations A state-of-the-art integrated coal gasification combined-cycle (IGCC) power plant, Tampa Electric's Polk Power Station produces enough electricity to serve 75,000 homes. A state-of-the-art integrated coal gasification combined-cycle (IGCC) power plant, Tampa Electric's Polk Power Station produces enough electricity to serve 75,000 homes. The Office of Fossil Energy is co-funding large-scale demonstrations of clean coal technologies to hasten their adoption into the commercial marketplace. Through the year 2030, electricity consumption in the United States is expected to grow by about 1 percent per year. The ability of coal-fired generation to help meet this demand could be limited by concerns over greenhouse gas emissions. While the Major Demonstrations performed to date

347

Desiccant-Based Combined Systems: Integrated Active Desiccant Rooftop Hybrid System Development and Testing Final Report- Phase 4  

SciTech Connect

This report summarizes the results of a research and development (R&D) program to design and optimize an active desiccant-vapor compression hybrid rooftop system. The primary objective was to combine the strengths of both technologies to produce a compact, high-performing, energy-efficient system that could accommodate any percentage of outdoor air and deliver essentially any required combination of temperature and humidity, or sensible heat ratio (SHR). In doing so, such a product would address the significant challenges imposed on the performance capabilities of conventional packaged rooftop equipment by standards 62 and 90.1 of the American Society of Heating, Refrigerating and Air-Conditioning Engineers. The body of work completed as part of this program built upon previous R&D efforts supported by the U.S. Department of Energy and summarized by the Phase 3b report ''Active Desiccant Dehumidification Module Integration with Rooftop Packaged HVAC Units'' (Fischer and Sand 2002), in addition to Fischer, Hallstrom, and Sand 2000; Fischer 2000; and Fischer and Sand 2004. All initial design objectives established for this development program were successfully achieved. The performance flexibility desired was accomplished by a down-sized active desiccant wheel that processes only a portion of the supply airflow, which is pre-conditioned by a novel vapor compression cycle. Variable-speed compressors are used to deliver the capacity control required by a system handling a high percentage of outdoor air. An integrated direct digital control system allows for control capabilities not generally offered by conventional packaged rooftop systems. A 3000-cfm prototype system was constructed and tested in the SEMCO engineering test laboratory in Columbia, MO, and was found to operate in an energy-efficient fashion relative to more conventional systems. Most important, the system offered the capability to independently control the supply air temperature and humidity content to provide individual sensible and latent loads required by an occupied space without over-cooling and reheating air. The product was developed using a housing construction similar to that of a conventional packaged rooftop unit. The resulting integrated active desiccant rooftop (IADR) is similar in size to a currently available conventional rooftop unit sized to provide an equivalent total cooling capacity. Unlike a conventional rooftop unit, the IADR can be operated as a dedicated outdoor air system processing 100% outdoor air, as well as a total conditioning system capable of handling any ratio of return air to outdoor air. As part of this R&D program, a detailed investigation compared the first cost and operating cost of the IADR with costs for a conventional packaged approach for an office building located in Jefferson City, MO. The results of this comparison suggest that the IADR approach, once commercialized, could be cost-competitive with existing technology--exhibiting a one-year to two-year payback period--while simultaneously offering improved humidity control, indoor air quality, and energy efficiency.

Fischer, J

2005-05-06T23:59:59.000Z

348

High Temperature Syngas Cleanup Technology Scale-up  

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

RECOVERY ACT: Scale-Up of RECOVERY ACT: Scale-Up of High-Temperature Syngas Cleanup Technology Background Coal gasification generates a synthesis gas (syngas)-predominantly a mixture of carbon monoxide (CO) and hydrogen (H 2 )-that can be used for chemical production of hydrogen, methanol, substitute natural gas (SNG), and many other industrial chemicals, or for electric power generation. Conventional integrated gasification combined cycle (IGCC) power plants use this syngas as a fuel for a combustion

349

Steady-state simulation and optimization of an integrated gasification combined cycle power plant with CO2 capture  

SciTech Connect

Integrated gasification combined cycle (IGCC) plants are a promising technology option for power generation with carbon dioxide (CO2) capture in view of their efficiency and environmental advantages over conventional coal utilization technologies. This paper presents a three-phase, top-down, optimization-based approach for designing an IGCC plant with precombustion CO2 capture in a process simulator environment. In the first design phase, important global design decisions are made on the basis of plant-wide optimization studies with the aim of increasing IGCC thermal efficiency and thereby making better use of coal resources and reducing CO2 emissions. For the design of an IGCC plant with 90% CO2 capture, the optimal combination of the extent of carbon monoxide (CO) conversion in the water-gas shift (WGS) reactors and the extent of CO2 capture in the SELEXOL process, using dimethylether of polyethylene glycol as the solvent, is determined in the first phase. In the second design phase, the impact of local design decisions is explored considering the optimum values of the decision variables from the first phase as additional constraints. Two decisions are made focusing on the SELEXOL and Claus unit. In the third design phase, the operating conditions are optimized considering the optimum values of the decision variables from the first and second phases as additional constraints. The operational flexibility of the plant must be taken into account before taking final design decisions. Two studies on the operational flexibility of the WGS reactors and one study focusing on the operational flexibility of the sour water stripper (SWS) are presented. At the end of the first iteration, after executing all the phases once, the net plant efficiency (HHV basis) increases to 34.1% compared to 32.5% in a previously published study (DOE/NETL-2007/1281; National Energy Technology Laboratory, 2007). The study shows that the three-phase, top-down design approach presented is very useful and effective in a process simulator environment for improving efficiency and flexibility of IGCC power plants with CO2 capture. In addition, the study identifies a number of key design variables that has strong impact on the efficiency of an IGCC plant with CO2 capture.

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

2011-01-01T23:59:59.000Z

350

Recovery, transport, and disposal of CO{sub 2} from an integrated gasification combined-cycle power plant  

SciTech Connect

Initiatives to limit CO{sub 2} emissions have drawn considerable interest to integrated gasification combined-cycle (IGCC) power generation, a process that reduces CO{sub 2} production and is amenable to CO{sub 2} capture. This paper presents a comparison of energy systems that encompass fuel supply, an IGCC system, CO{sub 2} recovery using commercial technologies, CO{sub 2} transport by pipeline, and land-based sequestering in geological reservoirs. The intent is to evaluate the energy efficiency impacts of controlling CO{sub 2} in such a system, and to provide the CO{sub 2} budget, or an equivalent CO{sub 2} budget, associated with each of the individual energy-cycle steps. The value used for the equivalent CO{sub 2} budget is 1 kg CO{sub 2}/kWh. The base case for the comparison is a 458-MW IGCC system using an air-blown Kellogg Rust Westinghouse (KRW) agglomerating fluidized-bed gasifier, Illinois No.6 bituminous coal, and in-bed sulfur removal. Mining, transportation, and preparation of the coal and limestone result in a net electric power production of 448 MW with a 0.872 kg/kWh CO{sub 2} release rate. For comparison, the gasifier output was taken through a water-gas shift to convert CO to CO{sub 2}, and processed in a Selexol unit to recover CO{sub 2} prior to the combustion turbine. A 500-km pipeline then took the CO{sub 2} to geological sequestering. The net electric power production was 383 MW with a 0.218 kg/kWh CO{sub 2} release rate.

Livengood, C.D.; Doctor, R.D.; Molburg, J.C.; Thimmapuram, P.; Berry, G.F.

1993-12-31T23:59:59.000Z

351

EFFECT OF FUEL IMPURITY ON STRUCTURAL INTEGRITY OF Ni-YSZ ANODE OF SOFCs  

SciTech Connect

Electricity production through the integration of coal gasification with solid oxide fuel cells (SOFCs) may potentially be an efficient technique for clean energy generation. However, multiple minor and trace components are naturally present in coals. These impurities in coal gas not only degrade the electrochemical performance of Ni-YSZ anode used in SOFCs, but also severely endanger the structural integrity of the Ni-YSZ anode. In this paper, effect of the trace impurity of the coal syngases on the mechanical degradation of Ni-YSZ anode was studied by using an integrated experimental/modeling approach. Phosphorus is taken as an example of impurity. Anode-support button cell was used to experimentally explore the migration of phosphorous impurity in the Ni-YSZ anode of SOFCs. X-ray mapping was used to show elemental distributions and new phase formation. The subsequent finite element stress analyses were conducted using the actual microstructure of the anode to illustrate the degradation mechanism. It was found that volume expansion induced by the Ni phase change produces high stress level such that local failure of the Ni-YSZ anode is possible under the operating conditions

Liu, Wenning N.; Sun, Xin; Marina, Olga A.; Pederson, Larry R.; Khaleel, Mohammad A.

2011-01-01T23:59:59.000Z

352

18.doc  

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

AN ENVIRONMENTAL ASSESSMENT OF IGCC POWER SYSTEMS AN ENVIRONMENTAL ASSESSMENT OF IGCC POWER SYSTEMS by Jay A. Ratafia-Brown, Lynn M. Manfredo, Jeff W. Hoffmann, Massood Ramezan Science Applications International Corporation and Gary J. Stiegel U.S. DOE/National Energy Technology Laboratory Presented at the Nineteenth Annual Pittsburgh Coal Conference, September 23 - 27, 2002 INTRODUCTION Coal gasification is a well-proven technology that started with the production of coal gas for urban areas, progressed to the production of fuels, such as oil and synthe tic natural gas (SNG), chemicals, and most recently, to large-scale Integrated Gasification Combined Cycle (IGCC) power generation. IGCC is an innovative electric power generation concept that combines modern coal gasification technology with both gas turbine (Brayton cycle) and steam turbine

353

Assembly and Testing of an On-Farm Manure to Energy Conversion BMP for Animal Waste Pollution Control  

E-Print Network (OSTI)

. The capital cost of a coal gasification combined-cycle power plant (without CO2 separation) is estimated estimates are in development. Sequestration of carbon dioxide may mandate the location of gasification power Bank, 1998). Economics The cost of power from a coal gasification power plant is comprised of capital

Wilkins, Neal

354

PEER REVIEW Advanced Thermal Processing Alternatives  

E-Print Network (OSTI)

. The capital cost of a coal gasification combined-cycle power plant (without CO2 separation) is estimated estimates are in development. Sequestration of carbon dioxide may mandate the location of gasification power Bank, 1998). Economics The cost of power from a coal gasification power plant is comprised of capital

Columbia University

355

NATIONAL HYDROGEN ENERGY ROADMAP  

E-Print Network (OSTI)

and replaced by coal gasification with carbon sequestration and, to a lesser extent, by biomass gasification. By 2050, biomass and wind, combined, provide 35% of hydrogen supplies. Hydrogen production from nuclear.energy.gov/hydrogenandfuelcells/posture_plan04.html. sequestration sites opt for more coal gasification while those with ample wind or biomass

356

Major Environmental Aspects of Gasification-Based Power Generation Technologies  

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

Detailed Evaluation of the Environmental Performance of Gasification-Based Power Systems Detailed Evaluation of the Environmental Performance of Gasification-Based Power Systems DECEMBER 2002 U.S. DOE/NETL 2-1 2. DETAILED EVALUATION OF THE ENVIRONMENTAL PERFORMANCE OF GASIFICATION-BASED POWER SYTEMS 2.1 Introduction and Summary of Information Presented The single most compelling reason for utilities to consider coal gasification for electric power generation is superior environmental performance. 1 As shown in Figure 2-1, gasification has fundamental environmental advantages over direct coal combustion. Commercial-scale plants for both integrated gasification combined cycle (IGCC) electric power generation and chemicals applications have already successfully demonstrated these advantages. The superior environmental capabilities of coal gasification apply to all three areas of concern: air emissions,

357

Albany, OR * Anchorage, AK * Morgantown, WV * Pittsburgh, PA * Sugar Land, TX  

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

Technology to Mitigate Syngas Technology to Mitigate Syngas Cooler Fouling Background Coal gasification, in conjunction with integrated gasification combined cycle (IGCC) power production, is under development to increase efficiency and reduce greenhouse gas emissions associated with coal-based power production. However, coal gasification plants have not achieved their full potential for superior performance and economics due to challenges with reliability and availability. In particular, performance of the syngas cooler located downstream of the gasifier has been an issue. The syngas cooler is a fire tube heat exchanger located between the gasifier and the gas turbine. The purpose of the syngas cooler is to cool the raw syngas from the gasifier and recover heat. Although

358

Major Environmental Aspects of Gasification-Based Power Generation Technologies  

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

Detailed Detailed Evaluation of the Environmental Performance of Gasification-Based Power Systems DECEMBER 2002 U.S. DOE/NETL 2-1 2. DETAILED EVALUATION OF THE ENVIRONMENTAL PERFORMANCE OF GASIFICATION-BASED POWER SYTEMS 2.1 Introduction and Summary of Information Presented The single most compelling reason for utilities to consider coal gasification for electric power generation is superior environmental performance. 1 As shown in Figure 2-1, gasification has fundamental environmental advantages over direct coal combustion. Commercial-scale plants for both integrated gasification combined cycle (IGCC) electric power generation and chemicals applications have already successfully demonstrated these advantages. The superior environmental capabilities of coal gasification apply to all three areas of concern: air emissions, water discharges, and solid

359

DKRW Advanced Fuels LLC | Open Energy Information  

Open Energy Info (EERE)

DKRW Advanced Fuels LLC DKRW Advanced Fuels LLC Jump to: navigation, search Name DKRW Advanced Fuels LLC Place Houston, Texas Zip 77056 Product Focues on projects that utilise coal gasification technology, including coal-to-liquids, methanation, and integrated coal gasification combined cycle power projects. Coordinates 29.76045°, -95.369784° Loading map... {"minzoom":false,"mappingservice":"googlemaps3","type":"ROADMAP","zoom":14,"types":["ROADMAP","SATELLITE","HYBRID","TERRAIN"],"geoservice":"google","maxzoom":false,"width":"600px","height":"350px","centre":false,"title":"","label":"","icon":"","visitedicon":"","lines":[],"polygons":[],"circles":[],"rectangles":[],"copycoords":false,"static":false,"wmsoverlay":"","layers":[],"controls":["pan","zoom","type","scale","streetview"],"zoomstyle":"DEFAULT","typestyle":"DEFAULT","autoinfowindows":false,"kml":[],"gkml":[],"fusiontables":[],"resizable":false,"tilt":0,"kmlrezoom":false,"poi":true,"imageoverlays":[],"markercluster":false,"searchmarkers":"","locations":[{"text":"","title":"","link":null,"lat":29.76045,"lon":-95.369784,"alt":0,"address":"","icon":"","group":"","inlineLabel":"","visitedicon":""}]}

360

Technical Support for the Development of the U.S. Department of Energy's Integrated Gasification Combined Cycle Dynamic Training Sim ulator  

Science Conference Proceedings (OSTI)

Integrated-gasification-combined-cycle (IGCC) is one technology option from the next generation of coal-fired power plants with high efficiency and near-zero emissions that has been evaluated by major utilities and developers for baseload capacity additions. The increased attention to IGCC power generation has created a growing demand for experience with the analysis, operation, and control of commercial-scale IGCC plants. To meet this need, DOE’s National Energy Technology Laboratory (NETL) has led a pr...

2011-06-28T23:59:59.000Z

Note: This page contains sample records for the topic "integrated coal-gasification combined" 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

Combination of job oriented simulation with ecological material flow analysis as integrated analysis tool for business production processes  

Science Conference Proceedings (OSTI)

This paper outlines the application of a special Environmental Management Information System (EMIS) as combination of discrete event simulation with ecological material flow analysis for a selected production process. The software tool serves as decision ...

Philip Joschko; Bernd Page; Volker Wohlgemuth

2009-12-01T23:59:59.000Z

362

ENHANCED HYDROGEN PRODUCTION INTEGRATED WITH CO2 SEPARATION IN A SINGLE-STAGE REACTOR  

DOE Green Energy (OSTI)

The water gas shift reaction (WGSR) plays a major role in increasing the hydrogen production from fossil fuels. However, the enhanced hydrogen production is limited by thermodynamic constrains posed by equilibrium limitations of WGSR. This project aims at using a mesoporous, tailored, highly reactive calcium based sorbent system for incessantly removing the CO{sub 2} product which drives the equilibrium limited WGSR forward. In addition, a pure sequestration ready CO{sub 2} stream is produced simultaneously. A detailed project vision with the description of integration of this concept with an existing coal gasification process for hydrogen production is presented. Conceptual reactor designs for investigating the simultaneous water gas shift and the CaO carbonation reactions are presented. In addition, the options for conducting in-situ sorbent regeneration under vacuum or steam are also reported. Preliminary, water gas shift reactions using high temperature shift catalyst and without any sorbent confirmed the equilibrium limitation beyond 600 C demonstrating a carbon monoxide conversion of about 80%. From detailed thermodynamic analyses performed for fuel gas streams from typical gasifiers the optimal operating temperature range to prevent CaO hydration and to effect its carbonation is between 575-830 C.

Himanshu Gupta; Mahesh Iyer; Bartev Sakadjian; Liang-Shih Fan

2005-03-10T23:59:59.000Z

363

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

364

Integrating catalytic coal gasifiers with solid oxide fuel cells  

Science Conference Proceedings (OSTI)

A review was conducted for coal gasification technologies that integrate with solid oxide fuel cells (SOFC) to achieve system efficiencies near 60% while capturing and sequestering >90% of the carbon dioxide [1-2]. The overall system efficiency can reach 60% when a) the coal gasifier produces a syngas with a methane composition of roughly 25% on a dry volume basis, b) the carbon dioxide is separated from the methane-rich synthesis gas, c) the methane-rich syngas is sent to a SOFC, and d) the off-gases from the SOFC are recycled back to coal gasifier. The thermodynamics of this process will be reviewed and compared to conventional processes in order to highlight where available work (i.e. exergy) is lost in entrained-flow, high-temperature gasification, and where exergy is lost in hydrogen oxidation within the SOFC. The main advantage of steam gasification of coal to methane and carbon dioxide is that the amount of exergy consumed in the gasifier is small compared to conventional, high temperature, oxygen-blown gasifiers. However, the goal of limiting the amount of exergy destruction in the gasifier has the effect of limiting the rates of chemical reactions. Thus, one of the main advantages of steam gasification leads to one of its main problems: slow reaction kinetics. While conventional entrained-flow, high-temperature gasifiers consume a sizable portion of the available work in the coal oxidation, the consumed exergy speeds up the rates of reactions. And while the rates of steam gasification reactions can be increased through the use of catalysts, only a few catalysts can meet cost requirements because there is often significant deactivation due to chemical reactions between the inorganic species in the coal and the catalyst. Previous research into increasing the kinetics of steam gasification will be reviewed. The goal of this paper is to highlight both the challenges and advantages of integrating catalytic coal gasifiers with SOFCs.

Siefert, N.; Shamsi, A.; Shekhawat, D.; Berry, D.

2010-01-01T23:59:59.000Z

365

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

366

Investigation of gasification chemical looping combustion combined cycle performance  

SciTech Connect

A novel combined cycle based on coal gasification and chemical looping combustion (CLC) offers a possibility of both high net power efficiency and separation of the greenhouse gas CO{sub 2}. The technique involves the use of a metal oxide as an oxygen carrier, which transfers oxygen from the combustion air to the fuel, and the avoidance of direct contact between fuel and combustion air. The fuel gas is oxidized by an oxygen carrier, an oxygen-containing compound, in the fuel reactor. The oxygen carrier in this study is NiO. The reduced oxygen carrier, Ni, in the fuel reactor is regenerated by the air in the air reactor. In this way, fuel and air are never mixed, and the fuel oxidation products CO{sub 2} and water vapor leave the system undiluted by air. All that is needed to get an almost pure CO{sub 2} product is to condense the water vapor and to remove the liquid water. When the technique is combined with gas turbine and heat recovery steam generation technology, a new type of combined cycle is formed which gives a possibility of obtaining high net power efficiency and CO{sub 2} separation. The performance of the combined cycle is simulated using the ASPEN software tool in this paper. The influence of the water/coal ratio on the gasification and the influence of the CLC process parameters such as the air reactor temperature, the turbine inlet supplementary firing, and the pressure ratio of the compressor on the system performance are discussed. Results show that, assuming an air reactor temperature of 1200{sup o}C, a gasification temperature of 1100 {sup o}C, and a turbine inlet temperature after supplementary firing of 1350{sup o}C, the system has the potential to achieve a thermal efficiency of 44.4% (low heating value), and the CO{sub 2} emission is 70.1 g/(kW h), 90.1% of the CO{sub 2} captured. 22 refs., 7 figs., 6 tabs.

Wenguo Xiang; Sha Wang; Tengteng Di [Southeast University, Nanjing (China). Key Laboratory of Clean Coal Power Generation and Combustion Technology of the Ministry of Education

2008-03-15T23:59:59.000Z

367

Advanced Integrated Systems Technology Development  

E-Print Network (OSTI)

Research Energy Systems Integration Environmentallyenergy use, combined with the capability of the BMS system, including alarms to identify anomalies. Integration

2013-01-01T23:59:59.000Z

368

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

369

Council Brief Photo: Ralph Perry, 1982.  

E-Print Network (OSTI)

. Coal Gasification Combined Cycle Plant Costs and Other Parameters simulated operations solely on the basis of minimizing cost. Elfin now estimates prevailing pool prices, including an energy payment to generators, and iteratively estimated payments to committed generators

370

Conceptual Design of Optimized Fossil Energy Systems with Capture and Sequestration of Carbon Dioxide  

E-Print Network (OSTI)

from a KRW Oxygen Blown Gasification Combined Cycle System,”or syngas) is produced via gasification of coal or steamCO 2 sequestration Coal gasification with and without CO 2

Ogden, Joan

2004-01-01T23:59:59.000Z

371

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

372

APPLICATION OF A DAMPED LOCALLY OPTIMIZED COMBINATION OF IMAGES METHOD TO THE SPECTRAL CHARACTERIZATION OF FAINT COMPANIONS USING AN INTEGRAL FIELD SPECTROGRAPH  

Science Conference Proceedings (OSTI)

High-contrast imaging instruments are now being equipped with integral field spectrographs (IFSs) to facilitate the detection and characterization of faint substellar companions. Algorithms currently envisioned to handle IFS data, such as the Locally Optimized Combination of Images (LOCI) algorithm, rely on aggressive point-spread function (PSF) subtraction, which is ideal for initially identifying companions but results in significantly biased photometry and spectroscopy owing to unwanted mixing with residual starlight. This spectrophotometric issue is further complicated by the fact that algorithmic color response is a function of the companion's spectrum, making it difficult to calibrate the effects of the reduction without using iterations involving a series of injected synthetic companions. In this paper, we introduce a new PSF calibration method, which we call 'damped LOCI', that seeks to alleviate these concerns. By modifying the cost function that determines the weighting coefficients used to construct PSF reference images, and also forcing those coefficients to be positive, it is possible to extract companion spectra with a precision that is set by calibration of the instrument response and transmission of the atmosphere, and not by post-processing. We demonstrate the utility of this approach using on-sky data obtained with the Project 1640 IFS at Palomar. Damped LOCI does not require any iterations on the underlying spectral type of the companion, nor does it rely on priors involving the chromatic and statistical properties of speckles. It is a general technique that can readily be applied to other current and planned instruments that employ IFSs.

Pueyo, Laurent [Department of Physics and Astronomy, Johns Hopkins University, 366 Bloomberg Center, 3400 N. Charles Street, Baltimore, MD 21218 (United States); Crepp, Justin R.; Hinkley, Sasha; Hillenbrand, Lynne; Dekany, Richard; Bouchez, Antonin; Roberts, Jenny [California Institute of Technology, 1200 E. California Blvd., Pasadena, CA 91125 (United States); Vasisht, Gautam; Roberts, Lewis C.; Shao, Mike; Burruss, Rick [Jet Propulsion Laboratory, California Institute of Technology, 4800 Oak Grove Drive, Pasadena, CA 91109 (United States); Brenner, Douglas; Oppenheimer, Ben R.; Zimmerman, Neil [American Museum of Natural History, Central Park West at 79th Street, New York, NY 10024 (United States); Parry, Ian [Institute of Astronomy, University of Cambridge, Madingley Rd., Cambridge, CB3 0HA (United Kingdom); Beichman, Charles [NASA Exoplanet Science Institute, 770 S. Wilson Avenue, Pasadena, CA 91225 (United States); Soummer, Remi, E-mail: lap@pha.jhu.edu [Space Telescope Science Institute, 3700 San Marin Drive, Baltimore, MD 21218 (United States)

2012-03-01T23:59:59.000Z

373

Enhanced Hydrogen Production Integrated with CO2 Separation in a Single-Stage Reactor  

DOE Green Energy (OSTI)

Hydrogen production from coal gasification can be enhanced by driving the equilibrium limited Water Gas Shift reaction forward by incessantly removing the CO{sub 2} by-product via the carbonation of calcium oxide. This project uses the high-reactivity mesoporous precipitated calcium carbonate sorbent for removing the CO{sub 2} product to enhance H{sub 2} production. Preliminary experiments demonstrate the show the superior performance of the PCC sorbent over other naturally occurring calcium sorbents. It was observed that the CO{sub 2} released during the in-situ calcination causes the deactivation of the iron oxide WGS catalyst by changing the active phase of the catalyst from magnetite (F{sub 3}O{sub 4}). Detailed understanding of the iron oxide phase diagram helped in developing a catalyst pretreatment procedure using a H{sub 2}/H{sub 2}O system. Intermediate catalyst pretreatment helps prevent its deactivation by reducing the catalyst back to its active magnetite (Fe{sub 3}O{sub 4}) form. Multicyclic runs which consist of combined WGS/carbonation reaction followed by in-situ calcination with a subsequent catalyst pretreatment procedure sustains the catalytic activity and prevents deactivation. The water gas shift reaction was studied at different temperatures, different steam to carbon monoxide ratios (S/C) 3:1, 2:1, 1:1 and different total pressures ranging from 0-300 psig. The CO conversion was found to have an optimal value with increasing pressure, S/C ratio and temperatures. The combined water gas shift and carbonation reaction was investigated at 650 C, S/C ratio of 3:1and at different pressures of 0-300 psig.

Mahesh Iyer; Shwetha Ramkumar; Liang-Shih Fan

2006-03-31T23:59:59.000Z

374

June 2005 Pub_v2  

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

June 2005 June 2005 *Sequestration in the News *Recent Publications *Events and Announcements *Legislative Activity Sequestration in the News New York Times, "Dirty Secret: Coal Plants Could Be Much Cleaner." Article discusses integrated coal gasification combined cycle (IGCC) technology. No new IGCC power plants have been built in the U.S. since the Tampa Electric plant was commissioned nearly a decade ago, and nine out of ten coal-fired power plants in the planning stages will use combustion technology. The National Commission on Energy Policy, an independent, bipartisan advisory body, has recommended that the federal government spend an additional $4 billion over 10 years to speed the power industry's

375

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

376

Measurement and modeling of advanced coal conversion processes, Volume I, Part 1. Final report, September 1986--September 1993  

Science Conference Proceedings (OSTI)

The objective of this program was the development of a predictive capability for the design, scale up, simulation, control and feedstock evaluation in advanced coal conversion devices. The foundation to describe coal specific conversion behavior was AFR`s Functional Group and Devolatilization, Vaporization and Crosslinking (DVC) models, which had been previously developed. The combined FG-DVC model was integrated with BYU`s comprehensive two-dimensional reactor model for combustion and coal gasification, PCGC-2, and a one-dimensional model for fixed-bed gasifiers, FBED-1. Progress utilizing these models is described.

Solomon, P.R.; Serio, M.A.; Hamblen, D.G. [and others

1995-09-01T23:59:59.000Z

377

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

378

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

SciTech Connect

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

NONE

1996-07-01T23:59:59.000Z

379

Cool water demonstration project and its industrial applications  

SciTech Connect

This paper discusses the 100 MW coal gasification combined cycle demonstration project underway at the ''Cool Water'' site of Southern California Edison Company, including the technology, project participants, schedule and opportunities for future industrial users. Industrial applications with multiple product outputs, termed ''polygeneration'', are illustrated with examples for cogeneration and trigeneration. Finally, actions required for planning large-sized gas turbine installations are suggested for today in order to hold open the future options in coal gasification.

Alger, J.; Ahner, D.J.

1982-08-01T23:59:59.000Z

380

Enhanced Hydrogen Production Integrated with CO2 Separation in a Single-Stage  

DOE Green Energy (OSTI)

Enhancement in the production of high purity hydrogen from fuel gas, obtained from coal gasification, is limited by thermodynamics of the Water Gas Shift Reaction. However, this constraint can be overcome by concurrent water-gas shift (WGS) and carbonation reactions to enhance H{sub 2} production by incessantly driving the equilibrium-limited WGS reaction forward and in-situ removing the CO2 product from the gas mixture. The spent sorbent is then regenerated by calcining it to produce a pure stream of CO{sub 2} and CaO which can be reused. However while performing the cyclic carbonation and calcination it was observed that the CO{sub 2} released during the in-situ calcination causes the deactivation of the iron oxide WGS catalyst. Detailed understanding of the iron oxide phase diagram helped in developing a catalyst pretreatment procedure using a H{sub 2}/H{sub 2}O system to convert the deactivated catalyst back to its active magnetite (Fe{sub 3}O{sub 4}) form. The water gas shift reaction was studied at different temperatures, different steam to carbon monoxide ratios (S/C) 3:1, 2:1, 1:1 and different total pressures ranging from 0-300 psig. The combined water gas shift and carbonation reaction was investigated at temperatures ranging from 600-700C, S/C ratio of 3:1 to 1:1 and at different pressures of 0-300 psig and the calcium looping process was found to produce high purity hydrogen with in-situ CO{sub 2} capture.

Mahesh Iyer; Shwetha Ramkumar; Liang-Shih Fan

2006-09-30T23:59:59.000Z

Note: This page contains sample records for the topic "integrated coal-gasification combined" 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

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

382

SOLVENT EXTRACTION OF PHENOLS FROM WATER  

E-Print Network (OSTI)

Shale Retorting, Synthane Coal Gasification and COED CoalBeychok, M.R. , "Coal Gasification and the Phenosolvanwaters formed during coal gasification and liquefaction (Ho,

Greminger, Douglas C.

2012-01-01T23:59:59.000Z

383

THE EROSION BEHAVIOR OF STEEL AS A FUNCTION OF MICROSTRUCTURE ON SOLID PARTICLE EROSION  

E-Print Network (OSTI)

Erosion Problems in Coal Gasification Processes, Speechsystems, especially coal gasification and liquefaction. 5been observed in coal gasification pilot plants caused by

Levy, Alan V.

2013-01-01T23:59:59.000Z

384

ELEVATED TEMPERATURE CORROSION BEHAVIOR OF IRON-BASE TERNARY ALLOYS THAT DEVELOP Cr2O3 AND/OR Al2O3 BARRIER SCALES  

E-Print Network (OSTI)

Resistant Alloy for Coal Gasification Service, LockheedI.M. , Table H Coal gasification atmosphere (mol fraction).development of "coal gasification" processes. large number

Nagarajan, V.

2011-01-01T23:59:59.000Z

385

Optimal Dynamic Strategy of Building a Hydrogen Infrastructure in Beijing  

E-Print Network (OSTI)

central plant, coal gasification central plant (with andinfrastructure of 2 coal gasification plants, 350km pipelinestep central plant via coal gasification with CO2 capture,

Lin, Zhenhong; Ogden, Joan M; Fan, Yueyue; Sperling, Dan

2005-01-01T23:59:59.000Z

386

Novel Regenerated Solvent Extraction Processes for the Recovery of Carboxylic Acids or Ammonia from Aqueous Solutions Part II. Recovery of Ammonia from Sour Waters  

E-Print Network (OSTI)

and other Gases for Coal-Gasification Processes", Chemicalof Liquid Effluents from Coal Gasification Plants", Economicand other Gases for Coal-Gasification Processes", Chemical

Poole, L.J.

2008-01-01T23:59:59.000Z

387

Novel heat pipe combination  

SciTech Connect

The basic heat pipe principle is employed in a heat pipe combination wherein two heat pipes are combined in opposing relationship to form an integral unit; such that the temperature, heat flow, thermal characteristics, and temperature-related parameters of a monitored environment or object exposed to one end of the heat pipe combination can be measured and controlled by controlling the heat flow of the opposite end of the heat pipe combination.

Arcella, F.G.

1978-01-10T23:59:59.000Z

388

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

389

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

390

Theoretical and experimental studies of fixed-bed coal gasification reactors. Final report  

Science Conference Proceedings (OSTI)

A laboratory fixed-bed gasification reactor was designed and built with the objective of collecting operational data for model validation and parameter estimation. The reactor consists of a 4 inch stainless steel tube filled with coal or char. Air and steam is fed at one end of the reactor and the dynamic progress of gasification in the coal or char bed is observed through thermocouples mounted at various radial and axial locations. Product gas compositions are also monitored as a function of time. Results of gasification runs using Wyoming coal are included in this report. In parallel with the experimental study, a two-dimensional model of moving bed gasifiers was developed, coded into a computer program and tested. This model was used to study the laboratory gasifier by setting the coal feed rate equal to zero. The model is based on prior work on steady state and dynamic modeling done at Washington University and published elsewhere in the literature. Comparisons are made between model predictions and experimental results. These are also included in this report. 23 references, 18 figures, 6 tables.

Joseph, B.; Bhattacharya, A.; Salam, L.; Dudukovic, M.P.

1983-09-01T23:59:59.000Z

391

Fluidized-bed catalytic coal-gasification process. [US patent; pretreatment to minimize agglomeration  

DOE Patents (OSTI)

Coal or similar carbonaceous solids impregnated with gasification catalyst constituents are oxidized by contact with a gas containing between 2 vol % and 21 vol % oxygen at a temperature between 50 and 250/sup 0/C in an oxidation zone and the resultant oxidized, catalyst impregnated solids are then gasified in a fluidized bed gasification zone at an elevated pressure. The oxidation of the catalyst impregnated solids under these conditions insures that the bed density in the fluidized bed gasification zone will be relatively high even though the solids are gasified at elevated pressure and temperature.

Euker, C.A. Jr.; Wesselhoft, R.D.; Dunkleman, J.J.; Aquino, D.C.; Gouker, T.R.

1981-09-14T23:59:59.000Z

392

ANG coal gasification project management control system report. [Great Plains project  

Science Conference Proceedings (OSTI)

Much time, money and effort has been spent in the forefront of this project for project controls. The work breakdown structure for the systems has been custom designed. The systems, both manual and computerized, have been well scrutinized and chosen by ANG to represent the most cost effective and efficient way of controlling a project the magnitude of $1.5 billion. These systems have been developed in a manner so that information can be gathered as detailed or as summarized as necessary, and in the most timely and expeditious ways.

Not Available

1981-01-01T23:59:59.000Z

393

Case-study of a coal gasification-based energy supply system for China  

E-Print Network (OSTI)

for biogas or DME, so we assumed the same values for biogas as for coke oven gas (i.e., town gas coal, washed coal and coke, 75 % for petroleum products and town gas, and 90 % for heat. We also synthesis gas and elec- tricity, high-value-added chemicals, high-value-added fu- els for vehicles

394

Great Plains Coal Gasification Plant start-up and modification report. [Lurgi Process  

SciTech Connect

This report will help in designing future coal conversion plants by documenting the areas which need additional research to obtain more reliable process data, more careful planning and equipment selection. The scope of this report is to: describe the problem with the particular process or item of equipment; identify the modification that was implemented to correct the problem; evaluate the impacts of the modification; and document the cost of the modification. Contents include the following: (1) process modifications (coal, oxygen and steam, gasification and gas processing, sulfur recovery, flare system, liquid processing, ash handling and solids disposal, other systems); (2) start-up schedule; (3) SNG production; (4) environmental data; and (5) cost data.

Miller, W.R.; Honea, F.I.; Lang, R.A.; Berty, T.E.; Delaney, R.C.; Hospodarec, R.W.; Mako, P.F.

1986-03-01T23:59:59.000Z

395

(Great Plains Coal Gasification project): Quarterly environmental, safety, medical, and industrial hygiene report, First quarter, 1987  

Science Conference Proceedings (OSTI)

ANG continued permitting activity during the reporting period. ANG conducted eight monitoring programs in the vicinity of the Great Plains facility. The RAMP network consists of five monitoring sites, and is designed to monitor meteorology and air quality in the vicinity of the Great Plains facility, and the Antelope Valley and Coyote electric generating stations. There were no exceedences of applicable state or federal standards for SO/sub 2/, NO/sub 2/, TSP, or ozone. ANG conducts ambient monitoring for H/sub 2/S at one site in the vicinity of the Great Plains facility. ANG conducts additional ambient monitoring for SO/sub 2/ at two sites in order to ensure that ambient air quality standards are not violated. ANG conducts groundwater monitoring programs associated with desulfurization waste disposal, deepwell injection, RCRA-compliance monitoring, gasifier ash disposal, and the surge ponds. Major activities on each program are summarized. ANG conducted six monitoring programs associated with process and effluent streams at the Great Plains facility to satisfy conditions in federal and state permits. The Continuous Emission Monitoring system is designed to provide for the continuous monitoring of emissions and fuel usage from all major fuel burning sources in the Great Plains facility. ANG conducts a comprehensive program to locate, characterize and eliminate objectionable odors. A total of thirty-three plant boundary surveys and sixty off-site surveys were conducted. Odors were detected at levels of two odor units or less approximately 81.7% of the time at distances up to 6 miles downwind during the off-site surveys. A total of nine odor complaints were received. To evaluate overall performance of pollution control systems, ANG examines selected process data and conducts periodic compliance and/or performance tests. 18 figs., 23 tabs.

Not Available

1987-04-01T23:59:59.000Z

396

Evaluation of the Stretford Unit at the Great Plains Coal Gasification Plant  

SciTech Connect

This report gives the results of an evaluation of the design and operational characteristics of the Stretford Sulfur Recovery Unit installed in the Great Plains Gasification Project, Beulah, North Dakota. The report contains discussion of the H/sub 2/S removal capability of the unit, the potential of solids deposition and the expected solution losses. 11 refs., 7 figs., 2 tabs.

Lang, R.A.

1984-12-01T23:59:59.000Z

397

(Great Plains Coal Gasification project): Quarterly environmental, safety, medical, and industrial hygiene report, fourth quarter 1986  

SciTech Connect

Contents of this quarterly report include: (1) environmental monitoring program; (2) supplemental environmental program; (3) quality assurance/quality control activities; (4) schedule of activities for next reporting period; (5) safety; (6) medical services; and (7) industrial hygiene. The environmental monitoring program covers: permitting activities; ambient monitoring; plant discharge monitoring; pollution control unit emissions; surface mining and reclamation; environmental incident summary; and regulatory environmental inspections. Supplemental environmental program includes: performance survey; toxicity screening study; data base management system; epidemiology; and contingency program.

Not Available

1987-01-01T23:59:59.000Z

398

Planning and initiation of detailed engineering design for the Great Plains coal gasification project. Final report  

Science Conference Proceedings (OSTI)

During the course of detailed engineering it was expected that preliminary engineering documents would need to be modified. In a number of instances, however, especially for flow diagrams and specifications, the revised preliminary engineering documents became the final approved for construction (AFC) documents. P and ID's and plot plans were updated as a result of the detailed piping design. Equipment data sheets which initially contained basic process data were made mechanically complete and then further updated to reflect the equipment actually purchased. The initial issue of the preliminary engineering documents represent a necessary baseline for monitoring project design changes. Foundation work, equipment specifications and status of engineering in the various process operations are discussed.

Not Available

1980-01-01T23:59:59.000Z

399

Great Plains Coal Gasification project. Quarterly environmental report, third quarter, 1985  

Science Conference Proceedings (OSTI)

Environmental monitoring, supplemental environmental programs and quality assurance/quality control activities are covered in this quarterly report. Under the environmental monitoring program, the following topics are covered: permitting activities; ambient monitoring; plant discharge monitoring; pollution control unit emissions; surface mining and reclamation; and environmental incident summary. The supplemental environmental program covers: performance survey; wastewater control and steam generation system; sulfur control; tar reinjection outage; gasifier effluent control systems; toxicity screening study; toxicant characterization; data base management system; workplace characterization; fugitive emissions; epidemiology; atmospheric program; effects of cooling tower effluents on terrestial ecosystems; and contingency program. 15 figs., 56 tabs.

Not Available

1985-10-01T23:59:59.000Z

400

Great Plains Coal Gasification project. Quarterly technical progress report, third quarter 1985  

Science Conference Proceedings (OSTI)

The operations of the Great Plains Gasification Plant are reported for the third quarter of 1985. Contents include the following: (1) lignite coal production; (2) SNG production; (3) SNG gas quality; (4) by-products production and inventories; (5) on-stream factors; (6) raw material, product and by-product consumption and energy consumption for plant operations; (7) plant modifications-1985; (8) plant maintenance; (9) safety; (10) industrial hygiene; (11) medical services; (12) environmental; and (13) quality assurance/quality control activities.

Not Available

1985-10-31T23:59:59.000Z

Note: This page contains sample records for the topic "integrated coal-gasification combined" 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

Great Plains Coal Gasification Project. Quarterly environmental report, second quarter, 1986  

Science Conference Proceedings (OSTI)

Following the executive summary, this quarterly report includes environmental monitoring program, supplemental environmental program, and quality assurance/quality control activities. Under the environmental monitoring program, the following topics are covered: permiting activities; ambient monitoring; plant discharge monitoring; pollution control unit emissions; surface mining and reclamation; environmental incident summary; and regulatory environmental inspections. The supplemental environmental program includes: performance survey; toxicity screening study; data base management system; epidemiology; and contingency program. (AT)

Not Available

1986-07-01T23:59:59.000Z

402

(Great Plains Coal Gasification Project): Quarterly environmental, safety, and medical report, first quarter 1988  

Science Conference Proceedings (OSTI)

The following brief synopsis is provided of the status of Environmental, Safety and Medical Programs described in the First Quarter 1988 Report. Tabular summaries of environmental QA/QC results and planned next quarter activities are presented in Sections 2.0 and 3.0, respectively. ANG continued permitting activity during the reporting period. These activities include reviewing the revised RCRA Part B application; receiving approval to discharge high temperature, low pressure steam condensate to the stormwater system; receiving approval to expand the current gasifier ash pit; submitting the results of the EPA laboratory audit samples; finalizing the contract for the Deepwell No. 1 and No. 2 work to comply with UIC-101; monitoring the progress of the cooling tower surge pond B liner leaks; receiving approval to delete several parameters in the Interim Groundwater Monitoring Plan; responding to an EPA Hazardous Waste Questionnaire and a CERCLA site assessment for DOE; submitting the DOE-assigned section for the Modified Permit Application; and submitting the first annual chemical inventory report to comply with Section 312 of SARA. ANG conducted eight monitoring programs in the vicinity of the Great Plains facility. The RAMP network consists of five monitoring sites, and it is designed to monitor meteorology and air quality in the vicinity of the Great Plains facility and the Antelope Valley and Coyote electric generating stations. ANG conducts ambient monitoring for H/sub 2/S at one site in the vicinity of the Great Plains facility. 15 figs., 49 tabs.

Not Available

1988-05-01T23:59:59.000Z

403

Great Plains Coal Gasification project. Quarterly technical progress report fourth quarter, 1985  

SciTech Connect

The operations of the Great Plains Gasification plant are reported for the fourth quarter of 1985. Contents include the following: (1) lignite coal production; (2) SNG production; (3) SNG gas quality; (4) by-products production and inventories; (5) on-stream factors; (6) raw material, product and by-product consumption and energy consumption for plant operations; (7) plant modifications - 1985; (8) plant maintenance; (9) safety; (10) industrial hygiene; (11) medical service; (12) environmental; and (13) quality assurance/quality control activities.

Not Available

1986-01-31T23:59:59.000Z

404

Great Plains coal gasification project. Quarterly technical progress report, first quarter 1986. [Lurgi Process  

SciTech Connect

Environmental monitoring, supplemental enviornmental programs, and quality assurance/quality control activities are covered in this quarterly report. Under the environmental monitoring program, the following topics are covered: permitting activities; ambient monitoring; plant discharge monitoring; pollution control unit emissions; surface mining and reclamation; environmental incident summary; and regulatory environmental inspections. The supplemental environmental program covers: performance survey; wastewater control and steam generation system; sulfur control; tar reinjection outage; gasifier effluent control system; toxicity screening study; toxicant characterization; data base management system; workplace characterization; fugitive emissions; epidemiology; atmospheric program; effects of cooling tower effluents on terrestrial ecosystems; and contingency program.

Not Available

1986-04-01T23:59:59.000Z

405

Great Plains Coal Gasification Project. Quarterly environmental report, fourth quarter 1985  

Science Conference Proceedings (OSTI)

Environmental monitoring, supplemental environmental programs and quality assurance/quality control activities are covered in this quarterly report. Under the environmental monitoring program, the following topics are covered: permitting activities; ambient monitoring; plant discharge monitoring; pollution control unit emissions; surface mining and reclamation; and environmental incident summary. The supplemental environmental program covers: performance survey; wastewater control and steam generation systems; sulfur control; tar reinjection outage; gasifier effluent control systems; toxicity screening study; toxicant characterization; data base management system; workplace characterization; fugitive emissions; epidemiology; atmospheric program; effects of cooling tower effluents on terrestial ecosystems and contingency program. 14 figs., 66 tabs.

Not Available

1986-01-01T23:59:59.000Z

406

(Great Plains coal gasification project): Quarterly environmental report, Third quarter 1986  

Science Conference Proceedings (OSTI)

Environmental monitoring, supplemental environmental programs and quality assurance/quality control activities are presented in this quarterly report. Under the environmental monitoring program, the following topics are covered: permitting activities; ambient monitoring; plant discharge monitoring; pollution control unit emissions; surface mining and reclamation; environmental incident summary; and regulatory environmental inspections. The supplemental environmental program covers: performance survey; toxicity screening study; data base management system; epidemiology; and contingency program. 16 figs., 53 tabs. (AT)

Not Available

1986-10-01T23:59:59.000Z

407

ENCOAL Mild Coal Gasification Project. Annual report, October 1990--September 1991  

DOE Green Energy (OSTI)

ENCOAL Corporation, a wholly-owned subsidiary of Shell Mining Company, is constructing a mild gasification demonstration plant at Triton Coal Company`s Buckskin Mine near Gillette, Wyoming. The process, using Liquids From Coal (LFC) technology developed by Shell and SGI International, utilizes low-sulfur Powder River Basin Coal to produce two new fuels, Process Derived Fuel (PDF) and Coal Derived Liquids (CDL). The products, as alternative fuels sources, are expected to significantly reduce current sulfur emissions at industrial and utility boiler sites throughout the nation, thereby reducing pollutants causing acid rain.

Not Available

1992-02-01T23:59:59.000Z

408

Inferential Estimation of Texaco Coal Gasification Quality Using Stacked Neural Networks  

Science Conference Proceedings (OSTI)

The robust inferential estimation of syngas compositions using stacked neural network was presented. Data for building non-linear models is re-sampled using bootstrap techniques to form a number of sets of training and test data. For each data set, a ...

Rong Guo; Weiwei Guo; Dongchen Shi

2008-12-01T23:59:59.000Z

409

An instrumentalist approach to validation: a quantitative assessment of a novel coal gasification model.  

E-Print Network (OSTI)

??The explosion in computing power and its application to complex multiphysics problems has led to the emergence of computer simulation as a new way of… (more)

Reid, Charles Martin

2012-01-01T23:59:59.000Z

410

(Great Plains Coal Gasification Associates). Quarterly technical progress report. [Lurgi Process  

SciTech Connect

The operations of the Great Plains Gasification plant are reported for the first quarter of 1986. Contents include the following: (1) lignite coal production; (2) SNG production; (3) SNG gas quality; (4) by-products production and inventories; (5) on-stream factors; (6) raw material, product and by-product consumption and energy consumption for plant operations; (7) plant modifications-1986 budget; (8) plant maintenance; (9) safety; (10) industrial hygiene; (11) medical services; (12) environmental executive summary; and (13) quality assurance/quality control activities.

Not Available

1986-04-30T23:59:59.000Z

411

Engineering support services for the DOE/GRI Coal Gasification Research Program  

SciTech Connect

The objective of this contract is to provide technical support. During this report period, the support consisted of project management services and the monitoring and evaluation of Foster Wheeler's study on the bioconversion of synthesis gas. The status of this project is summarized in one section of the paper. The Foster Wheeler process involves the bioconversion of coal synthesis gas to SNG or to hydrogen. The design and cost estimation of plants for the SNG process are given. 4 refs., 5 figs., 4 tabs. (CK)

Mazzella, G.

1990-01-01T23:59:59.000Z

412

A Brief Review of Viscosity Models for Slag in Coal Gasification  

Science Conference Proceedings (OSTI)

Many researchers have defined the phenomenon of 'slagging' as the deposition of ash in the radiative section of a boiler, while 'fouling' refers to the deposition of ash in the convective-pass region. Among the important parameters affecting ash deposition that need to be studied are ash chemistry, its transport, deposit growth, and strength development; removability of the ash deposit; heat transfer mechanisms; and the mode of operation for boilers. The heat transfer at the walls of a combustor depends on many parameters including ash deposition. This depends on the processes or parameters controlling the impact efficiency and the sticking efficiency. For a slagging combustor or furnace, however, the temperatures are so high that much of the coal particles are melted and the molten layer, in turn, captures more particles as it flows. The main problems with ash deposition are reduced heat transfer in the boiler and corrosion of the tubes. Common ways of dealing with these issues are soot blowing and wall blowing on a routine basis; however, unexpected or uncontrolled depositions can also complicate the situation, and there are always locations inaccessible to the use of such techniques. Studies have indicated that slag viscosity must be within a certain range of temperatures for tapping and the membrane wall to be accessible, for example, between 1300 C and 1500 C, the viscosity is approximately 25 Pa {center_dot} s. As the operating temperature decreases, the slag cools and solid crystals begin to form. In such cases the slag should be regarded as a non-Newtonian suspension, consisting of liquid silicate and crystals. A better understanding of the rheological properties of the slag, such as yield stress and shear-thinning, are critical in determining the optimum operating conditions. To develop an accurate heat transfer model in any type of coal combustion or gasification process, the heat transfer and to some extent the rheological properties of ash and slag, especially in high-temperature environments need to be understood and properly modeled. The viscosity of slag and the thermal conductivity of ash deposits are among two of the most important constitutive parameters that need to be studied. The accurate formulation or representations of the (transport) properties of coal (and biomass for co-firing cases) present a special challenge of modeling efforts in computational fluid dynamics applications. In this report, we first provide a brief review of the various approaches taken by different researchers in formulating or obtaining a slag viscosity model. In general, these models are based on experiments. Since slag behaves as a non-linear fluid, we discuss the constitutive modeling of slag and the important parameters that must be studied.

Massoudi, Mehrdad; Wang, Ping

2011-11-01T23:59:59.000Z

413

Stabilization and/or regeneration of spent sorbents from coal gasification  

SciTech Connect

The objective of this investigation is to determine the effects of SO{sub 2} partial pressure and reaction temperature on the conversion of sulfide containing solid wastes from coal gasifiers to stable and environmentally acceptable calcium-sulfate, while preventing the release of sulfur dioxide through undesirable side reactions during the stabilization step. An additional objective of this program is to investigate the use of the Spent Sorbent Regeneration Process (SSRP) to regenerate spent limestone, from a fluidized-bed gasifier with in-bed sulfur capture, for recycling to the gasifier. To achieve these objectives, selected samples of partially sulfided sorbents will be reacted with oxygen at a variety of operating conditions under sufficient SO{sub 2} partial pressure to prevent release of sulfur from the solids during stabilization that reduces the overall sorbent utilization. Partially sulfided limestone will also be regenerated with water to produce calcium hydroxide and release sulfur as H{sub 2}S. The regenerated sorbent will be dewatered, dried and pelletized. The reactivity of the regenerated sorbent toward H{sub 2}S will also be determined. During this quarter sulfidation tests were conducted in a quartz fluidized-bed reactor in which the selected calcium-based sorbents were first calcined and then were reacted with hydrogen sulfide at ambient pressure and 1650{degree}F. These tests were conducted with each sorbent in two particle sizes. Chemical analyses of the partially sulfided sorbents indicate that the extent of sulfidation was in the range of 40--50%. The partially sulfided material will be reacted with oxygen to determine the effects of temperature and SO{sub 2} partial pressure on the stabilization of the calcium sulfide in solid waste materials. 23 refs., 1 fig., 2 tabs.

Abbasian, J.

1991-01-01T23:59:59.000Z

414

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

415

Proceedings: Conference on Coal Gasification Systems and Synthetic Fuels for Power Generation, Volumes 1 and 2  

Science Conference Proceedings (OSTI)

The international effort to develop synthetic fuels and advanced power systems for the commercial generation of electric power from coal, oil shale, and tar sands has been an outstanding technical success. This conference highlighted the work that brought new fuels and power generation systems to reality.

1986-01-01T23:59:59.000Z

416

Highly Selective H2 Separation Zeolite Membranes for Coal Gasification Membrane Reactor Applications  

DOE Green Energy (OSTI)

Zeolite membranes are thermally, chemically, and mechanically stable. They also have tunable molecular sieving and catalytic ability. These unique properties make zeolite membrane an excellent candidate for use in catalytic membrane reactor applications related to coal conversion and gasification, which need high temperature and high pressure range separation in chemically challenging environment where existing technologies are inefficient or unable to operate. Small pore, good quality, and thin zeolite membranes are needed for highly selective H2 separation from other light gases (CO2, CH4, CO). However, current zeolite membranes have either too big zeolite pores or a large number of defects and have not been successful for H2 separation from light gases. The objective of this study is to develop zeolite membranes that are more suitable for H2 separation. In an effort to tune the size of zeolite pores and/or to decrease the number of defects, medium-pore zeolite B-ZSM-5 (MFI) membranes were synthesized and silylated. Silylation on B-ZSM-5 crystals reduced MFI-zeolite pore volume, but had little effect on CO2 and CH4 adsorption. Silylation on B-ZSM-5 membranes increased H2 selectivity both in single component and in mixtures with CO2, CH4, or N2. Single gas and binary mixtures of H2/CO2 and H2/CH4 were permeated through silylated B-ZSM-5 membranes at feed pressures up to 1.7 MPa and temperatures up to 773 K. For one B-ZSM-5 membrane after silylation, the H2/CO2 separation selectivity at 473 K increased from 1.4 to 37, whereas the H2/CH4 separation selectivity increased from 1.6 to 33. Hydrogen permeance through a silylated BZSM-5 membrane was activated with activation energy of {approx}10 kJ/mol, but the CO2 and CH4 permeances decreased slightly with temperature in both single gas and in mixtures. Therefore, the H2 permeance and H2/CO2 and H2/CH4 separation selectivities increased with temperature. At 673 K, the H2 permeance was 1.0x10-7 mol{center_dot}m-2{center_dot}s-1{center_dot}Pa-1, and the H2/CO2 separation selectivity was 47. Above 673 K, the silylated membrane catalyzed reverse water gas shift reaction and still separated H2 with high selectivity; and it was thermally stable. However, silylation decreased H2 permeance more than one order of magnitude. Increasing the membrane feed pressure increased the H2 flux and the H2 mole fraction in the permeate stream for both H2/CO2 and H2/CH4 mixtures. The H2 separation performance of the silylated B-ZSM-5 membranes depended on the initial membrane quality and acidity, as well as the silane precursors. Another approach used in this study is optimizing the synthesis of small-pore SAPO-34 (CHA) membranes and/or modifying SAPO-34 membranes by silylation or ion exchange. For SAPO-34 membranes, strong CO2 adsorption inhibited H2 adsorption and decreased H2 permeances, especially at low temperatures. At 253 K, CO2/H2 separation selectivities of a SAPO-34 membrane were greater than 100 with CO2 permeances of about 3 x 10-8 mol{center_dot}m-2{center_dot}s-1{center_dot}Pa-1. The high reverse-selectivity of the SAPO-34 membranes can minimize H2 recompression because H2 remained in the retentate stream at a higher pressure. The CO2/H2 separation selectivity exhibited a maximum with CO2 feed concentration possibly caused by a maximum in the CO2/H2 sorption selectivity with increased CO2 partial pressure. The SAPO-34 membrane separated H2 from CH4 because CH4 is close to the SAPO-34 pore size so its diffusivity (ABSTRACT TRUNCATED)

Mei Hong; Richard Noble; John Falconer

2007-09-24T23:59:59.000Z

417

Exxon catalytic coal gasification process: predevelopment program. Monthly report, July 1977  

SciTech Connect

Operation of the catalyst recovery unit continued and water soluble potassium was recovered and recycled to the catalyst addition unit. The recovery of water soluble potassium increased to 94.0%. Approximately 324 hours of material-balanced operations were logged with excellent closures. The longest continuous run lasted over 290 hours. Carbon and steam conversions remained essentially the same as for the June material balance periods. Construction of a digestion unit for secondary catalyst recovery was completed. Bench scale studies of catalyst recovery via water washing were continued. Data confirmed the discovery that exposure of char to air adversely affects catalyst recovery. The effect of residence time on catalyst recovery by water-washing was also investigated. Over the range of conditions investigated, recovery of water-soluble catalyst is independent of residence time. Work continued on the use of Ca(OH)/sub 2/ digestion to recover water-insoluble potassium from gasifier ash/char residue. Recoveries of water-insoluble potassium from unwashed char decreased with a decrease in liquid/char ratio. A simulation of digestion using solutions of recovered catalyst was conducted. Recoveries from these recycle runs are in the same range as recoveries obtained in runs made under the same conditions with fresh 15% KOH solution. Work has continued on the development of the process basis for the Catalytic Gasification Study Design.

Kalina, T.

1977-08-26T23:59:59.000Z

418

Exxon catalytic coal gasification process: predevelopment program. Quarterly technical progress report, July 1--September 30, 1976  

SciTech Connect

Predevelopment Program activities for the Exxon Catalytic Gasification Process include: recommissioning of the existing 20 lbs/hr Fluid Bed Gasifier (FBG); modifications to the FBG data acquisition system including the on-line computer program for the calculation of unit material balances from process variable data; start-up and initial operations of the 1-3 lbs/hr Continuous Gasification Unit (CGU); and computer programs development for CRT display of the CGU operating variables profile and for on-line material balance calculations. Data were obtained in the CGU for the gasification of catalyzed Illinois coal during four continuous and two captive fluid-bed yield periods. Good agreement was obtained with previous fixed bed kinetic data. This project is an ERDA-sponsored extension of previous EXXON results.

Kalina, T.

1976-11-01T23:59:59.000Z

419

Exxon catalytic coal gasification process: predevelopment program. Monthly report, June 1977  

SciTech Connect

Operations of the Catalyst Recovery Unit (CRU) continued and the water-soluble catalyst on the gasifier ash/char residue was recovered and recycled to the Catalyst Addition Unit. Several changes were made in the operating procedures which increased the recovery of water-soluble catalyst to about 90 percent. Further improvement is expected as a result of additional changes planned. FBG operations utilizing coal feed impregnated with recycle catalyst solution were excellent. The unit service factor was 96% which is the highest onsteam factor obtained to date. The longest continuous run lasted 587 hours. The carbon and steam conversions have remained high. Bench scale studies of catalyst recovery via water-washing were initiated in order to investigate lower-than expected recoveries of water-soluble catalyst obtained in the CRU. The data suggest that the precautions previously taken to prevent exposure of the gasifier ash/char residue to air were inadequate, and that inadvertent exposure of the residue played a significant part in the difficulty experienced in recovering the water soluble catalyst. Work has been completed on engineering scoping studies to define and compare the ''cash flows'' for alternative processes for potassium catalyst manufacture. Similar scoping studies to estimate ''cash flows'' for processes to recover water-insoluble catalyst from spent gasifier solids have also been completed.

Kalina, T.

1977-07-29T23:59:59.000Z

420

Failure analyses of two ball valves used for coal-gasification applications  

SciTech Connect

Two ball valves which had failed by developing excess leakage were supplied for analyses. The 2'' (51 mm) valve had experienced 5000 cycles during 20 hrs usage in an unknown chemical environment. Wear on the ball and seats was a multi-stage process starting with breakdown of a hard chrome plating on the stainless steel ball. This eventually led to adhesive weld transfer of the stainless steel to the seat made of Stellite 6 alloy. The 6'' (152 mm) ball valve had experienced a cycling test sequence using compressed air up to 300 psig (2.07 MPa) at 850/sup 0/F (727/sup 0/K). Damage was characterized as abrasive wear caused either by particles deposited by the compressed air or by carbide particles present in the Stellite 6 alloy ball and seat hardfacing. The decrease in this alloy's compressive yield strength at the elevated test temperature contributed to increased wear rates.

Van Den Avyle, J.A.; Pope, L.E.

1982-07-01T23:59:59.000Z

Note: This page contains sample records for the topic "integrated coal-gasification combined" from the National Library of EnergyBeta (NLEBeta).
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421

In situ formation of coal gasification catalysts from low cost alkali metal salts  

DOE Patents (OSTI)

A carbonaceous material, such as crushed coal, is admixed or impregnated with an inexpensive alkali metal compound, such as sodium chloride, and then pretreated with a stream containing steam at a temperature of 350.degree. to 650.degree. C. to enhance the catalytic activity of the mixture in a subsequent gasification of the mixture. The treatment may result in the transformation of the alkali metal compound into another, more catalytically active, form.

Wood, Bernard J. (Santa Clara, CA); Brittain, Robert D. (Cupertino, CA); Sancier, Kenneth M. (Menlo Park, CA)

1985-01-01T23:59:59.000Z

422

Sintering and slagging of mineral matter in South African coals during the coal gasification process.  

E-Print Network (OSTI)

?? Coals, from mines in the Highveld coalfield, as well as gasification ash samples were characterised, in order to understand the mineralogical and chemical properties… (more)

Matjie, Ratale Henry

2008-01-01T23:59:59.000Z

423

Solar coal-gasification reactor with pyrolysis-gas recycle. [Patent application  

DOE Patents (OSTI)

Coal (or other carbonaceous matter, such as biomass) is converted into a product gas that is substantially free from hydrocarbons. The coal is fed into a solar reactor, and solar energy is directed into the reactor onto coal char, creating a gasification front and a pyrolysis front. A gasification zone is produced well above the coal level within the reactor. A pyrolysis zone is produced immediately above the coal level. Steam, injected into the reactor adjacent to the gasification zone, reacts with char to generate product gases. Solar energy supplies the energy for the endothermic steam-char reaction. The hot product gases flow from the gasification zone to the pyrolysis zone to generate hot char. Gases are withdrawn from the pyrolysis zone and reinjected into the region of the reactor adjacent the gasification zone. This eliminates hydrocarbons in the gas by steam reformation on the hot char. The product gas is withdrawn from a region of the reactor between the gasification zone and the pyrolysis zone. The product gas will be free of tar and other hydrocarbons, and thus be suitable for use in many processes.

Aiman, W.R.; Gregg, D.W.

1981-04-06T23:59:59.000Z

424

Prediction of Syngas Compositions in Texaco Coal Gasification Process Using Robust Neural Estimator  

Science Conference Proceedings (OSTI)

A robust inferential estimator model based on improved dynamic principal component analysis (DPCA) and multiple neural networks (MNN) was proposed. Data for building non-linear models was re-sampled using DPCA algorithm to form a number of sets of training ...

Rong Guo; Weiwei Guo; Wei Wang

2008-12-01T23:59:59.000Z

425

Materials Testing in a Syngas Cooler of a Coal Gasification Plant  

Science Conference Proceedings (OSTI)

As part of an ongoing study of the corrosion of metallic alloys, several steels and protective coatings were exposed for up to 17,000 hrs in a syngas cooler of a coal-slurry-fed, entrained slagging gasifier. The materials suffered from corrosion during high-temperature service as well as during shutdown. Stainless steels containing molybdenum and low-alloy steels protected by a silicon-carbide refractory showed promising low corrosion rates, which decreased with increasing service time.

1996-05-03T23:59:59.000Z

426

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

427

Software Component Integration Testing  

Science Conference Proceedings (OSTI)

... a combination of off-the-shelf components, with new components integrated to satisfy ... oriented, that is, it consists of objects with state and behavior. ...

2011-12-02T23:59:59.000Z

428

An investigation into the mechanism and kinetics of dimethoxymethane carbonylation over FAU and MFI zeolites  

E-Print Network (OSTI)

............................................................................................................................................... 4 2.1 COAL GASIFICATION ................................................................................................................................. 12 3.2 THERMOCHEMICAL GASIFICATION..................................................................................................... 2 3 Coal gasification schematic

Bell, Alexis T.

429

Optimized Pathways for Regional H2 Infrastructure Transitions: A Case Study for Southern California  

E-Print Network (OSTI)

production technologies including biomass gasification,coal gasification, natural gas reforming, and waterby biomass central gasification and then coal gasification

Lin, Zhenhong; Fan, Yueyue; Ogden, Joan M; Chen, Chien-Wei

2008-01-01T23:59:59.000Z

430

Optimized Pathways for Regional H2 Infrastructure Transitions: The Least-Cost Hydrogen for Southern California  

E-Print Network (OSTI)

production technologies including biomass gasification,coal gasification, natural gas reforming, and waterby biomass central gasification and then coal gasification

Lin, Zhenhong; Chen, Chien-Wei; Fan, Yueyue; Ogden, Joan M.

2008-01-01T23:59:59.000Z

431

The Role of Illinois and the Midwest in Responding to the Challenges of Climate Change  

E-Print Network (OSTI)

permitted a coal gasification plant that has carbon se-strongly advocating coal gasification and other clean coal

Scott, Douglas

2009-01-01T23:59:59.000Z

432

The Westinghouse solid oxide fuel cell program: Clean, efficient energy for the future  

DOE Green Energy (OSTI)

This paper provides an overview of the Westinghouse tubular SOFC technology and field testing program. The development program for the field testing was initiated in 1986 with a 400 W unit. This program has progressed to the installation and start-up in early 1992 of the 25 kill field unit at Rokko Island in Japan. In mid-1992 the second 25 kill field unit, a cogeneration system producing both ac electric power and intermediate pressure steam, will be delivered to the Joint Gas Utilities, a consortium of the Tokyo Gas Company and the Osaka Gas Company. This will be followed by the 20 kill SOFC unit to be supplied to Southern California Edison in early 1993. Future plans include the 100 kill Cogeneration Proof-of-Concept unit for the Southern California Gas Company which is scheduled for delivery in late 1993. Applications for SOFC technology range from on-site power generation for commercial second small industrial applications to dispersed generating plants and central station electric power generation. The design studies have included integrated coal gasification SOFC-steam turbine power plants. Installed capital costs of a 250 MW plant of this configuration compares favorably with the integrated coal gasification combined cycle plants.

Gockley, G.B.

1992-01-01T23:59:59.000Z

433

The Westinghouse solid oxide fuel cell program: Clean, efficient energy for the future  

DOE Green Energy (OSTI)

This paper provides an overview of the Westinghouse tubular SOFC technology and field testing program. The development program for the field testing was initiated in 1986 with a 400 W unit. This program has progressed to the installation and start-up in early 1992 of the 25 kill field unit at Rokko Island in Japan. In mid-1992 the second 25 kill field unit, a cogeneration system producing both ac electric power and intermediate pressure steam, will be delivered to the Joint Gas Utilities, a consortium of the Tokyo Gas Company and the Osaka Gas Company. This will be followed by the 20 kill SOFC unit to be supplied to Southern California Edison in early 1993. Future plans include the 100 kill Cogeneration Proof-of-Concept unit for the Southern California Gas Company which is scheduled for delivery in late 1993. Applications for SOFC technology range from on-site power generation for commercial second small industrial applications to dispersed generating plants and central station electric power generation. The design studies have included integrated coal gasification SOFC-steam turbine power plants. Installed capital costs of a 250 MW plant of this configuration compares favorably with the integrated coal gasification combined cycle plants.

Gockley, G.B.

1992-12-01T23:59:59.000Z

434

Forecast Combinations  

E-Print Network (OSTI)

Forecast combinations have frequently been found in empirical studies to produce better forecasts on average than methods based on the ex-ante best individual forecasting model. Moreover, simple combinations that ignore correlations between forecast errors often dominate more refined combination schemes aimed at estimating the theoretically optimal combination weights. In this chapter we analyze theoretically the factors that determine the advantages from combining forecasts (for example, the degree of correlation between forecast errors and the relative size of the individual models’ forecast error variances). Although the reasons for the success of simple combination schemes are poorly understood, we discuss several possibilities related to model misspecification, instability (non-stationarities) and estimation error in situations where thenumbersofmodelsislargerelativetothe available sample size. We discuss the role of combinations under asymmetric loss and consider combinations of point, interval and probability forecasts. Key words: Forecast combinations; pooling and trimming; shrinkage methods; model misspecification, diversification gains

Allan Timmermann; Jel Codes C

2006-01-01T23:59:59.000Z

435

EIS-0431: Hydrogen Energy California's Integrated Gasification...  

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

31: Hydrogen Energy California's Integrated Gasification Combined Cycle and Carbon Capture and Sequestration Project, California EIS-0431: Hydrogen Energy California's Integrated...

436

Progress on a New Integrated 3-D UCG Simulator and its Initial Application  

Science Conference Proceedings (OSTI)

A comprehensive simulator is being developed for underground coal gasification (UCG), with the capability to support site selection, design, hazard analyses, operations, and monitoring (Nitao et al., 2010). UCG is computationally challenging because it involves tightly-coupled multi-physical/chemical processes, with vastly different timescales. This new capability will predict cavity growth, product gas composition and rate, and the interaction with the host environment, accounting for site characteristics, injection gas composition and rate, and associated water-well extraction rates. Progress on the new simulator includes completion and system integration of a wall model, a rock spalling model, a cavity boundary tracking model, a one-dimensional cavity gas reactive transport model, a rudimentary rubble heat, mass, and reaction model, and coupling with a pre-existing hydrology simulator. An existing geomechanical simulator was enhanced to model cavity collapse and overburden subsidence. A commercial computational fluid dynamics (CFD) code is being evaluated to model cavity gas flow and combustion in two and three dimensions. Although the simulator is midway in its developm