National Library of Energy BETA

Sample records for gasification combined-cycle igcc

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

    SciTech Connect (OSTI)

    NONE

    2007-01-15

    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.

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

    SciTech Connect (OSTI)

    Kumar, Aditya; Shi, Ruijie; Dokucu, Mustafa

    2013-09-17

    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.

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

    SciTech Connect (OSTI)

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

    2010-01-01

    Next-generation coal-fired power plants need to consider the option for CO2 capture as stringent governmental mandates are expected to be issued in near future. Integrated gasification combined cycle (IGCC) plants are more efficient than the conventional coal combustion processes when the option for CO2 capture is considered. However, no IGCC plant with CO2 capture currently exists in the world. Therefore, it is important to consider the operability and controllability issues of such a plant before it is commercially built. To facilitate this objective, a detailed plant-wide dynamic simulation of an IGCC plant with 90% CO2 capture has been developed in Aspen Plus Dynamics{reg_sign}. The plant considers a General Electric Energy (GEE)-type downflow radiant-only gasifier followed by a quench section. A two-stage water gas shift (WGS) reaction is considered for conversion of CO to CO2. A two-stage acid gas removal (AGR) process based on a physical solvent is simulated for selective capture of H2S and CO2. Compression of the captured CO2 for sequestration, an oxy-Claus process for removal of H2S and NH3, black water treatment, and the sour water treatment are also modeled. The tail gas from the Claus unit is recycled to the SELEXOL unit. The clean syngas from the AGR process is sent to a gas turbine followed by a heat recovery steam generator. This turbine is modeled as per published data in the literature. Diluent N2 is used from the elevated-pressure ASU for reducing the NOx formation. The heat recovery steam generator (HRSG) is modeled by considering generation of high-pressure, intermediate-pressure, and low-pressure steam. All of the vessels, reactors, heat exchangers, and the columns have been sized. The basic IGCC process control structure has been synthesized by standard guidelines and existing practices. The steady state results are validated with data from a commercial gasifier. In the future grid-connected system, the plant should satisfy the environmental 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.

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

    SciTech Connect (OSTI)

    1995-05-01

    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.

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

    Broader source: Energy.gov [DOE]

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

  6. Integrated gasification combined-cycle research development and demonstration activities

    SciTech Connect (OSTI)

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

    1995-12-01

    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.

  7. Analysis of Integrated Gasification Combined Cycle power plants and process integration with pre-combustion carbon capture 

    E-Print Network [OSTI]

    Kapetaki, Zoe

    2015-06-29

    Integrated Gasification Combined Cycle (IGCC) power plants have been considered as one of the best options for energy production in an environmental friendly manner. IGCC power plants are demonstrating better results, ...

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

    SciTech Connect (OSTI)

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

    1996-09-01

    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.

  9. Tampa Electric Company`s Polk Power Station Integrated Gasification Combined Cycle Project

    SciTech Connect (OSTI)

    Jenkins, S.D.; Shafer, J.R.

    1994-12-31

    Tampa Electric Company (TEC) is in the construction phase for the new Polk Power Station, Unit {number_sign}1. This will be the first unit at a new site and will use Integrated Gasification Combined Cycle (IGCC) technology for power generation. The unit will utilize oxygen-blown entrained-flow coal gasification, along with combined cycle technology, to provide nominal net 26OMW of generation. As part of the environmental features of this process, the sulfur species in the coal will be recovered as a commercial grade sulfuric acid by-product. The sulfur will be removed from the synthesis gas utilizing a cold gas clean-up system (CGCU).

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

    SciTech Connect (OSTI)

    B. Wayne Bequette; Priyadarshi Mahapatra

    2010-08-31

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

  11. Combined cycle power plant incorporating coal gasification

    DOE Patents [OSTI]

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

    1981-01-01

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

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

    DOE Patents [OSTI]

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

    2013-04-09

    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.

  13. EIS-0409: Kemper County Integrated Gasification Combined Cycle Project, Mississippi

    Broader source: Energy.gov [DOE]

    This EIS analyzes DOE's decision to provide funding for the Kemper County Integrated Gasification Combined Cycle Project in Kemper County, Mississippi to assess the potential environmental impacts associated with the construction and operation of a project proposed by Southern Power Company, through its affiliate Mississippi Power Company, which has been selected by DOE for consideration under the Clean Coal Power Initiative (CCPI) program.

  14. ASME PTC 47 - IGCC performance testing: Gasification island thermal performance testing

    SciTech Connect (OSTI)

    Mirolli, M.D.; Doering, E.L.

    1998-07-01

    In the past several years, Integrated Gasification Combined Cycle (IGCC) power plants have been introduced in a number of competitive markets. Most of the demonstration projects have been subsidized. However, as the technology is further developed, its versatility will lead to its application in a variety of market segments. This leads to the need of the user to evaluate the performance of the gasification process within the IGCC power plant through field testing. This paper deals with an approach to measuring the gasification island thermal performance. A thermal efficiency term based upon an input/output test approach is introduced. Measured parameters and pre-test planning are discussed. Computational procedures for determining the thermal efficiency of the gasification island are described including an uncertainty analysis for the performance test.

  15. Advanced integration concepts for oxygen plants and gas turbines in gasification/IGCC facilities

    SciTech Connect (OSTI)

    Smith, A.R.; Klosek, J.; Woodward, D.W.

    1996-12-31

    The commercialization of Integrated Gasification Combined-Cycle (IGCC) power has been aided by concepts involving the integration of a cryogenic air separation unit (ASU) with the gas turbine combined-cycle module. Other processes, such as coal-based ironmaking and combined power and industrial gas production facilities, can benefit from the integration of these two units. It is known and now widely accepted that an ASU designed for elevated pressure service and optimally integrated with the gas turbine can increase overall IGCC power output, increase overall efficiency, and decrease the net cost of power generation compared to non-integrated facilities employing low pressure ASU`s. Depending upon the specific gas turbine, gasification technology, NOx emission specification, and other site specific factors, various degrees of compressed air and nitrogen integration are optimal. Air Products has supplied ASU`s with no integration (Destec/Plaquemine IGCC), nitrogen-only integration (Tampa Electric/Polk County IGCC), and full air and nitrogen integration (Demkolec/Buggenum IGCC). Continuing advancements in both air separation and gas turbine technologies offer new integration opportunities to further improve performance and reduce costs. This paper will review basic integration principles and describe advanced concepts based on emerging high compression ratio gas turbines. Humid Air Turbine (HAT) cycles, and integration of compression heat and refrigeration sources from the ASU. Operability issues associated with integration will be reviewed and control measures described for the safe, efficient, and reliable operation of these facilities.

  16. ASME PTC 47, gasification combined cycle performance -- Uncertainty

    SciTech Connect (OSTI)

    Archer, D.H.; Horazak, D.A.; Bannister, R.L.

    1998-07-01

    Determining the uncertainty of measured calculated performance parameters is required in all Performance Test Codes of the ASME. This determination begins with the equations defining the performance parameters of the equipment or system--input, useful output, and effectiveness (an input/output ratio). The variables in these equations are: plant operating conditions measured throughout a test; corrections that compensate for deviations of other significant measured plant and ambient operating conditions from their values specified for the test. PTC47, Gasification Combined Cycle Plant Performance, will define procedures for the performance testing of overall gasification combined cycle plants and for each of three major sections that may comprise such a plant. The Committee is now defining the performance parameters for these tests. Performance factor computations include uncertainty calculations in order to provide preliminary estimates of the accuracy expected from the test methods proposed in this Code. Uncertainty calculations will also be used to explore energy balance methods for calculating the energy input to various gasifiers--entrained flow, fluidized bed, and moving bed. Such methods would be important as possible alternatives to direct measurements of flows and heating values of the various fuels fed to the gasifiers. Uncertainty calculations will also be used to assist in identifying those measurements of ambient, imposed, and controlled operating conditions that significantly affect test results and for which correction factors should be determined.

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

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

    produce both power generation increases and significant cost savings at Integrated Gasification Combined Cycle (IGCC) power plants, according to new research from a U.S....

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

    SciTech Connect (OSTI)

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

    1996-07-01

    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.

  19. Life cycle assessment of a biomass gasification combined-cycle power system

    SciTech Connect (OSTI)

    Mann, M.K.; Spath, P.L.

    1997-12-01

    The potential environmental benefits from biomass power are numerous. However, biomass power may also have some negative effects on the environment. Although the environmental benefits and drawbacks of biomass power have been debated for some time, the total significance has not been assessed. This study serves to answer some of the questions most often raised in regard to biomass power: What are the net CO{sub 2} emissions? What is the energy balance of the integrated system? Which substances are emitted at the highest rates? What parts of the system are responsible for these emissions? To provide answers to these questions, a life cycle assessment (LCA) of a hypothetical biomass power plant located in the Midwest United States was performed. LCA is an analytical tool for quantifying the emissions, resource consumption, and energy use, collectively known as environmental stressors, that are associated with converting a raw material to a final product. Performed in conjunction with a technoeconomic feasibility study, the total economic and environmental benefits and drawbacks of a process can be quantified. This study complements a technoeconomic analysis of the same process, reported in Craig and Mann (1996) and updated here. The process studied is based on the concept of power Generation in a biomass integrated gasification combined cycle (BIGCC) plant. Broadly speaking, the overall system consists of biomass production, its transportation to the power plant, electricity generation, and any upstream processes required for system operation. The biomass is assumed to be supplied to the plant as wood chips from a biomass plantation, which would produce energy crops in a manner similar to the way food and fiber crops are produced today. Transportation of the biomass and other materials is by both rail and truck. The IGCC plant is sized at 113 MW, and integrates an indirectly-heated gasifier with an industrial gas turbine and steam cycle. 63 refs., 34 figs., 32 tabs.

  20. NOVEL GAS CLEANING/CONDITIONING FOR INTEGRATED GASIFICATION COMBINED CYCLE

    SciTech Connect (OSTI)

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

    2005-12-01

    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

  1. Making IGCC slag valuable

    SciTech Connect (OSTI)

    Wicker, K.

    2005-12-01

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

  2. Catalytic combustor for integrated gasification combined cycle power plant

    DOE Patents [OSTI]

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

    2008-12-16

    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.

  3. Could IGCC swing

    SciTech Connect (OSTI)

    Blankinship, S.

    2007-06-15

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

  4. Coal Gasification for Power Generation, 3. edition

    SciTech Connect (OSTI)

    NONE

    2007-11-15

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

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

    E-Print Network [OSTI]

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

    2014-01-01

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

  6. Simulation and optimization of hot syngas separation processes in integrated gasification combined cycle

    E-Print Network [OSTI]

    Prakash, Kshitij

    2009-01-01

    IGCC with CO2 capture offers an exciting approach for cleanly using abundant coal reserves of the world to generate electricity. The present state-of-the-art synthesis gas (syngas) cleanup technologies in IGCC involve ...

  7. The suitability of coal gasification in India's energy sector

    E-Print Network [OSTI]

    Simpson, Lori Allison

    2006-01-01

    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 ...

  8. Coal gasification players, projects, prospects

    SciTech Connect (OSTI)

    Blankinship, S.

    2006-07-15

    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.

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

    E-Print Network [OSTI]

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

    2012-05-09

    of the GEE IGCC with CO2 capture (with traditional PBR? Plant 4) in the DOE/NTEL report (Haslbeck et al. 2010). The present value of the equipment costs were calculated by using the Marshal & Swift (M&S) equipment cost indexes (M&S cost...

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

    E-Print Network [OSTI]

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

    2011-01-01

    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 ...

  11. A dynamic process model of a natural gas combined cycle -- Model development with startup and shutdown simulations

    SciTech Connect (OSTI)

    Liese, Eric [U.S. DOE; Zitney, Stephen E. [U.S. DOE

    2013-01-01

    Research in dynamic process simulation for integrated gasification combined cycles (IGCC) with carbon capture has been ongoing at the National Energy Technology Laboratory (NETL), culminating in a full operator training simulator (OTS) and immersive training simulator (ITS) for use in both operator training and research. A derivative work of the IGCC dynamic simulator has been a modification of the combined cycle section to more closely represent a typical natural gas fired combined cycle (NGCC). This paper describes the NGCC dynamic process model and highlights some of the simulator’s current capabilities through a particular startup and shutdown scenario.

  12. EIS-0428: Department of Energy Loan Guarantee for Mississippi Integrated Gasification Combined Cycle, Moss Point, Mississippi

    Broader source: Energy.gov [DOE]

    This EIS evaluates the environmental impacts of a petroleum coke-to-substitute natural gas facility proposed to be built by Mississippi Gasification. The facility would be designed to produce 120 million standard cubic feet of gas per day. Other products would be marketable sulfuric acid, carbon dioxide, argon, and electric power. This project is inactive.

  13. EIS-0429: Department of Energy Loan Guarantee for Indiana Integrated Gasification Combined Cycle, Rockport, IN

    Broader source: Energy.gov [DOE]

    This EIS evaluates the environmental impacts of a coal-to-substitute natural gas facility proposed to be built in Rockport, IN by Indiana Gasification. The facility would utilize Illinois Basin coal. Other products would be marketable sulfuric acid, argon, and electric power. This project is inactive.

  14. A utility`s perspective of the market for IGCC

    SciTech Connect (OSTI)

    Black, C.R.

    1993-06-01

    The market for Integrated Gasification Combined Cycle (IGCC) power plants is discussed and some of the experiments with an Integrated Gasification Combined Cycle Power Plant Project, Polk Unit {number_sign}1 are described. It was found that not only is the technology different from what most US utilities are accustomed to, but also that the non-technical issues or business issues, such as contracting, project management and contract administration also have different requirements. The non-technical or business issues that are vital to the successful commercialization of this technology are described. These business issues must be successfully addressed by both the utilities and the technology suppliers in order for integrated gasification combined cycle power plants to achieve commercial success.

  15. Coal gasification for power generation. 2nd ed.

    SciTech Connect (OSTI)

    NONE

    2006-10-15

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

  16. Filter systems for IGCC applications

    SciTech Connect (OSTI)

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

    1995-11-01

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

  17. ASME PTC 47 -- Calculation of overall IGCC plant performance

    SciTech Connect (OSTI)

    Xiong, T.; Horazak, D.A.

    1999-07-01

    An integrated gasification combined cycle (IGCC) plant is a combined chemical and power system that converts coal or other unrefined fuel into clean gaseous fuel, electric power, and other byproducts. The conversion process requires interactions among the gasification, gas cleaning, air or oxygen production, power and steam generation systems. Overall performance testing of IGCC plants. however, is based only on the streams that cross the overall plant boundary. This paper describes the calculation procedures required to conduct a fair and accurate performance test of an IGCC plant, as proposed for ASME Performance Test Code 47. Discussions include identification of parameters to be measured, calculations needed to evaluate performance, and corrections to performance data for test conditions that differ from reference conditions.

  18. Integration of oxygen plants and gas turbines in IGCC facilities

    SciTech Connect (OSTI)

    Smith, A.R.; Sorensen, J.C.; Woodward, D.W.

    1996-10-01

    The commercialization of Integrated Gasification Combined-Cycle (IGCC) power has been aided by concepts involving the integration of a cryogenic air separation unit (ASU) with the gas turbine combined-cycle module. It is known and now widely accepted that an ASU designed for elevated pressure service and optimally integrated with the gas turbine can increase overall IGCC power output, increase overall efficiency, and decrease the net cost of power generation compared to non-integrated facilities employing low pressure ASU`s. Depending upon the specific gas turbine, gasification technology, NO{sub x} emission specification, and other site specific factors, various degrees of compressed air and nitrogen integration are optimal. Air Products has supplied ASU`s with no integration (Destec/Plaquemine IGCC), nitrogen-only integration (Tampa Electric/Polk County IGCC), and full air and nitrogen integration (Demkolec/Buggenum IGCC). Continuing advancements in both air separation and gas turbine technologies offer new integration opportunities to further improve performance and reduce costs. This paper reviews basic integration principles, highlights the integration scheme used at Polk County, and describes some advanced concepts based on emerging gas turbines. Operability issues associated with integration will be reviewed and control measures described for the safe, efficient, and reliable operation of these facilities.

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

    E-Print Network [OSTI]

    Kundi, Manish

    2011-12-16

    to as capture ready, with comparatively much lower costs for capturing greenhouse gas (CO2). Despite the promise of this technology, it is still being developed and tested and is not half as mature as pulverized coal plant technologies. IGCC power plants have...

  20. Development of a dynamic simulator for a natural gas combined cycle (NGCC) power plant with post-combustion carbon capture

    SciTech Connect (OSTI)

    Liese, E.; Zitney, S.

    2012-01-01

    The AVESTAR Center located at the U.S. Department of Energy’s National Energy Technology Laboratory and West Virginia University is a world-class research and training environment dedicated to using dynamic process simulation as a tool for advancing the safe, efficient and reliable operation of clean energy plants with CO{sub 2} capture. The AVESTAR Center was launched with a high-fidelity dynamic simulator for an Integrated Gasification Combined Cycle (IGCC) power plant with pre-combustion carbon capture. The IGCC dynamic simulator offers full-scope Operator Training Simulator (OTS) Human Machine Interface (HMI) graphics for realistic, real-time control room operation and is integrated with a 3D virtual Immersive Training Simulator (ITS), thus allowing joint control room and field operator training. The IGCC OTS/ITS solution combines a “gasification with CO{sub 2} capture” process simulator with a “combined cycle” power simulator into a single high-performance dynamic simulation framework. This presentation will describe progress on the development of a natural gas combined cycle (NGCC) dynamic simulator based on the syngas-fired combined cycle portion of AVESTAR’s IGCC dynamic simulator. The 574 MW gross NGCC power plant design consisting of two advanced F-class gas turbines, two heat recovery steam generators (HRSGs), and a steam turbine in a multi-shaft 2x2x1 configuration will be reviewed. Plans for integrating a post-combustion carbon capture system will also be discussed.

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

    SciTech Connect (OSTI)

    Berry, T.E.

    1998-12-31

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

  2. Future Impacts of Coal Distribution Constraints on Coal Cost

    E-Print Network [OSTI]

    McCollum, David L

    2007-01-01

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

  3. Future Impacts of Coal Distribution Constraints on Coal Cost

    E-Print Network [OSTI]

    McCollum, David L

    2007-01-01

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

  4. INTEGRATED PYROLYSIS COMBINED CYCLE BIOMASS POWER SYSTEM CONCEPT DEFINITION

    SciTech Connect (OSTI)

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

    2003-03-01

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

  5. Commercial gasifier for IGCC applications study report

    SciTech Connect (OSTI)

    Notestein, J.E.

    1990-06-01

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

  6. International potential of IGCC technology for use in reducing global warming and climate change emissions

    SciTech Connect (OSTI)

    Lau, F.S.

    1996-12-31

    High efficiency advanced coal-based technologies such as Integrated Gasification Combined Cycle (IGCC) that can assist in reducing CO{sub 2} emissions which contribute to Global Warming and Climate Change are becoming commercially available. U-GAS is an advanced gasification technology that can be used in many applications to convert coal in a high efficiency manner that will reduce the total amount of CO{sub 2} produced by requiring less coal-based fuel per unit of energy output. This paper will focus on the status of the installation and performance of the IGT U-GAS gasifiers which were installed at the Shanghai Cooking and Chemical Plant General located in Shanghai, China. Its use in future IGCC project for the production of power and the benefits of IGCC in reducing CO{sub 2} emissions through its high efficiency operation will be discussed.

  7. Mesaba next-generation IGCC plant

    SciTech Connect (OSTI)

    NONE

    2006-01-01

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

  8. Kemper County IGCC (tm) Project Preliminary Public Design Report

    SciTech Connect (OSTI)

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

    2012-07-01

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

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

    E-Print Network [OSTI]

    Apps, J.A.

    2006-01-01

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

  10. ASME PTC47.4 -- IGCC performance testing issues for the power block

    SciTech Connect (OSTI)

    Anand, A.K.; Parmar, J.

    1999-07-01

    Integrated Gasification Combined Cycle (IGCC) plants that utilize solid and unconventional liquid fuels have now reached commercialization stage as evidenced by their worldwide construction and new orders. The complex nature or integration between the power generating and the fuel gas generating gasification units of an IGCC has created a need to provide guidance and procedures on how to conduct the performance test for the users and owners of these power plants. ASME Performance Test Code 47 (PTC47) and the associated subsets (PTC47.1, PTC47.2, PTC47.3 and PTC47.4) are being written to define the significant performance factors and provide recommendations how these factors should be applied on test measurements to evaluate the deviation from the IGCC equipment guarantees. This paper reports the progress and issues pertaining to the PTC 47.4 for the IGCC Power Block and how it differs from ASME PTC 46 test code. The paper also discusses the creation of a thermodynamic Power Block model of Wabash River Repowering IGCC plant using a proprietary software. Correction curves derived from the model, which define the performance at design and off design from site conditions are also presented.

  11. Tampa Electric Company, Polk Power Station IGCC Project: Project Status

    SciTech Connect (OSTI)

    Berry, T.E.; Shelnut, C.A.; McDaniel, J.E.

    1999-07-01

    Over the last ten years, Tampa Electric Company (TEC) has taken the Polk Power Station from a concept to a reality. The Tampa Electric Company Polk Power Station is a nominal 250 MW (net) Integrated Gasification Combined Cycle (IGCC) power plant located to the southeast of Tampa, Florida in Polk County, Florida. This project is being partially funded under the Department of Energy Clean Coal Technology Program pursuant to a Round III award. The Polk Power Station achieved first fire of the gasification system on schedule in mid-July, 1996. It was placed in commercial operation on September 30, 1996. Since start-up in July, 1996, significant advances have occurred in the design and operation of the entire IGCC train. This presentation will feature an up-to-the-minute update of actual performance parameters achieved by the Polk Power Station. These parameters include overall capacity, heat rate, and availability. Several different coal feedstocks have been tested and the resulting performance will be compared to that achieved on the base coal. This paper also provides an update of the general operating experiences and shutdown causes of the gasification facility. Finally, the future plans for improving the reliability and efficiency of the Unit will be addressed, as well as plans for future additional alternate fuel test burns.

  12. Prioritizing Climate Change Mitigation Alternatives: Comparing Transportation Technologies to Options in Other Sectors

    E-Print Network [OSTI]

    Lutsey, Nicholas P.

    2008-01-01

    of natural gas-powered combined cycle power plants. The mostintegrated gasification combined cycle (IGCC) coal plants,integrated gasification combined cycle (IGCC) technology for

  13. Tampa Electric Company Polk Power Station IGCC project: Project status

    SciTech Connect (OSTI)

    McDaniel, J.E.; Carlson, M.R.; Hurd, R.; Pless, D.E.; Grant, M.D.

    1997-12-31

    The Tampa Electric Company Polk Power Station is a nominal 250 MW (net) Integrated Gasification Combined Cycle (IGCC) power plant located to the southeast of Tampa, Florida in Polk County, Florida. This project is being partially funded under the Department of Energy`s Clean Coal Technology Program pursuant to a Round II award. The Polk Power Station uses oxygen-blown, entrained-flow IGCC technology licensed from Texaco Development Corporation to demonstrate significant reductions of SO{sub 2} and NO{sub x} emissions when compared to existing and future conventional coal-fired power plants. In addition, this project demonstrates the technical feasibility of commercial scale IGCC and Hot Gas Clean Up (HGCU) technology. The Polk Power Station achieved ``first fire`` of the gasification system on schedule in mid-July, 1996. Since that time, significant advances have occurred in the operation of the entire IGCC train. This paper addresses the operating experiences which occurred in the start-up and shakedown phase of the plant. Also, with the plant being declared in commercial operation as of September 30, 1996, the paper discusses the challenges encountered in the early phases of commercial operation. Finally, the future plans for improving the reliability and efficiency of the Unit in the first quarter of 1997 and beyond, as well as plans for future alternate fuel test burns, are detailed. The presentation features an up-to-the-minute update on actual performance parameters achieved by the Polk Power Station. These parameters include overall Unit capacity, heat rate, and availability. In addition, the current status of the start-up activities for the HGCU portion of the plant is discussed.

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

    SciTech Connect (OSTI)

    Ashok K. Anand

    2005-12-16

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

  15. Life Cycle Regulation of Transportation Fuels: Uncertainty and its Policy Implications

    E-Print Network [OSTI]

    Plevin, Richard Jay

    2010-01-01

    cycle; BIGCC = biomass integrated gasification combined-and (iii) biomass integrated gasification combined-cycle (gasification combined cycle (IGCC) and (iv) biomass IGCC. To

  16. Tampa Electric Company`s Polk Power Station IGCC project

    SciTech Connect (OSTI)

    Jenkins, S.D.

    1995-12-31

    Tampa Electric Company (TEC) is in the construction phase of its new Polk Power Station Unit No. 1. This unique project incorporates the use of Integrated Gasification Combined Cycle (IGCC) technology for electric power production. The project is being partially funded by the US Department of Energy (DOE), as part of the Clean Coal Technology Program. This will help to demonstrate this state-of-the-art technology, providing utilities with the ability to use a wide range of coals in an efficient, environmentally superior manner. During the summer of 1994, TEC began site development at the new Polk Power Station. Since that time, most of the Site work has been completed, and erection and installation of the power plant equipment is well underway. This is the first time that IGCC technology will be installed at a new unit at a greenfield site. This is a major endeavor for TEC in that Polk Unit No. 1 is a major addition to the existing generating capacity and it involves the demonstration of technology new to utility power generation. As a part of the Cooperative Agreement with the DOE, TEC will also be demonstrating the use of a new Hot Gas Clean-Up System which has a potential for greater IGCC efficiency.

  17. Tampa Electric Company IGCC Project. Quarterly report, April 1 - June 30, 1996

    SciTech Connect (OSTI)

    1996-12-31

    Tampa Electric Company continued efforts to complete construction and start-up of the Polk Power Station, Unit {number_sign}1 which will use Integrated Gasification Combined Cycle (IGCC) technology for power generation. From an overall standpoint, the Project continues to track well. The completion of construction system turnovers to Start-up is encouraging. Start-up will accept responsibility of the plant until turnover to operations. The major focus continues to be on the production of first Syngas, scheduled for July 17. All construction, engineering, and start-up activities are in support of Syngas production. Key activities toward this goal include final checkout and startup of remaining gasification systems, completion of punch list items required for first syngas, finalization of operating procedures, preparation of site and area access control plans, site- wide safety training, and other Process Safety management (PSM) requirements.

  18. WABASH RIVER COAL GASIFICATION REPOWERING PROJECT

    SciTech Connect (OSTI)

    Unknown

    2000-09-01

    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.

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

    SciTech Connect (OSTI)

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

    2011-01-01

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

  20. Gasification, polygeneration capture interest of refiners

    SciTech Connect (OSTI)

    Aalund, L.R.

    1996-12-09

    Integrated gasification combined cycle (IGCC) plants are moving into the mainstream of international refining. Such plants can turn refinery dregs into the whitest of all products--sparkling electricity--plus hydrogen and synthesis gas. Hydrogen is an indispensable element for cleaning up and improving modern fuels, while syngas is the feedstock for important finished petrochemicals and intermediaries. The status and potential of gasification technologies and projects were covered in a 3 day conference early in October in San Francisco. What made this conference different from others on the subject in the past was recognition that oil and natural gas producers and the international refining industry are becoming major power producers without government subsidies. Such projects can pass the scrutiny of lenders and the test of commerciality. They are not targeted simply for electricity, but also for production of hydrogen, steam, and petrochemical feedstock. The process objective for projects now far exceeds simple cogeneration. It`s now trigeneration, even polygeneration.

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

    SciTech Connect (OSTI)

    Alptekin, Gokhan

    2013-09-30

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

  2. West Virginia University 1 Department of Chemical Engineering

    E-Print Network [OSTI]

    Mohaghegh, Shahab

    gasification combined cycle (IGCC), Chemical looping, Fuel cells (SOFC & PEM), Optimization, Dynamic modeling

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

    SciTech Connect (OSTI)

    1997-12-31

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

  4. Partially Adaptive Stochastic Optimization for Electric Power ...

    E-Print Network [OSTI]

    2015-01-03

    capacity expansion, namely Base Load, Combined Cycle (CC), Combined Turbine (CT), Nuclear, Wind, and. Integrated Gasification Combined Cycle (IGCC

  5. Resource Limits and Conversion Efficiency with Implications for Climate Change

    E-Print Network [OSTI]

    Croft, Gregory Donald

    2009-01-01

    using Integrated Gasification Combined Cycle (IGCC) plants.Natural gas-fired combined cycle plants can be converted toand more efficient combined-cycle plants. Combined cycle

  6. Optimal control system design for IGCC power plants with CO2 capture

    SciTech Connect (OSTI)

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

    2012-01-01

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

  7. Improving process performances in coal gasification for power and synfuel production

    SciTech Connect (OSTI)

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

    2008-11-15

    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.

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

    SciTech Connect (OSTI)

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

    1994-06-01

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

  9. ConocoPhillips Sweeny IGCC/CCS Project

    SciTech Connect (OSTI)

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

    2010-06-16

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

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

    SciTech Connect (OSTI)

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

    2009-01-01

    To eliminate the harmful effects of greenhouse gases, especially that of CO2, future coalfired power plants need to consider the option for CO2 capture. The loss in efficiency for CO2 capture is less in an Integrated Gasification Combined Cycle (IGCC) plant compared to other conventional coal combustion processes. However, no IGCC plant with CO2 capture currently exists in the world. Therefore, it is important to consider the operability and controllability issues of such a plant before it is commercially built. With this objective in mind, a detailed plant-wide dynamic simulation of an IGCC plant with CO2 capture has been developed. The plant considers a General Electric Energy (GEE)-type downflow radiant-only gasifier followed by a quench section. A two-stage water gas shift (WGS) reaction is considered for conversion of about 96 mol% of CO to CO2. A two-stage acid gas removal (AGR) process based on a physical solvent is simulated for selective capture of H2S and CO2. The clean syngas is sent to a gas turbine (GT) followed by a heat recovery steam generator (HRSG). The steady state results are validated with data from a commercial gasifier. A 5 % ramp increase in the flowrate of coal is introduced to study the system dynamics. To control the conversion of CO at a desired level in the WGS reactors, the steam/CO ratio is manipulated. This strategy is found to be efficient for this operating condition. In the absence of an efficient control strategy in the AGR process, the environmental emissions exceeded the limits by a great extent.

  11. An Overview of Coal based

    E-Print Network [OSTI]

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

  12. Reading the Tea Leaves: How Utilities in the West Are Managing Carbon Regulatory Risk in their Resource Plans

    E-Print Network [OSTI]

    Barbose, Galen

    2008-01-01

    of a natural gas-fired combined cycle gas turbine (CCGT).integrated gasification combined cycle (IGCC) generationrate exceeding that of a combined-cycle natural gas unit.

  13. A Framework for Environmental Assessment of CO2 Capture and Storage Systems

    E-Print Network [OSTI]

    Sathre, Roger

    2013-01-01

    Integrated Gasification Combined Cycle (IGCC) Power Plant.Analysis: Natural Gas Combined Cycle (NGCC) Power Plant.assessment of natural gas combined cycle power plant with

  14. Assessing Vehicle Electricity Demand Impacts on California Electricity Supply

    E-Print Network [OSTI]

    McCarthy, Ryan W.

    2009-01-01

    IGCC Integrated gasification combined cycle IID ImperialCorporation NGCC Natural gas combined-cycle NGCT Natural gas79% from natural gas combined cycle (NGCC) power plants, and

  15. The role of Life Cycle Assessment in identifying and reducing environmental impacts of CCS

    E-Print Network [OSTI]

    Sathre, Roger

    2011-01-01

    Integrated Gasification Combined Cycle (IGCC) Power Plant.Analysis: Natural Gas Combined Cycle (NGCC) Power Plant.assessment of natural gas combined cycle power plant with

  16. Advanced Coal Wind Hybrid: Economic Analysis

    E-Print Network [OSTI]

    Phadke, Amol

    2008-01-01

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

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

    SciTech Connect (OSTI)

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

    1994-06-01

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

  18. Status of Tampa Electric Company IGCC Project

    SciTech Connect (OSTI)

    Jenkins, S.D.

    1992-01-01

    Tampa Electric Company will utilize Integrated Gasification Combined Cycle technology for its new Polk Power Station Unit [number sign]1. The project is partially funded under the Department of Energy Clean Coal Technology Program Round III. This paper describes the technology to be used, process details, demonstration of a new hot gas clean-up system, and the schedule, leading to commercial operation in July 1996.

  19. Status of Tampa Electric Company IGCC Project

    SciTech Connect (OSTI)

    Jenkins, S.D.

    1992-10-01

    Tampa Electric Company will utilize Integrated Gasification Combined Cycle technology for its new Polk Power Station Unit {number_sign}1. The project is partially funded under the Department of Energy Clean Coal Technology Program Round III. This paper describes the technology to be used, process details, demonstration of a new hot gas clean-up system, and the schedule, leading to commercial operation in July 1996.

  20. How and why Tampa Electric Company selected IGCC for its next generating capacity addition

    SciTech Connect (OSTI)

    Pless, D.E. )

    1992-01-01

    As the title indicates, the purpose of this paper is to relate how and why Tampa Electric Company decided to select the Integrated Gasification Combined Cycle (IGCC) for their next capacity addition at Polk Power Station, Polk Unit No. 1. For a complete understanding of this process, it is necessary to review the history related to the initial formulation of the IGCC concept as it was proposed to the Department of Energy (DOE) Clean Coal Initiative Round Three. Further, it is important to understand the relationship between Tampa Electric Company and TECO Pay Services Corporation (TPS). TECO Energy, Inc. is an energy related holding company with headquarters in Tampa, Florida. Tampa Electric Company is the principal, wholly-owned subsidiary of TECO Energy, Inc. Tampa Electric Company is an investor-owned electric utility with about 3200 MW of generation capacity of which 97% is coal fired. Tampa Electric Company serves about 2,000 square miles and approximately 470,000 customers, in west central Florida, primarily in and around Hillsborough County and Tampa, Florida. Tampa Electric Company generating units consist of coal fired units ranging in size from a 110 MW coal fired cyclone unit installed in 1957 to a 450 MW pulverized coal unit with wet limestone flue gas desulfurization installed in 1985. In addition, Tampa Electric Company has six (6) No. 6 oil fired steam units totaling approximately 220 MW. Five (5) of these units, located at the Hookers Point Station, were installed in the late 1940's and early 1950's. Tampa Electric also has about 150 MW of No. 2 oil fired start-up and peaking combustion turbines. The company also owns a 1966 vintage 12 MW natural gas fired steam plant (Dinner Lake) and two nO. 6 oil fired diesel units with heat recovery equipment built in 1983 (Phillips Plant).

  1. ASME PTC 47 - IGCC performance testing: Air separation issues

    SciTech Connect (OSTI)

    Smith, A.R.

    1998-07-01

    Air separation units have been incorporated into the designs of many gasification combined cycle projects worldwide for the supply of pressurized oxygen and nitrogen. Pressurized gaseous oxygen at a purity usually above 95% by volume is supplied to the gasification unit to partially oxidized a hydrocarbon feed to yield syngas. Nitrogen streams are used for purging and inerting purposes or for the reactor. Several facilities have incorporated integration of air and/or nitrogen streams between the gas turbine and the air separation unit to improve overall facility cost, power output and efficiency. Gasification processes that are based on air as the oxidant source may also require an air separation unit to supply pressurized nitrogen for inerting and dry fuel transport. This paper reports on the progress of PTC 47's air separation subcommittee in defining test measurement boundaries and performance parameter definitions for the testing of an air separation unit as a subsystem of the gasification combined cycle facility.

  2. Efficiency combined cycle power plant

    SciTech Connect (OSTI)

    Pavel, J.; Meyers, G.A.; Baldwin, T.S.

    1990-06-12

    This patent describes a method of operating a combined cycle power plant. It comprises: flowing exhaust gas from a combustion turbine through a heat recovery steam generator (HRSG); flowing feed water through an economizer section of the HRSG at a flow rate and providing heated feed water; flowing a first portion of the heated feed water through an evaporator section of the HRSG and producing saturated steam at a production rate, the flow rate of the feed water through the economizer section being greater than required to sustain the production rate of steam in the evaporator section; flowing fuel for the turbine through a heat exchanger; and, flowing a second portion of the heated feed water provided by the economizer section through the heat exchanger then to an inlet of the economizer section, thereby heating the fuel flowing through the heat exchanger.

  3. igcc | netl.doe.gov

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

    addition, cofiring coal with opportunity materials such as municipal waste and biomass feedstocks in this context may enable IGCC-based power generation to more quickly gain a...

  4. "Integrated Gasification Combined Cycle"

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

    AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative Fuels Data Center Home Page on Google Bookmark EERE: Alternative Fuels Data Center Home Page| Open Energy Informationmonthly gasoline price to fall to $3.43U.S.longec 188 U.S.1 HomeRegional cost adjustments

  5. Optimal integrated design of air separation unit and gas turbine block for IGCC systems

    SciTech Connect (OSTI)

    Kamath, R.; Grossman, I.; Biegler, L.; Zitney, S.

    2009-01-01

    The Integrated Gasification Combined Cycle (IGCC) systems are considered as a promising technology for power generation. However, they are not yet in widespread commercial use and opportunities remain to improve system feasibility and profitability via improved process integration. This work focuses on the integrated design of gasification system, air separation unit (ASU) and the gas turbine (GT) block. The ASU supplies oxygen to the gasification system and it can also supply nitrogen (if required as a diluent) to the gas turbine block with minimal incremental cost. Since both GT and the ASU require a source of compressed air, integrating the air requirement of these units is a logical starting point for facility optimization (Smith et al., 1997). Air extraction from the GT can reduce or avoid the compression cost in the ASU and the nitrogen injection can reduce NOx emissions and promote trouble-free operation of the GT block (Wimer et al., 2006). There are several possible degrees of integration between the ASU and the GT (Smith and Klosek, 2001). In the case of 'total' integration, where all the air required for the ASU is supplied by the GT compressor and the ASU is expected to be an elevated-pressure (EP) type. Alternatively, the ASU can be 'stand alone' without any integration with the GT. In this case, the ASU operates at low pressure (LP), with its own air compressor delivering air to the cryogenic process at the minimum energy cost. Here, nitrogen may or may not be injected because of the energy penalty issue and instead, syngas humidification may be preferred. A design, which is intermediate between these two cases, involves partial supply of air by the gas turbine and the remainder by a separate air compressor. These integration schemes have been utilized in some IGCC projects. Examples include Nuon Power Plant at Buggenum, Netherlands (both air and nitrogen integration), Polk Power Station at Tampa, US (nitrogen-only integration) and LGTI at Plaquemine, US (stand-alone). However, there is very little information on systematic assessment of air extraction, nitrogen injection and configuration and operating conditions of the ASU and it is not clear which scheme is optimal for a given IGCC application. In this work, we address the above mentioned problem systematically using mixed-integer optimization. This approach allows the use of various objectives such as minimizing the investment and operating cost or SOx and NOx emissions, maximizing power output or overall efficiency or a weighted combination of these factors. A superstructure is proposed which incorporates all the integration schemes described above. Simplified models for ASU, gas turbine system and steam cycle are used which provide reasonable estimates for performance and cost (Frey and Zhu, 2006). The optimal structural configuration and operating conditions are presented for several case studies and it is observed that the optimal solution changes significantly depending on the specified objective.

  6. Optimal Integrated Design of Air Separation Unit and Gas Turbine Block for IGCC Systems

    SciTech Connect (OSTI)

    Ravindra S. Kamath; Ignacio E. Grossmann; Lorenz T. Biegler; Stephen E. Zitney

    2009-01-01

    The Integrated Gasification Combined Cycle (IGCC) systems are considered as a promising technology for power generation. However, they are not yet in widespread commercial use and opportunities remain to improve system feasibility and profitability via improved process integration. This work focuses on the integrated design of gasification system, air separation unit (ASU) and the gas turbine (GT) block. The ASU supplies oxygen to the gasification system and it can also supply nitrogen (if required as a diluent) to the gas turbine block with minimal incremental cost. Since both GT and the ASU require a source of compressed air, integrating the air requirement of these units is a logical starting point for facility optimization (Smith et al., 1997). Air extraction from the GT can reduce or avoid the compression cost in the ASU and the nitrogen injection can reduce NOx emissions and promote trouble-free operation of the GT block (Wimer et al., 2006). There are several possible degrees of integration between the ASU and the GT (Smith and Klosek, 2001). In the case of 'total' integration, where all the air required for the ASU is supplied by the GT compressor and the ASU is expected to be an elevated-pressure (EP) type. Alternatively, the ASU can be 'stand alone' without any integration with the GT. In this case, the ASU operates at low pressure (LP), with its own air compressor delivering air to the cryogenic process at the minimum energy cost. Here, nitrogen may or may not be injected because of the energy penalty issue and instead, syngas humidification may be preferred. A design, which is intermediate between these two cases, involves partial supply of air by the gas turbine and the remainder by a separate air compressor. These integration schemes have been utilized in some IGCC projects. Examples include Nuon Power Plant at Buggenum, Netherlands (both air and nitrogen integration), Polk Power Station at Tampa, US (nitrogen-only integration) and LGTI at Plaquemine, US (stand-alone). However, there is very little information on systematic assessment of air extraction, nitrogen injection and configuration and operating conditions of the ASU and it is not clear which scheme is optimal for a given IGCC application. In this work, we address the above mentioned problem systematically using mixed-integer optimization. This approach allows the use of various objectives such as minimizing the investment and operating cost or SOx and NOx emissions, maximizing power output or overall efficiency or a weighted combination of these factors. A superstructure is proposed which incorporates all the integration schemes described above. Simplified models for ASU, gas turbine system and steam cycle are used which provide reasonable estimates for performance and cost (Frey and Zhu, 2006). The optimal structural configuration and operating conditions are presented for several case studies and it is observed that the optimal solution changes significantly depending on the specified objective.

  7. Gasification Technologie: Opportunities & Challenges

    SciTech Connect (OSTI)

    Breault, R.

    2012-01-01

    This course has been put together to provide a single source document that not only reviews the historical development of gasification but also compares the process to combustion. It also provides a short discussion on integrated gasification and combined cycle processes. The major focus of the course is to describe the twelve major gasifiers being developed today. The hydrodynamics and kinetics of each are reviewed along with the most likely gas composition from each of the technologies when using a variety of fuels under different conditions from air blown to oxygen blown and atmospheric pressure to several atmospheres. If time permits, a more detailed discussion of low temperature gasification will be included.

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

    SciTech Connect (OSTI)

    Not Available

    1993-12-01

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

  9. Degradation of TBC Systems in Environments Relevant to Advanced Gas Turbines for IGCC Systems

    SciTech Connect (OSTI)

    Gleeson, Brian

    2014-09-30

    Air plasma sprayed (APS) thermal barrier coatings (TBCs) are used to provide thermal insulation for the hottest components in gas turbines. Zirconia stabilized with 7wt% yttria (7YSZ) is the most common ceramic top coat used for turbine blades. The 7YSZ coating can be degraded from the buildup of fly-ash deposits created in the power-generation process. Fly ash from an integrated gasification combined cycle (IGCC) system can result from coal-based syngas. TBCs are also exposed to harsh gas environments containing CO2, SO2, and steam. Degradation from the combined effects of fly ash and harsh gas atmospheres has the potential to severely limit TBC lifetimes. The main objective of this study was to use lab-scale testing to systematically elucidate the interplay between prototypical deposit chemistries (i.e., ash and its constituents, K2SO4, and FeS) and environmental oxidants (i.e., O2, H2O and CO2) on the degradation behavior of advanced TBC systems. Several mechanisms of early TBC failure were identified, as were the specific fly-ash constituents responsible for degradation. The reactivity of MCrAlY bondcoats used in TBC systems was also investigated. The specific roles of oxide and sulfate components were assessed, together with the complex interplay between gas composition, deposit chemistry and alloy reactivity. Bondcoat composition design strategies to mitigate corrosion were established, particularly with regard to controlling phase constitution and the amount of reactive elements the bondcoat contains in order to achieve optimal corrosion resistance.

  10. A combined cycle engine test facility

    SciTech Connect (OSTI)

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

    1995-09-01

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

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

    SciTech Connect (OSTI)

    Aditya Kumar

    2010-12-30

    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.

  12. December 9, 2008 Conservation

    E-Print Network [OSTI]

    expensive Gasification Integrated coal gasification combined-cycle (IGCC) - Very early commercial IGCC w supercritical plant + biomass co-firing + BACT retrofit to adjacent existing project(s) Genesee 3 450 MW

  13. Combined cycle comes to the Philippines

    SciTech Connect (OSTI)

    1995-03-01

    The first combined cycle power station in the Philippines has gone into operation at National Power Corporation`s (NPC) Limay Bataan site, some 40 km west of Manila. The plant comprises two 300 MW blocks in 3+3+1 configuration, based on ABB Type GT11N gas turbines. It was built by a consortium of ABB, with their Japanese licensee Kawasaki Heavy Industries, and Marubeni Corporation. This paper discusses Philippine power production, design and operation of the Limay Bataan plant, and conversion of an existing turbine of the nuclear plant project that was abandoned earlier, into a combined cycle operation. 6 figs.

  14. Combined Cycle Cogeneration at NALCO Chemical 

    E-Print Network [OSTI]

    Thunem, C. B.; Jacobs, K. W.; Hanzel, W.

    1985-01-01

    approach for determining the most economical system design. Generation capacity ranging from 2.7 MW up to 7.0 MW in both simple cycle cogeneration and combined cycle cogeneration was analyzed. Both single pressure and dual pressure waste heat boilers were...

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

    SciTech Connect (OSTI)

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

    2009-06-03

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

  16. Development of standardized air-blown coal gasifier/gas turbine concepts for future electric power systems. Volume 1, Final report

    SciTech Connect (OSTI)

    Sadowski, R.S.; Brown, M.J.; Hester, J.C.; Harriz, J.T.; Ritz, G.J.

    1991-02-01

    The objective of this study is to develop standardized air blown fixed bed gasification hot gas cleanup integrated gasifier combined cycle (IGCC) systems.

  17. Development of standardized air-blown coal gasifier/gas turbine concepts for future electric power systems

    SciTech Connect (OSTI)

    Sadowski, R.S.; Brown, M.J.; Hester, J.C.; Harriz, J.T.; Ritz, G.J.

    1991-02-01

    The objective of this study is to develop standardized air blown fixed bed gasification hot gas cleanup integrated gasifier combined cycle (IGCC) systems.

  18. EIS-0409: EPA Notice of Availability of the Draft Environmental...

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

    Availability of the Draft Environmental Impact Statement Kemper County Integrated Gasification Combined-Cycle (IGCC) Project, Mississippi Notice of Availability for the Draft...

  19. fabrication-polybenzimidazole-sri | netl.doe.gov

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

    membrane module for pre-combustion capture of carbon dioxide (CO2) from integrated gasification combined cycle (IGCC)-derived synthesis gas (syngas). The membrane utilizes...

  20. EIS-0409: EPA Notice of Availability of the Final Environmental...

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

    Availability of the Final Environmental Impact Statement Kemper County Integrated Gasification Combined-Cycle (IGCC) Project, Kemper County, Mississippi Kemper County Integrated...

  1. EIS-0382: DOE Notice of Availability of the Draft Environmental...

    Broader source: Energy.gov (indexed) [DOE]

    for the design and one-year operational demonstration of a coal-based, Integrated Gasification Combined Cycle (IGCC) electric generating facility on the Iron Range of northern...

  2. U.S. Secretary of Energy Concludes Productive G8+3 Energy Ministerial...

    Energy Savers [EERE]

    funding for the addition of CCS technology to multiple commercial-scale Integrated Gasification Combined Cycle (IGCC) or other advanced clean-coal technology power plants....

  3. DOE/NETL-2010/???? DOE/NETL-341/013113

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

    gpm Gallons per minute Hg Mercury HGCU Hot-gas-cleanup unit HP High pressure HRSG Heat recovery steam generator IGCC Integrated gasification combined cycle ISO International...

  4. Impact of coal quality and gasifier technology on IGCC performance

    E-Print Network [OSTI]

    on coal type, and had lowest performance for low rank coals. On the other hand, the dry feed IGCC was little affected by coal type. The slurry feed IGCC performed closest to the dry feed IGCC when CO21 Impact of coal quality and gasifier technology on IGCC performance Ola Maurstad1 *, Howard Herzog

  5. EIS-0428: Mississippi Gasification, LLC, Industrial Gasification...

    Office of Environmental Management (EM)

    8: Mississippi Gasification, LLC, Industrial Gasification Facility in Moss Point, MS EIS-0428: Mississippi Gasification, LLC, Industrial Gasification Facility in Moss Point, MS...

  6. EIS-0429: Indiana Gasification, LLC, Industrial Gasification...

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

    Indiana Gasification, LLC, Industrial Gasification Facility in Rockport, IN and CO2 Pipeline EIS-0429: Indiana Gasification, LLC, Industrial Gasification Facility in Rockport, IN...

  7. Optimum Design of Coal Gasification Plants 

    E-Print Network [OSTI]

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

    1982-01-01

    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...

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

    SciTech Connect (OSTI)

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

    2009-04-15

    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.

  9. Thermodynamic Analysis of Combined Cycle District Heating System 

    E-Print Network [OSTI]

    Suresh, S.; Gopalakrishnan, H.; Kosanovic, D.

    2011-01-01

    thermal power plant using design data, where the exergy destruction from each component in the plant was calculated. Senthil Murugan and Subbarao [4] analyzed a Rankine-Kalina combined cycle plant with different modes of operation. Unlike... thermal power plant, Wiley-Interscience. [4] Senthil Murugan R., Subbarao P.M.V., Thermodynamic Analysis of Rankine-Kalina Combined Cycle. [5] Kotas T.J., 1985, The exergy method of thermal plant analysis, Butterworths, London. [6] Rivero R., Rend...

  10. Combined cycle phosphoric acid fuel cell electric power system

    SciTech Connect (OSTI)

    Mollot, D.J.; Micheli, P.L.

    1995-12-31

    By arranging two or more electric power generation cycles in series, combined cycle systems are able to produce electric power more efficiently than conventional single cycle plants. The high fuel to electricity conversion efficiency results in lower plant operating costs, better environmental performance, and in some cases even lower capital costs. Despite these advantages, combined cycle systems for the 1 - 10 megawatt (MW) industrial market are rare. This paper presents a low noise, low (oxides of nitrogen) NOx, combined cycle alternative for the small industrial user. By combining a commercially available phosphoric acid fuel cell (PAFC) with a low-temperature Rankine cycle (similar to those used in geothermal applications), electric conversion efficiencies between 45 and 47 percent are predicted. While the simple cycle PAFC is competitive on a cost of energy basis with gas turbines and diesel generators in the 1 to 2 MW market, the combined cycle PAFC is competitive, on a cost of energy basis, with simple cycle diesel generators in the 4 to 25 MW market. In addition, the efficiency and low-temperature operation of the combined cycle PAFC results in a significant reduction in carbon dioxide emissions with NO{sub x} concentration on the order of 1 parts per million (per weight) (ppmw).

  11. Conceptual design report -- Gasification Product Improvement Facility (GPIF)

    SciTech Connect (OSTI)

    Sadowski, R.S.; Skinner, W.H.; House, L.S.; Duck, R.R. [CRS Sirrine Engineers, Inc., Greenville, SC (United States); Lisauskas, R.A.; Dixit, V.J. [Riley Stoker Corp., Worcester, MA (United States); Morgan, M.E.; Johnson, S.A. [PSI Technology Co., Andover, MA (United States). PowerServe Div.; Boni, A.A. [PSI-Environmental Instruments Corp., Andover, MA (United States)

    1994-09-01

    The problems heretofore with coal gasification and IGCC concepts have been their high cost and historical poor performance of fixed-bed gasifiers, particularly on caking coals. The Gasification Product Improvement Facility (GPIF) project is being developed to solve these problems through the development of a novel coal gasification invention which incorporates pyrolysis (carbonization) with gasification (fixed-bed). It employs a pyrolyzer (carbonizer) to avoid sticky coal agglomeration caused in the conventional process of gradually heating coal through the 400 F to 900 F range. In so doing, the coal is rapidly heated sufficiently such that the coal tar exists in gaseous form rather than as a liquid. Gaseous tars are then thermally cracked prior to the completion of the gasification process. During the subsequent endothermic gasification reactions, volatilized alkali can become chemically bound to aluminosilicates in (or added to) the ash. To reduce NH{sub 3} and HCN from fuel born nitrogen, steam injection is minimized, and residual nitrogen compounds are partially chemically reduced in the cracking stage in the upper gasifier region. Assuming testing confirms successful deployment of all these integrated processes, future IGCC applications will be much simplified, require significantly less mechanical components, and will likely achieve the $1,000/kWe commercialized system cost goal of the GPIF project. This report describes the process and its operation, design of the plant and equipment, site requirements, and the cost and schedule. 23 refs., 45 figs., 23 tabs.

  12. Modeling the Performance, Emissions, and Cost of an Entrained-Flow Gasification Combined Cycle System Using

    E-Print Network [OSTI]

    Frey, H. Christopher

    the type of coal gasifier technology, oxidant (e.g., oxygen or air), and gas cleanup system employed for the conversion of a variety of feedstocks, including coal, heavy residue oil, biomass, solid waste, and others is presented to illustrate the typical performance, emissions, and cost of a coal- based system

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

    SciTech Connect (OSTI)

    1996-07-01

    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.

  14. Tampa Electric Company -- IGCC Project. Quarterly report, July--September 1995

    SciTech Connect (OSTI)

    1995-10-01

    This is the quarterly report for 1995 of the Tampa Electric Company integrated gasification combined-cycle project at Polk Power Station. As of the end of the third quarter of 1995, engineering is essentially complete; construction is about 50% complete. The project is on schedule for the Target Project Completion Date of September 15, 1996. The work force at the site now stands at 1,300 people. Recently the project was recognized for reaching 1 million man-hours without a lost time injury. The report discusses engineering issues, project management issues, construction issues, and accomplishments of each.

  15. GASIFICATION PLANT COST AND PERFORMANCE OPTIMIZATION

    SciTech Connect (OSTI)

    Samuel S. Tam

    2002-05-01

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

  16. Hybrid solar central receiver for combined cycle power plant

    DOE Patents [OSTI]

    Bharathan, D.; Bohn, M.S.; Williams, T.A.

    1995-05-23

    A hybrid combined cycle power plant is described including a solar central receiver for receiving solar radiation and converting it to thermal energy. The power plant includes a molten salt heat transfer medium for transferring the thermal energy to an air heater. The air heater uses the thermal energy to preheat the air from the compressor of the gas cycle. The exhaust gases from the gas cycle are directed to a steam turbine for additional energy production. 1 figure.

  17. Hybrid solar central receiver for combined cycle power plant

    DOE Patents [OSTI]

    Bharathan, Desikan (Lakewood, CO); Bohn, Mark S. (Golden, CO); Williams, Thomas A. (Arvada, CO)

    1995-01-01

    A hybrid combined cycle power plant including a solar central receiver for receiving solar radiation and converting it to thermal energy. The power plant includes a molten salt heat transfer medium for transferring the thermal energy to an air heater. The air heater uses the thermal energy to preheat the air from the compressor of the gas cycle. The exhaust gases from the gas cycle are directed to a steam turbine for additional energy production.

  18. Feature Article Negative pressure dependence of mass burning rates of H2/CO/O2/diluent flames

    E-Print Network [OSTI]

    Ju, Yiguang

    with predominantly CO, CO2, and H2O) as a fuel itself as synthetic gas or ``syngas" from coal or biomass gasification in Integrated Gasification Combined Cycle pro- cesses, including preheated mixtures and other diluents such as N. Integrated Gasification Combined Cycle (IGCC) processes involve gasifying a solid hydrocarbon feedstock

  19. Developments in ITM oxygen technology for IGCC

    SciTech Connect (OSTI)

    Stein, V.E.E.; Richards, R.E.

    1999-07-01

    In partnership with the U.S. Department of Energy (DOE), an Air Products-led team (with Ceramatec, Eltron Research, McDermott Technology, NREC, Texaco, the Pennsylvania State University, and the University of Pennsylvania) is developing a new technology for air separation - Ion Transport Membrane Oxygen - based on the use of mixed-conducting ceramic membranes that have both electronic and oxygen ionic conductivity when operated at high temperature, typically 800 to 900 C. Under the influence of an oxygen partial-pressure driving force, the ITM Oxygen process achieves a high-purity, high-flux separation of oxygen from a compressed-air stream. By integrating the energy-rich, oxygen-depleted, non-permeate stream with a gas turbine system, the ITM Oxygen process becomes a co-producer of high-purity oxygen, power, and steam. Under a recent CRADA entitled ``Ion Transport Membranes (ITM) for Oxygen-Blown IGCC Systems and Indirect Coal Liquefaction,'' Air Products and DOE completed an initial quantification of the benefits of an ITM Oxygen-integrated IGCC facility. Compared to the cryogenic oxygen base case, the ITM Oxygen technology can potentially: reduce total installed costs by 7%; improve thermal efficiency for the integrated IGCC system by about 3%, leading to further decreases in carbon dioxide and sulfur emissions; and reduce the cost of generated electric power by more than 6%. The ITM Oxygen development project will proceed in three phases. Phase 1, which commenced under a DOE Cooperative Agreement in October 1998, is a 3-year effort focusing on construction of a technology development unit (TDU) for process concept validation tests at a capacity of 0.1 ton-per-day (TPD) oxygen. To accomplish this objective, the Air Products team will address relevant technical challenges in ITM Oxygen materials, engineering, membrane module development, and performance testing. During Phase 1 the team will also verify the economic prospects for integrating ITM Oxygen technology with IGCC and other advanced power generation systems. After at least one intermediate scaleup, Phase 2 and 3 activities will culminate with scaleup to a 25- to 50-TPD pre-commercial demonstration unit, fully integrated with a gas turbine. Meeting these challenges of developing cost-effective fabrication techniques for ITM Oxygen devices, and successfully integrating them with commercially available gas turbine engines, is key to bringing ITM Oxygen technology to the marketplace.

  20. Tampa Electric Company - DOE IGCC project. Quarterly report, July 1 - September 30, 1996

    SciTech Connect (OSTI)

    1996-12-31

    The third quarter of 1996 has resulted in the completion of over five (5) years of extensive project development, design, construction and start-up of the 250 MW Polk Power Station Unit {number_sign}1 IGCC Project. the combined cycle performance test was completed on June 18, 1996. This test demonstrated that on distillate fuel, the combined cycle achieved a net output of 222,299 KW with a net heat rate of 6,868 BTU/KW. This is about 3.86% and 2.76% better than the guaranteed values of 214,040 KW and 7,063 BTU/KW respectively. During the third quarter of 1996, the combustion turbine was run on syngas two (2) different times for a combined total of about seven hours. Attachment {number_sign}4 shows graphically the transfer from oil to syngas. Emission levels were generally acceptable even though no specific emissions tuning was completed by GE and the emissions monitoring equipment was not yet completely operational.

  1. Screening of low cost sorbents for arsenic and mercury capture in gasification systems

    SciTech Connect (OSTI)

    Cedric Charpenteau; Revata Seneviratne; Anthe George; Marcos Millan; Denis R. Dugwell; Rafael Kandiyoti

    2007-09-15

    A novel laboratory-scale fixed-bed reactor has been developed to investigate trace metal capture on selected sorbents for cleaning the hot raw gas in Integrated Gasification Combined Cycle (IGCC) power plants. The new reactor design is presented, together with initial results for mercury and arsenic capture on five sorbents. It was expected that the capture efficiency of sorbents would decrease with increasing temperature. However, a commercial activated carbon, Norit Darco 'Hg', and a pyrolysis char prepared from scrap tire rubber exhibit similar efficiencies for arsenic at 200 and at 400{sup o}C (70% and 50%, respectively). Meta-kaolinite and fly ash both exhibit an efficiency of around 50% at 200{sup o}C, which then dropped as the test temperature was increased to 400{sup o}C. Activated scrap tire char performed better at 200{sup o}C than the pyrolysis char showing an arsenic capture capacity similar to that of commercial Norit Darco 'Hg'; however, efficiency dropped to below 40% at 400{sup o}C. These results suggest that the capture mechanism of arsenic (As4) is more complex than purely physical adsorption onto the sorbents. Certain elements within the sorbents may have significant importance for chemical adsorption, in addition to the effect of surface area, as determined by the BET method. This was indeed the case for the mercury capture efficiency for all four sorbents tested. Three of the sorbents tested retained 90% of the mercury when operated at 100{sup o}C. As the temperature increased, the efficiency of activated carbon and pyrolysis char reduced significantly. Curiously, despite having the smallest Brunauer-Emmet-Teller (BET) surface area, a pf-combustion ash was the most effective in capturing mercury over the temperature range studied. These observations suggest that the observed mercury capture was not purely physical adsorption but a combination of physical and chemical processes. 27 refs., 4 figs., 4 tabs.

  2. Power production from renewable resources in a gasification power system

    SciTech Connect (OSTI)

    Paisley, M.A.; Farris, G.; Bain, R.

    1996-12-31

    The US Department of Energy (DOE) has been a leader in the promotion and development of alternative fuel supplies based on renewable energy crops. One promising power generation technology is biomass gasification coupled with either a gas turbine in a combined cycle system or a fuel cell. The gasification of biomass can efficiently and economically produce a renewable source of a clean gaseous fuel suitable for use in these high efficiency power systems or as a substitute fuel in other combustion devices such as boilers, kilns, or other natural gas fired equipment. This paper discusses the development and commercialization of the Battelle high-throughput gasification process for gas turbine based power generation systems. Projected process economics for a gas turbine combined cycle plant are presented along with a description of integrated system operation coupling a 200kW gas turbine power generation system to a 10 ton per day gasifier, and current commercialization activities. 6 refs., 3 figs., 1 tab.

  3. Performance evaluation of a combined-cycle cogeneration system

    SciTech Connect (OSTI)

    Huang, F.F.; Naumowicz, T.

    1999-07-01

    A methodology for performance evaluation of a combined-cycle cogeneration system has been presented. Results for such a system using an advanced gas-turbine as the prime mover show that it is a very versatile system. It can produce a large power-to-heat ratio together with a high second-law efficiency over a wide range of process steam pressures. This work also demonstrates once again that the most appropriate and useful performance parameters for decision-making in cogeneration system design are the second-law efficiency and the power-to-heat ratio.

  4. Coal Gasification Report

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

    and Recommendations 4.5. Non-Fossil Technologies Non-fossil technologies include nuclear, photovoltaic, solar thermal, biomass IGCC, municipal solid waste, geothermal, wind,...

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

    SciTech Connect (OSTI)

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

    2012-03-11

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

  6. FEED SYSTEM INNOVATION FOR GASIFICATION OF LOCALLY ECONOMICAL ALTERNATIVE FUELS (FIGLEAF)

    SciTech Connect (OSTI)

    Michael L. Swanson; Mark A. Musich; Darren D. Schmidt; Joseph K. Schultz

    2003-02-01

    The Feed System Innovation for Gasification of Locally Economical Alternative Fuels (FIGLEAF) project was conducted by the Energy & Environmental Research Center and Gasification Engineering Corporation of Houston, Texas (a subsidiary of Global Energy Inc., Cincinnati, Ohio), with 80% cofunding from the U.S. Department of Energy (DOE). The goal of the project was to identify and evaluate low-value fuels that could serve as alternative feedstocks and to develop a feed system to facilitate their use in integrated gasification combined-cycle and gasification coproduction facilities. The long-term goal, to be accomplished in a subsequent project, is to install a feed system for the selected fuel(s) at Global Energy's commercial-scale 262-MW Wabash River Coal Gasification Facility in West Terre Haute, Indiana. The feasibility study undertaken for the project consisted of identifying and evaluating the economic feasibility of potential fuel sources, developing a feed system design capable of providing a fuel at 400 psig to the second stage of the E-Gas (Destec) gasifier to be cogasified with coal, performing bench- and pilot-scale testing to verify concepts and clarify decision-based options, reviewing information on high-pressure feed system designs, and determining the economics of cofeeding alternative feedstocks with the conceptual feed system design. A preliminary assessment of feedstock availability within Indiana and Illinois was conducted. Feedstocks evaluated included those with potential tipping fees to offset processing cost: sewage sludge, municipal solid waste, used railroad ties, urban wood waste (UWW), and used tires/tire-derived fuel. Agricultural residues and dedicated energy crop fuels were not considered since they would have a net positive cost to the plant. Based on the feedstock assessment, sewage sludge was selected as the primary feedstock for consideration at the Wabash River Plant. Because of the limited waste heat available for drying and the ability of the gasifier to operate with alternative feedstocks at up to 80% moisture, a decision was made to investigate a pumping system for delivering the as-received fuel across the pressure boundary into the second stage of the gasifier. A high-pressure feed pump and fuel dispersion nozzles were tested for their ability to cross the pressure boundary and adequately disperse the sludge into the second stage of the gasifier. These results suggest that it is technically feasible to get the sludge dispersed to an appropriate size into the second stage of the gasifier although the recycle syngas pressure needed to disperse the sludge would be higher than originally desired. A preliminary design was prepared for a sludge-receiving, storage, and high-pressure feeding system at the Wabash River Plant. The installed capital costs were estimated at approximately $9.7 million, within an accuracy of {+-}10%. An economic analysis using DOE's IGCC Model, Version 3 spreadsheet indicates that in order to justify the additional capital cost of the system, Global Energy would have to receive a tipping fee of $12.40 per wet ton of municipal sludge delivered. This is based on operation with petroleum coke as the primary fuel. Similarly, with coal as the primary fuel, a minimum tipping of $16.70 would be required. The availability of delivered sludge from Indianapolis, Indiana, in this tipping-fee range is unlikely; however, given the higher treatment costs associated with sludge treatment in Chicago, Illinois, delivery of sludge from Chicago, given adequate rail access, might be economically viable.

  7. Gasification system

    DOE Patents [OSTI]

    Haldipur, Gaurang B. (Hempfield, PA); Anderson, Richard G. (Penn Hills, PA); Cherish, Peter (Bethel Park, PA)

    1983-01-01

    A method and system for injecting coal and process fluids into a fluidized bed gasification reactor. Three concentric tubes extend vertically upward into the fluidized bed. Coal particulates in a transport gas are injected through an inner tube, and an oxygen rich mixture of oxygen and steam are injected through an inner annulus about the inner tube. A gaseous medium relatively lean in oxygen content, such as steam, is injected through an annulus surrounding the inner annulus.

  8. Gasification system

    DOE Patents [OSTI]

    Haldipur, Gaurang B. (Hempfield, PA); Anderson, Richard G. (Penn Hills, PA); Cherish, Peter (Bethel Park, PA)

    1985-01-01

    A method and system for injecting coal and process fluids into a fluidized bed gasification reactor. Three concentric tubes extend vertically upward into the fluidized bed. Coal particulates in a transport gas are injected through an inner tube, and an oxygen rich mixture of oxygen and steam are injected through an inner annulus about the inner tube. A gaseous medium relatively lean in oxygen content, such as steam, is injected through an annulus surrounding the inner annulus.

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

    E-Print Network [OSTI]

    Couling, David Joseph

    2012-01-01

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

  10. Natural and industrial analogues for release of CO2 from storage reservoirs: Identification of features, events, and processes and lessons learned

    E-Print Network [OSTI]

    Lewicki, Jennifer L.; Birkholzer, Jens; Tsang, Chin-Fu

    2006-01-01

    natural gas, and gas turbine power plants. As shown, thein the flue gas stream of coal and fuel oil power plants.gas stream from the integrated gasification combined-cycle (IGCC) power plant

  11. Fundamental studies in hydrogen-rich combustion : instability mechanisms and dynamic mode selection

    E-Print Network [OSTI]

    Speth, Raymond L., 1981-

    2010-01-01

    Hydrogen-rich alternative fuels are likely to play a significant role in future power generation systems. The emergence of the integrated gasification combined cycle (IGCC) as one of the favored technologies for incorporating ...

  12. Sequestering Carbon from Power Plants: The Jury is Still Out Sean D. Biggs

    E-Print Network [OSTI]

    coal gasification combined cycle (IGCC) capture plant. Although the cost of using CCS technologies.4.1 Type A Error: Misrepresenting the total costs of the technology.....23 2.4.2 Type B Error

  13. BEFORE THE ENERGY RESOURCES CONSERVATION AND DEVELOPMENT COMMISSION OF THE STATE OF CALIFORNIA

    E-Print Network [OSTI]

    Combined-Cycle (IGCC) polygeneration technology. It would gasify a 75 percent coal and 25 percent petroleum coke (petcoke) fuel blend to produce synthesis gas (syngas). Syngas produced via gasification would

  14. 2007 gasification technologies conference papers

    SciTech Connect (OSTI)

    NONE

    2007-07-01

    Sessions covered: gasification industry roundtable; the gasification market in China; gasification for power generation; the gasification challenge: carbon capture and use storage; industrial and polygeneration applications; gasification advantage in refinery applications; addressing plant performance; reliability and availability; gasification's contribution to supplementing gaseous and liquid fuels supplies; biomass gasification for fuel and power markets; and advances in technology-research and development

  15. Gasification Plant Cost and Performance Optimization

    SciTech Connect (OSTI)

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

    2005-05-01

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

  16. Wabash River coal gasification repowering project: Public design report

    SciTech Connect (OSTI)

    NONE

    1995-07-01

    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.

  17. An Edge-based Formulation for the Combined-Cycle Units

    E-Print Network [OSTI]

    Lei Fan

    2014-10-01

    Oct 1, 2014 ... Based on various combinations of combustion turbines (CTs) and steam turbines (STs), the combined-cycle unit could work at different ...

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

    SciTech Connect (OSTI)

    Not Available

    1992-01-01

    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).

  19. GASIFICATION PLANT COST AND PERFORMANCE OPTIMIZATION

    SciTech Connect (OSTI)

    Sheldon Kramer

    2003-09-01

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

  20. Combined-cycle solarised gas turbine with steam, organic and CO2 bottoming cycles

    E-Print Network [OSTI]

    Combined-cycle solarised gas turbine with steam, organic and CO2 bottoming cycles John Pye, Keith of the technical feasibility a solarised combined-cycle gas turbines with a dish concentrator, with several with a thermal receiver taken from the earlier 400 m² 'SG3' dish. Work is underway to design a new steam receiver

  1. Start-up Optimization of a Combined Cycle Power Plant A. Linda, E. Sllberga,

    E-Print Network [OSTI]

    Start-up Optimization of a Combined Cycle Power Plant A. Linda, E. Sällberga, S. Velutb, S the dynamic start-up procedure of a com- bined cycle power plant can be optimized using di- rect collocation. Keywords: Combined Cycle Power Plants, Start-up, Dynamic optimization, Optimica, Control, Modelica

  2. Development and commercialization of a biomass gasification/power generation system

    SciTech Connect (OSTI)

    Paisley, M.A.; Farris, G.

    1995-11-01

    The US Department of Energy (DOE) has been a leader in the promotion and development of alternative fuel supplies based on renewable energy crops. One promising power generation technology is biomass gasification coupled with either a gas turbine in a combined cycle system or a fuel cell. The gasification of biomass can efficiently and economically produce a renewable source of a clean gaseous fuel suitable for use in these high efficiency power systems or as a substitute fuel in other combustion devices such as boilers, kilns, or other natural gas fired equipment. This paper discusses the development and commercialization of the Battelle high-throughput gasification process for gas turbine based power generation systems. Projected process economics for a gas turbine combined cycle plant are presented along with a description of integrated system operation coupling a 200kW gas turbine power generation system to a 10 ton per day gasifier, and current commercialization activities.

  3. 1 Copyright 2010 by ASME Proceedings of ASME Turbo Expo 2010: Power for Land, Sea and Air

    E-Print Network [OSTI]

    Thole, Karen A.

    resources in a clean manner is coal gasification. Integrated gasification combine cycle (IGCC) power plants utilize coal gasification technology to produce hydrogen and carbon monoxide based synthesis gas (syngas of Mechanical and Nuclear Engineering University Park, PA, USA ABSTRACT Demand for clean energy has increased

  4. Seth A. Lawson e-mail: seth.lawson9@gmail.com

    E-Print Network [OSTI]

    Thole, Karen A.

    that exist for utilizing available coal resources in a clean manner is coal gasification. Integrated gasification combined cycle IGCC power plants utilize coal gasification technology to produce hydrogen of Multiphase Particle Deposition on Endwall Film-Cooling Demand for clean energy has increased motivation

  5. Gasification: redefining clean energy

    SciTech Connect (OSTI)

    NONE

    2008-05-15

    This booklet gives a comprehensive overview of how gasification is redefining clean energy, now and in the future. It informs the general public about gasification in a straight-forward, non-technical manner.

  6. 2010 Worldwide Gasification Database

    DOE Data Explorer [Office of Scientific and Technical Information (OSTI)]

    The 2010 Worldwide Gasification Database describes the current world gasification industry and identifies near-term planned capacity additions. The database lists gasification projects and includes information (e.g., plant location, number and type of gasifiers, syngas capacity, feedstock, and products). The database reveals that the worldwide gasification capacity has continued to grow for the past several decades and is now at 70,817 megawatts thermal (MWth) of syngas output at 144 operating plants with a total of 412 gasifiers.

  7. Advanced Coal Wind Hybrid: Economic Analysis

    E-Print Network [OSTI]

    Phadke, Amol

    2008-01-01

    such as synthetic crude gasification combined cycle powerstand-alone integrated gasification combined cycle powertransmission integrated gasification, combined cycle power

  8. Wabash River Coal Gasification Repowering Project. Topical report, July 1992--December 1993

    SciTech Connect (OSTI)

    Not Available

    1994-01-01

    The Wabash River Coal Gasification Repowering Project (WRCGRP, or Wabash Project) is a joint venture of Destec Energy, Inc. of Houston, Texas and PSI Energy, Inc. of Plainfield, Indiana, who will jointly repower an existing 1950 vintage coal-fired steam generating plant with coal gasification combined cycle technology. The Project is located in West Terre Haute, Indiana at PSI`s existing Wabash River Generating Station. The Project will process locally-mined Indiana high-sulfur coal to produce 262 megawatts of electricity. PSI and Destec are participating in the Department of Energy Clean Coal Technology Program to demonstrate coal gasification repowering of an existing generating unit affected by the Clean Air Act Amendments. As a Clean Coal Round IV selection, the project will demonstrate integration of an existing PSI steam turbine generator and auxiliaries, a new combustion turbine generator, heat recovery steam generator tandem, and a coal gasification facility to achieve improved efficiency, reduced emissions, and reduced installation costs. Upon completion in 1995, the Project will not only represent the largest coal gasification combined cycle power plant in the United States, but will also emit lower emissions than other high sulfur coal-fired power plants and will result in a heat rate improvement of approximately 20% over the existing plant configuration. As of the end of December 1993, construction work is approximately 20% complete for the gasification portion of the Project and 25% complete for the power generation portion.

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

    E-Print Network [OSTI]

    Apps, J.A.

    2006-01-01

    Coal Gasification.IGCC technology. The coal gasification stage in IGCC plantsThe basic method for coal gasification in IGCC plants has

  10. Chemical Looping Gasification for Hydrogen Enhanced Syngas Production with In-Situ CO2 Capture

    SciTech Connect (OSTI)

    Kathe, Mandar; Xu, Dikai; Hsieh, Tien-Lin; Simpson, James; Statnick, Robert; Tong, Andrew; Fan, Liang-Shih

    2014-12-31

    This document is the final report for the project titled “Chemical Looping Gasification for Hydrogen Enhanced Syngas Production with In-Situ CO2 Capture” under award number FE0012136 for the performance period 10/01/2013 to 12/31/2014.This project investigates the novel Ohio State chemical looping gasification technology for high efficiency, cost efficiency coal gasification for IGCC and methanol production application. The project developed an optimized oxygen carrier composition, demonstrated the feasibility of the concept and completed cold-flow model studies. WorleyParsons completed a techno-economic analysis which showed that for a coal only feed with carbon capture, the OSU CLG technology reduced the methanol required selling price by 21%, lowered the capital costs by 28%, increased coal consumption efficiency by 14%. Further, using the Ohio State Chemical Looping Gasification technology resulted in a methanol required selling price which was lower than the reference non-capture case.

  11. Steam-Coal Gasification Using CaO and KOH for in Situ Carbon and Sulfur Capture

    E-Print Network [OSTI]

    Litster, Shawn

    for integration with existing natural gas combined cycle power plants16,17 while meeting proposed U.S. EPA regul and ash in the precalcined feedstock. 1. INTRODUCTION There are multiple coal power plant designs with CO2Steam-Coal Gasification Using CaO and KOH for in Situ Carbon and Sulfur Capture Nicholas S. Siefert

  12. Calderon coal gasification Process Development Unit design and test program

    SciTech Connect (OSTI)

    Calderon, A.; Madison, E.; Probert, P.

    1992-01-01

    The Process Development Unit (PDU) was designed and constructed to demonstrate the novel Calderon gasification/hot gas cleanup process. in the process, run-of-mine high sulfur coal is first pyrolyzed to recover a rich gas (medium Btu gas), after which the resulting char is subjected to airblown gasification to yield a lean gas (low Btu gas). The process incorporates a proprietary integrated system for the conversion of coal to gases and for the hot cleanup of the gases which removes both particulate and sulfur components of the gaseous products. The yields are: a syngas (CO and H[sub 2] mix) suitable for further conversion to liquid fuel (e.g. methanol/gasoline), and a lean gas suitable to fuel the combustion turbine of a combined cycle power generation plant with very low levels of NO[sub x] (15 ppmv). The fused slag (from the gasified char ash content) and the sulfur recovered during the hot gas cleanup will be sold as by-products. The small quantity of spent sorbent generated will be combined with the coal feed as a fluxing agent for the slag. The small quantity of wastewater from slag drainings and steam generation blowdown will be mixed with the coal feed for disposal. The Calderon gasification/hot gas cleanup, which is a completely closed system, operates at a pressure suitable for combined cycle power generation.

  13. Calderon coal gasification Process Development Unit design and test program

    SciTech Connect (OSTI)

    Calderon, A.; Madison, E.; Probert, P.

    1992-11-01

    The Process Development Unit (PDU) was designed and constructed to demonstrate the novel Calderon gasification/hot gas cleanup process. in the process, run-of-mine high sulfur coal is first pyrolyzed to recover a rich gas (medium Btu gas), after which the resulting char is subjected to airblown gasification to yield a lean gas (low Btu gas). The process incorporates a proprietary integrated system for the conversion of coal to gases and for the hot cleanup of the gases which removes both particulate and sulfur components of the gaseous products. The yields are: a syngas (CO and H{sub 2} mix) suitable for further conversion to liquid fuel (e.g. methanol/gasoline), and a lean gas suitable to fuel the combustion turbine of a combined cycle power generation plant with very low levels of NO{sub x} (15 ppmv). The fused slag (from the gasified char ash content) and the sulfur recovered during the hot gas cleanup will be sold as by-products. The small quantity of spent sorbent generated will be combined with the coal feed as a fluxing agent for the slag. The small quantity of wastewater from slag drainings and steam generation blowdown will be mixed with the coal feed for disposal. The Calderon gasification/hot gas cleanup, which is a completely closed system, operates at a pressure suitable for combined cycle power generation.

  14. 2007 gasification technologies workshop papers

    SciTech Connect (OSTI)

    NONE

    2007-03-15

    Topics covered in this workshop are fundamentals of gasification, carbon capture, reviews of financial and regulatory incentives, coal to liquids, and focus on gasification in the Western US.

  15. Gasification-based biomass

    SciTech Connect (OSTI)

    None, None

    2009-01-18

    The gasification-based biomass section of the Renewable Energy Technology Characterizations describes the technical and economic status of this emerging renewable energy option for electricity supply.

  16. Gasification: A Cornerstone Technology

    SciTech Connect (OSTI)

    Gary Stiegel

    2008-03-26

    NETL is a leader in the science and technology of gasification - a process for the conversion of carbon-based materials such as coal into synthesis gas (syngas) that can be used to produce clean electrical energy, transportation fuels, and chemicals efficiently and cost-effectively using domestic fuel resources. Gasification is a cornerstone technology of 21st century zero emissions powerplants

  17. Gasification: A Cornerstone Technology

    ScienceCinema (OSTI)

    Gary Stiegel

    2010-01-08

    NETL is a leader in the science and technology of gasification - a process for the conversion of carbon-based materials such as coal into synthesis gas (syngas) that can be used to produce clean electrical energy, transportation fuels, and chemicals efficiently and cost-effectively using domestic fuel resources. Gasification is a cornerstone technology of 21st century zero emissions powerplants

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

    E-Print Network [OSTI]

    condensing-extraction steam turbine (CEST) systems, the present-day commercial technology for electricity-competitive with conventional condensing-ex- traction steam-turbine (CEST) technology using biomass by-products of sugarcaneA review of biomass integrated-gasifier/gas turbine combined cycle technology and its application

  19. Combined-cycle solarised gas turbine with steam, organic and CO2 bottoming cycles

    E-Print Network [OSTI]

    of the new dish has been characterised, and, more recently, on-sun thermal tests have been performed, optimised for the new SG4 collector. This study aims to determine whether a combined-cycle gas turbine (CCGT) cycle could be viable with the SG4 collector. The intention would be to have a Brayton cycle engine

  20. Apparatus and methods for supplying auxiliary steam in a combined cycle system

    DOE Patents [OSTI]

    Gorman, William G. (Ballston Spa, NY); Carberg, William George (Ballston Spa, NY); Jones, Charles Michael (Ballston Lake, NY)

    2002-01-01

    To provide auxiliary steam, a low pressure valve is opened in a combined cycle system to divert low pressure steam from the heat recovery steam generator to a header for supplying steam to a second combined cycle's steam turbine seals, sparging devices and cooling steam for the steam turbine if the steam turbine and gas turbine lie on a common shaft with the generator. Cooling steam is supplied the gas turbine in the combined cycle system from the high pressure steam turbine. Spent gas turbine cooling steam may augment the low pressure steam supplied to the header by opening a high pressure valve whereby high and low pressure steam flows are combined. An attemperator is used to reduce the temperature of the combined steam in response to auxiliary steam flows above a predetermined flow and a steam header temperature above a predetermined temperature. The auxiliary steam may be used to start additional combined cycle units or to provide a host unit with steam turbine cooling and sealing steam during full-speed no-load operation after a load rejection.

  1. Environmental Assessment for the Warren Station externally fired combined cycle demonstration project

    SciTech Connect (OSTI)

    1995-04-01

    The proposed Penelec project is one of 5 projects for potential funding under the fifth solicitation under the Clean Coal Technology program. In Penelec, two existing boilers would be replaced at Warren Station, PA; the new unit would produce 73 MW(e) in a combined cycle mode (using both gas-fired and steam turbines). The project would fill the need for a full utility-size demonstration of externally fire combined cycle (EFCC) technology as the next step toward commercialization. This environmental assessment was prepared for compliance with NEPA; its purpose is to provide sufficient basis for determining whether to prepare an environmental impact statement or to issue a finding of no significant impact. It is divided into the sections: purpose and need for proposed action; alternatives; brief description of affected environment; environmental consequences, including discussion of commercial operation beyond the demonstration period.

  2. BIOMASS GASIFICATION AND POWER GENERATION USING ADVANCED GAS TURBINE SYSTEMS

    SciTech Connect (OSTI)

    David Liscinsky

    2002-10-20

    A multidisciplined team led by the United Technologies Research Center (UTRC) and consisting of Pratt & Whitney Power Systems (PWPS), the University of North Dakota Energy & Environmental Research Center (EERC), KraftWork Systems, Inc. (kWS), and the Connecticut Resource Recovery Authority (CRRA) has evaluated a variety of gasified biomass fuels, integrated into advanced gas turbine-based power systems. The team has concluded that a biomass integrated gasification combined-cycle (BIGCC) plant with an overall integrated system efficiency of 45% (HHV) at emission levels of less than half of New Source Performance Standards (NSPS) is technically and economically feasible. The higher process efficiency in itself reduces consumption of premium fuels currently used for power generation including those from foreign sources. In addition, the advanced gasification process can be used to generate fuels and chemicals, such as low-cost hydrogen and syngas for chemical synthesis, as well as baseload power. The conceptual design of the plant consists of an air-blown circulating fluidized-bed Advanced Transport Gasifier and a PWPS FT8 TwinPac{trademark} aeroderivative gas turbine operated in combined cycle to produce {approx}80 MWe. This system uses advanced technology commercial products in combination with components in advanced development or demonstration stages, thereby maximizing the opportunity for early implementation. The biofueled power system was found to have a levelized cost of electricity competitive with other new power system alternatives including larger scale natural gas combined cycles. The key elements are: (1) An Advanced Transport Gasifier (ATG) circulating fluid-bed gasifier having wide fuel flexibility and high gasification efficiency; (2) An FT8 TwinPac{trademark}-based combined cycle of approximately 80 MWe; (3) Sustainable biomass primary fuel source at low cost and potentially widespread availability-refuse-derived fuel (RDF); (4) An overall integrated system that exceeds the U.S. Department of Energy (DOE) goal of 40% (HHV) efficiency at emission levels well below the DOE suggested limits; and (5) An advanced biofueled power system whose levelized cost of electricity can be competitive with other new power system alternatives.

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

    SciTech Connect (OSTI)

    Nezammahalleh, H.; Farhadi, F.; Tanhaemami, M.

    2010-09-15

    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)

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

    SciTech Connect (OSTI)

    Kenneth A. Yackly

    2005-12-01

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

  5. Pressurized solid oxide fuel cell/gas turbine combined cycle systems

    SciTech Connect (OSTI)

    George, R.A.

    1997-12-31

    Over the last 10 years, Westinghouse Electric Corporation has made great strides in advancing tubular solid oxide fuel cell (SOFC) technology towards commercialization by the year 2001. In 1993, Westinghouse initiated a program to develop pressurized solid oxide fuel cell/gas turbine (PSOFC/GT) combined cycle power systems because of the ultra-high electrical efficiencies, 60-75% (net AC/LHV CH4), inherent with these systems. This paper will discuss SOFC technology advancements in recent years, and the final phase development program which will focus on the development and demonstration of PSOFC/GT power systems for distributed power applications.

  6. Underground coal gasification. Presentations

    SciTech Connect (OSTI)

    NONE

    2007-07-01

    The 8 presentations are: underground coal gasification (UCG) and the possibilities for carbon management (J. Friedmann); comparing the economics of UCG with surface gasification technologies (E. Redman); Eskom develops UCG technology project (C. Gross); development and future of UCG in the Asian region (L. Walker); economically developing vast deep Powder River Basin coals with UCG (S. Morzenti); effectively managing UCG environmental issues (E. Burton); demonstrating modelling complexity of environmental risk management; and UCG research at the University of Queensland, Australia (A.Y. Klimenko).

  7. Gas cleanup for combined cycle power generation using a hot gas conditioning catalyst

    SciTech Connect (OSTI)

    Paisley, M.A.; Gebhard, S.C.

    1995-11-01

    Biomass gasification provides the potential to efficiently and economically produce a renewable source of a clean gaseous fuel suitable for power generation or synthesis gas (syngas) applications. Biomass as the feedstock for the process is uniquely suited to this application because it provides the means to increase the nation`s energy security, and also, to potentially provide a more stable agricultural industry. An important side benefit of the use of biomass is the effective minimization of the primary greenhouse gas, carbon dioxide (CO{sub 2}), by providing a means to close-loop the CO{sub 2} cycle. However, high molecular weight hydrocarbon constituents (tar) in the product gas from gasification can complicate the downstream uses of the gas. This paper discusses both the development of a low cost, disposable catalyst system that can eliminate these heavy hydrocarbons from the gas and the use of the catalyst in conjunction with the Battelle high-throughput gasification process for power generation systems.

  8. GASIFICATION FOR DISTRIBUTED GENERATION

    SciTech Connect (OSTI)

    Ronald C. Timpe; Michael D. Mann; Darren D. Schmidt

    2000-05-01

    A recent emphasis in gasification technology development has been directed toward reduced-scale gasifier systems for distributed generation at remote sites. The domestic distributed power generation market over the next decade is expected to be 5-6 gigawatts per year. The global increase is expected at 20 gigawatts over the next decade. The economics of gasification for distributed power generation are significantly improved when fuel transport is minimized. Until recently, gasification technology has been synonymous with coal conversion. Presently, however, interest centers on providing clean-burning fuel to remote sites that are not necessarily near coal supplies but have sufficient alternative carbonaceous material to feed a small gasifier. Gasifiers up to 50 MW are of current interest, with emphasis on those of 5-MW generating capacity. Internal combustion engines offer a more robust system for utilizing the fuel gas, while fuel cells and microturbines offer higher electric conversion efficiencies. The initial focus of this multiyear effort was on internal combustion engines and microturbines as more realistic near-term options for distributed generation. In this project, we studied emerging gasification technologies that can provide gas from regionally available feedstock as fuel to power generators under 30 MW in a distributed generation setting. Larger-scale gasification, primarily coal-fed, has been used commercially for more than 50 years to produce clean synthesis gas for the refining, chemical, and power industries. Commercial-scale gasification activities are under way at 113 sites in 22 countries in North and South America, Europe, Asia, Africa, and Australia, according to the Gasification Technologies Council. Gasification studies were carried out on alfalfa, black liquor (a high-sodium waste from the pulp industry), cow manure, and willow on the laboratory scale and on alfalfa, black liquor, and willow on the bench scale. Initial parametric tests evaluated through reactivity and product composition were carried out on thermogravimetric analysis (TGA) equipment. These tests were evaluated and then followed by bench-scale studies at 1123 K using an integrated bench-scale fluidized-bed gasifier (IBG) which can be operated in the semicontinuous batch mode. Products from tests were solid (ash), liquid (tar), and gas. Tar was separated on an open chromatographic column. Analysis of the gas product was carried out using on-line Fourier transform infrared spectroscopy (FT-IR). For selected tests, gas was collected periodically and analyzed using a refinery gas analyzer GC (gas chromatograph). The solid product was not extensively analyzed. This report is a part of a search into emerging gasification technologies that can provide power under 30 MW in a distributed generation setting. Larger-scale gasification has been used commercially for more than 50 years to produce clean synthesis gas for the refining, chemical, and power industries, and it is probable that scaled-down applications for use in remote areas will become viable. The appendix to this report contains a list, description, and sources of currently available gasification technologies that could be or are being commercially applied for distributed generation. This list was gathered from current sources and provides information about the supplier, the relative size range, and the status of the technology.

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

    SciTech Connect (OSTI)

    Kenneth A. Yackly

    2004-09-30

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

  10. Gasification of black liquor

    DOE Patents [OSTI]

    Kohl, Arthur L. (Woodland Hills, CA)

    1987-07-28

    A concentrated aqueous black liquor containing carbonaceous material and alkali metal sulfur compounds is treated in a gasifier vessel containing a relatively shallow molten salt pool at its bottom to form a combustible gas and a sulfide-rich melt. The gasifier vessel, which is preferably pressurized, has a black liquor drying zone at its upper part, a black liquor solids gasification zone located below the drying zone, and a molten salt sulfur reduction zone which comprises the molten salt pool. A first portion of an oxygen-containing gas is introduced into the gas space in the gasification zone immediatley above the molten salt pool. The remainder of the oxygen-containing gas is introduced into the molten salt pool in an amount sufficient to cause gasification of carbonaceous material entering the pool from the gasification zone but not sufficient to create oxidizing conditions in the pool. The total amount of the oxygen-containing gas introduced both above the pool and into the pool constitutes between 25 and 55% of the amount required for complete combustion of the black liquor feed. A combustible gas is withdrawn from an upper portion of the drying zone, and a melt in which the sulfur content is predominantly in the form of alkali metal sulfide is withdrawn from the molten salt sulfur reduction zone.

  11. Gasification of black liquor

    DOE Patents [OSTI]

    Kohl, A.L.

    1987-07-28

    A concentrated aqueous black liquor containing carbonaceous material and alkali metal sulfur compounds is treated in a gasifier vessel containing a relatively shallow molten salt pool at its bottom to form a combustible gas and a sulfide-rich melt. The gasifier vessel, which is preferably pressurized, has a black liquor drying zone at its upper part, a black liquor solids gasification zone located below the drying zone, and a molten salt sulfur reduction zone which comprises the molten salt pool. A first portion of an oxygen-containing gas is introduced into the gas space in the gasification zone immediately above the molten salt pool. The remainder of the oxygen-containing gas is introduced into the molten salt pool in an amount sufficient to cause gasification of carbonaceous material entering the pool from the gasification zone but not sufficient to create oxidizing conditions in the pool. The total amount of the oxygen-containing gas introduced both above the pool and into the pool constitutes between 25 and 55% of the amount required for complete combustion of the black liquor feed. A combustible gas is withdrawn from an upper portion of the drying zone, and a melt in which the sulfur content is predominantly in the form of alkali metal sulfide is withdrawn from the molten salt sulfur reduction zone. 2 figs.

  12. Potential trace element emissions from the gasification of Illinois...

    Office of Scientific and Technical Information (OSTI)

    GASIFICATION PLANTS; ENVIRONMENTAL EFFECTS; ABSORPTION SPECTROSCOPY; ACTIVATION ANALYSIS; AIR POLLUTION; BERYLLIUM; COAL GASIFICATION; ELEMENTS; FLOWSHEETS; FLUORESCENCE...

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

    SciTech Connect (OSTI)

    1988-04-28

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

  14. Coal Gasification and Transportation Fuels Magazine

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

    Coal Gasification and Transportation Fuels Magazine Current Edition: Coal Gasification and Transportation Fuels Quarterly News, Vol.1, Issue 4 (July 2015) Archived Editions: Coal...

  15. Hydrogen Production Cost Estimate Using Biomass Gasification...

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

    Cost Estimate Using Biomass Gasification: Independent Review Hydrogen Production Cost Estimate Using Biomass Gasification: Independent Review This independent review is the...

  16. Advanced Biomass Gasification Projects

    SciTech Connect (OSTI)

    Not Available

    1997-08-01

    DOE has a major initiative under way to demonstrate two high-efficiency gasification systems for converting biomass into electricity. As this fact sheet explains, the Biomass Power Program is cost-sharing two scale-up projects with industry in Hawaii and Vermont that, if successful, will provide substantial market pull for U.S. biomass technologies, and provide a significant market edge over competing foreign technologies.

  17. Recovery Act: Johnston Rhode Island Combined Cycle Electric Generating Plant Fueled by Waste Landfill Gas

    SciTech Connect (OSTI)

    Galowitz, Stephen

    2013-06-30

    The primary objective of the Project was to maximize the productive use of the substantial quantities of waste landfill gas generated and collected at the Central Landfill in Johnston, Rhode Island. An extensive analysis was conducted and it was determined that utilization of the waste gas for power generation in a combustion turbine combined cycle facility was the highest and best use. The resulting project reflected a cost effective balance of the following specific sub-objectives. 1) Meet environmental and regulatory requirements, particularly the compliance obligations imposed on the landfill to collect, process and destroy landfill gas. 2) Utilize proven and reliable technology and equipment. 3) Maximize electrical efficiency. 4) Maximize electric generating capacity, consistent with the anticipated quantities of landfill gas generated and collected at the Central Landfill. 5) Maximize equipment uptime. 6) Minimize water consumption. 7) Minimize post-combustion emissions. To achieve the Project Objective the project consisted of several components. 1) The landfill gas collection system was modified and upgraded. 2) A State-of-the Art gas clean up and compression facility was constructed. 3) A high pressure pipeline was constructed to convey cleaned landfill gas from the clean-up and compression facility to the power plant. 4) A combined cycle electric generating facility was constructed consisting of combustion turbine generator sets, heat recovery steam generators and a steam turbine. 5) The voltage of the electricity produced was increased at a newly constructed transformer/substation and the electricity was delivered to the local transmission system. The Project produced a myriad of beneficial impacts. 1) The Project created 453 FTE construction and manufacturing jobs and 25 FTE permanent jobs associated with the operation and maintenance of the plant and equipment. 2) By combining state-of-the-art gas clean up systems with post combustion emissions control systems, the Project established new national standards for best available control technology (BACT). 3) The Project will annually produce 365,292 MWh?s of clean energy. 4) By destroying the methane in the landfill gas, the Project will generate CO{sub 2} equivalent reductions of 164,938 tons annually. The completed facility produces 28.3 MWnet and operates 24 hours a day, seven days a week.

  18. Tampa electric company - IGCC project. Quarterly report, January 1, 1996--March 31, 1996

    SciTech Connect (OSTI)

    1998-02-01

    This quarterly report consists of materials presented at a recent review of the project. The project is an IGCC project being conducted by Tampa Electric Company. The report describes the status of the facility construction, components, operations staff training, and discusses aspects of the project which may impact the final scheduled completion.

  19. Aspen Process Flowsheet Simulation Model of a Battelle Biomass-Based Gasification, Fischer-Tropsch Liquefaction and Combined-Cycle Power Plant

    SciTech Connect (OSTI)

    None

    1998-10-30

    This study was done to support the research and development program of the National Renewable Energy Laboratory (NREL) in the thermochemical conversion of biomass to liquid transportation fuels using current state-of-the-art technology. The Mitretek study investigated the use of two biomass gasifiers; the RENUGAS gasifier being developed by the Institute of Gas Technology, and the indirectly heated gasifier being developed by Battelle Columbus. The Battelle Memorial Institute of Columbus, Ohio indirectly heated biomass gasifier was selected for this model development because the syngas produced by it is better suited for Fischer-Tropsch synthesis with an iron-based catalyst for which a large amount of experimental data are available. Bechtel with Amoco as a subcontractor developed a conceptual baseline design and several alternative designs for indirect coal liquefaction facilities. In addition, ASPEN Plus process flowsheet simulation models were developed for each of designs. These models were used to perform several parametric studies to investigate various alternatives for improving the economics of indirect coal liquefaction.

  20. PNNL Coal Gasification Research

    SciTech Connect (OSTI)

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

    2010-07-28

    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.

  1. Gasification Systems Publications

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

    AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative Fuels Data Center Homesum_a_epg0_fpd_mmcf_m.xls" ,"Available from WebQuantityBonneville Power Administration would likeUniverse (Journal Article)ForthcomingGENERALProblems I n QEstimatesPlantGasification

  2. NETL: Coal Gasification Systems

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

    AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative Fuels Data Center Homesum_a_epg0_fpd_mmcf_m.xls" ,"Available from WebQuantity ofkandz-cm11 Outreach Home Room NewsInformationJessework usesof Energy Moving Basic NERSC TrainingPartnershipsGasification

  3. Economic Analysis of a 3MW Biomass Gasification Power Plant

    E-Print Network [OSTI]

    Cattolica, Robert; Lin, Kathy

    2009-01-01

    Collaborative, Biomass gasification / power generationANALYSIS OF A 3MW BIOMASS GASIFICATION POWER PLANT R obert Cbiomass. Figure 1: Biomass Gasification to Power Process

  4. Economic Analysis of a 3MW Biomass Gasification Power Plant

    E-Print Network [OSTI]

    Cattolica, Robert; Lin, Kathy

    2009-01-01

    Collaborative, Biomass gasification / power generationANALYSIS OF A 3MW BIOMASS GASIFICATION POWER PLANT R obert Cinvolved in the gasification of biomass to produce gas are

  5. Recovery Act: Brea California Combined Cycle Electric Generating Plant Fueled by Waste Landfill Gas

    SciTech Connect (OSTI)

    Galowitz, Stephen

    2012-12-31

    The primary objective of the Project was to maximize the productive use of the substantial quantities of waste landfill gas generated and collected at the Olinda Landfill near Brea, California. An extensive analysis was conducted and it was determined that utilization of the waste gas for power generation in a combustion turbine combined cycle facility was the highest and best use. The resulting Project reflected a cost effective balance of the following specific sub-objectives: • Meeting the environmental and regulatory requirements, particularly the compliance obligations imposed on the landfill to collect, process and destroy landfill gas • Utilizing proven and reliable technology and equipment • Maximizing electrical efficiency • Maximizing electric generating capacity, consistent with the anticipated quantities of landfill gas generated and collected at the Olinda Landfill • Maximizing equipment uptime • Minimizing water consumption • Minimizing post-combustion emissions • The Project produced and will produce a myriad of beneficial impacts. o The Project created 360 FTE construction and manufacturing jobs and 15 FTE permanent jobs associated with the operation and maintenance of the plant and equipment. o By combining state-of-the-art gas clean up systems with post combustion emissions control systems, the Project established new national standards for best available control technology (BACT). o The Project will annually produce 280,320 MWh’s of clean energy o By destroying the methane in the landfill gas, the Project will generate CO2 equivalent reductions of 164,938 tons annually. The completed facility produces 27.4 MWnet and operates 24 hours a day, seven days a week.

  6. CX-000422: Categorical Exclusion Determination

    Broader source: Energy.gov [DOE]

    Carbon Dioxide Capture From Integrated Gasification Combined Cycle (IGCC) Gas Streams Using the Ammonium Carbonate-Ammonium Bicarbonate (AC-ABC) ProcessCX(s) Applied: B3.6Date: 12/11/2009Location(s): CaliforniaOffice(s): Fossil Energy, National Energy Technology Laboratory

  7. CX-001643: Categorical Exclusion Determination

    Broader source: Energy.gov [DOE]

    Scale-Up of Hydrogen Transport Membranes (HTM) for Integrated Gasification Combined Cycle (IGCC) and FutureGen Coal-to-Hydrogen Plants (Boulder)CX(s) Applied: B3.6Date: 04/23/2010Location(s): Boulder, ColoradoOffice(s): Fossil Energy, National Energy Technology Laboratory

  8. Sulfurization of carbon surface for vapor phase mercury removal I: Effect of temperature and sulfurization protocol

    E-Print Network [OSTI]

    Borguet, Eric

    a fixed bed reactor system to determine the effects of sorbent properties, temperature (200­800 °C; Impregnation; Temperature programmed desorption; Surface properties 1. Introduction Hydrogen sulfide, such as the Integrated Gasification Combined Cycle (IGCC) process [4], and the coal gas cleaning process [5], removal

  9. NOx emission characteristics of counterflow syngas diffusion flames with airstream dilution

    E-Print Network [OSTI]

    Aggarwal, Suresh K.

    a viable fuel for electric power generation using integrated gasification combined cycle (IGCC) systems [3 is being recognized as a viable energy source worldwide, particularly for stationary power generation to its high specific heat that decreases the thermal NO, and its ability to significantly reduce

  10. Clean coal technologies in electric power generation: a brief overview

    SciTech Connect (OSTI)

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

    2006-07-15

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

  11. Sensing Requirements for Real-Time Monitoring and Control in Energy Production

    E-Print Network [OSTI]

    Ghosh, Ruby N.

    combined cycle (IGCC) power plant is a minimally polluting, energy efficient and cost effective technique is gasification, the generation of synthetic gas (syngas). In the Wabash project a 1950's steam turbine of coal (syngas), requires physical and chemical sensors for exhaust gas monitoring as well as real

  12. Coal Problems 1. Name two examples of clean coal technology and in what manner do they clean the coal?

    E-Print Network [OSTI]

    Bowen, James D.

    Coal Problems 1. Name two examples of clean coal technology and in what manner do they clean the coal? a. Coal Washing- Crushing coal then mixing it with a liquid to allow the impurities to settle. b burning coal altogether. With integrated gasification combined cycle (IGCC) systems, steam and hot

  13. Polk power station syngas cooling system

    SciTech Connect (OSTI)

    Jenkins, S.D.

    1995-01-01

    Tampa Electric Company (TEC) is in the site development and construction phase of the new Polk Power Station Unit No. 1. This will be the first unit at a new site and will use Integrated Gasification Combined Cycle (IGCC) Technology. The unit will utilize Texaco`s oxygen-blown, entrained-flow coal gasification, along with combined cycle power generation, to produce nominal 260MW. Integral to the gasification process is the syngas cooling system. The design, integration, fabrication, transportation, and erection of this equipment have provided and continue to provide major challenges for this project.

  14. Catalytic Hydrothermal Gasification of Biomass

    SciTech Connect (OSTI)

    Elliott, Douglas C.

    2008-05-06

    A recent development in biomass gasification is the use of a pressurized water processing environment in order that drying of the biomass can be avoided. This paper reviews the research undertaken developing this new option for biomass gasification. This review does not cover wet oxidation or near-atmospheric-pressure steam-gasification of biomass. Laboratory research on hydrothermal gasification of biomass focusing on the use of catalysts is reviewed here, and a companion review focuses on non-catalytic processing. Research includes liquid-phase, sub-critical processing as well as super-critical water processing. The use of heterogeneous catalysts in such a system allows effective operation at lower temperatures, and the issues around the use of catalysts are presented. This review attempts to show the potential of this new processing concept by comparing the various options under development and the results of the research.

  15. Coal gasification vessel

    DOE Patents [OSTI]

    Loo, Billy W. (Oakland, CA)

    1982-01-01

    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).

  16. Coal liquefaction and gasification technologies

    SciTech Connect (OSTI)

    Mangold, E.C.; Muradaz, M.A.; Ouellette, R.P.; Farah, O.G.; Cheremisinoff, P.N.

    1982-01-01

    The state-of-the-art of selected coal liquefaction and gasification processes developed with support from the United States are reviewed. The Exxon Donor Solvent, H-Coal, SRC-I, SRC-II, Mobile Gasoline Synthesis, Fischer-Tropsch Synthesis, and Zinc Halide Hydrocracking liquefaction processes and the Slagging Lurgi, Texaco, Combustion Engineering, COGAS, and Shell-Koppers gasification processes are covered. Separate abstracts were prepared for 5 chapters.

  17. Materials of Gasification

    SciTech Connect (OSTI)

    2005-09-15

    The objective of this project was to accumulate and establish a database of construction materials, coatings, refractory liners, and transitional materials that are appropriate for the hardware and scale-up facilities for atmospheric biomass and coal gasification processes. Cost, fabricability, survivability, contamination, modes of corrosion, failure modes, operational temperatures, strength, and compatibility are all areas of materials science for which relevant data would be appropriate. The goal will be an established expertise of materials for the fossil energy area within WRI. This would be an effort to narrow down the overwhelming array of materials information sources to the relevant set which provides current and accurate data for materials selection for fossil fuels processing plant. A significant amount of reference material on materials has been located, examined and compiled. The report that describes these resources is well under way. The reference material is in many forms including texts, periodicals, websites, software and expert systems. The most important part of the labor is to refine the vast array of available resources to information appropriate in content, size and reliability for the tasks conducted by WRI and its clients within the energy field. A significant has been made to collate and capture the best and most up to date references. The resources of the University of Wyoming have been used extensively as a local and assessable location of information. As such, the distribution of materials within the UW library has been added as a portion of the growing document. Literature from recent journals has been combed for all pertinent references to high temperature energy based applications. Several software packages have been examined for relevance and usefulness towards applications in coal gasification and coal fired plant. Collation of the many located resources has been ongoing. Some web-based resources have been examined.

  18. June 2007 gasification technologies workshop papers

    SciTech Connect (OSTI)

    NONE

    2007-06-15

    Topics covered in this workshop are fundamentals of gasification, carbon capture and sequestration, reviews of financial and regulatory incentives, co-production, and focus on gasification in the Western US.

  19. EIS-0382: Mesaba Energy Project Itasca County, Minnesota

    Broader source: Energy.gov [DOE]

    NOTE: All DOE funding has been expended. This EIS evalutes the environmental impacts of a proposal to construct and demonstrate a commercial utility-scale next-generation Integrated Gasification Combined Cycle (IGCC) electric power generating facility having a capacity of 606 MWe (net). It will incorporate over 1,600 design and operational lessons learned from the successful but smaller-scale 262 MWe (net) Wabash River Coal Gasification Repowering Project, located in Terre Haute, Indiana.

  20. Beluga Coal Gasification - ISER

    SciTech Connect (OSTI)

    Steve Colt

    2008-12-31

    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.

  1. Hydrogen and electricity: Parallels, interactions,and convergence

    E-Print Network [OSTI]

    Yang, Christopher

    2008-01-01

    such as natural gas combined cycle (NGCC) or solid oxidewind, natural gas combined cycle (NGCC), natural gascoal integrated gasi?cation combined cycle (IGCC), and coal

  2. Water Challenges for Geologic Carbon Capture and Sequestration

    E-Print Network [OSTI]

    Newmark, Robin L.; Friedmann, Samuel J.; Carroll, Susan A.

    2010-01-01

    represents natural gas combined cycle, PC Sub and PC Superintegrated gasi?cation combined cycle (IGCC) plants withand natural gas combined cycle (NGCC) with amine capture (

  3. High-reliability gas-turbine combined-cycle development program: Phase II, Volume 3. Final report

    SciTech Connect (OSTI)

    Hecht, K.G.; Sanderson, R.A.; Smith, M.J.

    1982-01-01

    This three-volume report presents the results of Phase II of the multiphase EPRI-sponsored High-Reliability Gas Turbine Combined-Cycle Development Program whose goal is to achieve a highly reliable gas turbine combined-cycle power plant, available by the mid-1980s, which would be an economically attractive baseload generation alternative for the electric utility industry. The Phase II program objective was to prepare the preliminary design of this power plant. The power plant was addressed in three areas: (1) the gas turbine, (2) the gas turbine ancillaries, and (3) the balance of plant including the steam turbine generator. To achieve the program goals, a gas turbine was incorporated which combined proven reliability characteristics with improved performance features. This gas turbine, designated the V84.3, is the result of a cooperative effort between Kraftwerk Union AG and United Technologies Corporation. Gas turbines of similar design operating in Europe under baseload conditions have demonstrated mean time between failures in excess of 40,000. The reliability characteristics of the gas turbine ancillaries and balance-of-plant equipment were improved through system simplification and component redundancy and by selection of component with inherent high reliability. A digital control system was included with logic, communications, sensor redundancy, and manual backup. An independent condition monitoring and diagnostic system was also included. Program results provide the preliminary design of a gas turbine combined-cycle baseload power plant. This power plant has a predicted mean time between failure of nearly twice the 3000-h EPRI goal. The cost of added reliability features is offset by improved performance, which results in a comparable specific cost and an 8% lower cost of electricty compared to present market offerings.

  4. Coal gasification 2006: roadmap to commercialization

    SciTech Connect (OSTI)

    NONE

    2006-05-15

    Surging oil and gas prices, combined with supply security and environmental concerns, are prompting power generators and industrial firms to further develop coal gasification technologies. Coal gasification, the process of breaking down coal into its constituent chemical components prior to combustion, will permit the US to more effectively utilize its enormous, low cost coal reserves. The process facilitates lower environmental impact power generation and is becoming an increasingly attractive alternative to traditional generation techniques. The study is designed to inform the reader as to this rapidly evolving technology, its market penetration prospects and likely development. Contents include: Clear explanations of different coal gasification technologies; Emissions and efficiency comparisons with other fuels and technologies; Examples of US and global gasification projects - successes and failures; Commercial development and forecast data; Gasification projects by syngas output; Recommendations for greater market penetration and commercialization; Current and projected gasification technology market shares; and Recent developments including proposals for underground gasification process. 1 app.

  5. A modeling software linking approach for the analysis of an integrated reforming combined cycle with hot potassium carbonate CO[subscript 2] capture

    E-Print Network [OSTI]

    Nord, Lars Olof

    The focus of this study is the analysis of an integrated reforming combined cycle (IRCC) with natural gas as fuel input. This IRCC consisted of a hydrogen-fired gas turbine (GT) with a single-pressure steam bottoming cycle ...

  6. Tsiklauri-Durst combined cycle (T-D Cycle{trademark}) application for nuclear and fossil-fueled power generating plants

    SciTech Connect (OSTI)

    Tsiklauri, B.; Korolev, V.N.; Durst, B.M.; Shen, P.K.

    1998-07-01

    The Tsiklauri-Durst combined cycle is a combination of the best attributes of both nuclear power and combined cycle gas power plants. A technology patented in 1994 by Battelle Memorial Institute offers a synergistic approach to power generation. A typical combined cycle is defined as the combination of gas turbine Brayton Cycle, topping steam turbine Rankine Cycle. Exhaust from the gas turbine is used in heat recovery steam generators to produce steam for a steam turbine. In a standard combined cycle gas turbine-steam turbine application, the gas turbine generates about 65 to 70 percent of system power. The thermal efficiency for such an installation is typically about 45 to 50 percent. A T-D combined cycle takes a new, creative approach to combined cycle design by directly mixing high enthalpy steam from the heat recovery steam generator, involving the steam generator at more than one pressure. Direct mixing of superheated and saturated steam eliminates the requirement for a large heat exchanger, making plant modification simple and economical.

  7. Hydrogen-or-Fossil-Combustion Nuclear Combined-Cycle Systems for Base- and Peak-Load Electricity Production

    SciTech Connect (OSTI)

    Forsberg, Charles W; Conklin, Jim

    2007-09-01

    A combined-cycle power plant is described that uses (1) heat from a high-temperature nuclear reactor to meet base-load electrical demands and (2) heat from the same high-temperature reactor and burning natural gas, jet fuel, or hydrogen to meet peak-load electrical demands. For base-load electricity production, fresh air is compressed; then flows through a heat exchanger, where it is heated to between 700 and 900 C by heat provided by a high-temperature nuclear reactor via an intermediate heat-transport loop; and finally exits through a high-temperature gas turbine to produce electricity. The hot exhaust from the Brayton-cycle gas turbine is then fed to a heat recovery steam generator that provides steam to a steam turbine for added electrical power production. To meet peak electricity demand, the air is first compressed and then heated with the heat from a high-temperature reactor. Natural gas, jet fuel, or hydrogen is then injected into the hot air in a combustion chamber, combusts, and heats the air to 1300 C-the operating conditions for a standard natural-gas-fired combined-cycle plant. The hot gas then flows through a gas turbine and a heat recovery steam generator before being sent to the exhaust stack. The higher temperatures increase the plant efficiency and power output. If hydrogen is used, it can be produced at night using energy from the nuclear reactor and stored until needed. With hydrogen serving as the auxiliary fuel for peak power production, the electricity output to the electric grid can vary from zero (i.e., when hydrogen is being produced) to the maximum peak power while the nuclear reactor operates at constant load. Because nuclear heat raises air temperatures above the auto-ignition temperatures of the various fuels and powers the air compressor, the power output can be varied rapidly (compared with the capabilities of fossil-fired turbines) to meet spinning reserve requirements and stabilize the electric grid. This combined cycle uses the unique characteristics of high-temperature reactors (T>700 C) to produce electricity for premium electric markets whose demands can not be met by other types of nuclear reactors. It may also make the use of nuclear reactors economically feasible in smaller electrical grids, such as those found in many developing countries. The ability to rapidly vary power output can be used to stabilize electric grid performance-a particularly important need in small electrical grids.

  8. Economic Analysis of a 3MW Biomass Gasification Power Plant

    E-Print Network [OSTI]

    Cattolica, Robert; Lin, Kathy

    2009-01-01

    Collaborative, Biomass gasification / power generationANALYSIS OF A 3MW BIOMASS GASIFICATION POWER PLANT R obert Cas a feedstock for gasification for a 3 MW power plant was

  9. Development and Application of Advanced Models for Steam Hydrogasification: Process Design and Economic Evaluation

    E-Print Network [OSTI]

    Lu, Xiaoming

    2012-01-01

    S. Integrated Gasification Combined Cycle-A review of IGCCBiomass Gasification Combined Cycle System. December 1997.liquefaction and combined-cycle power plant. Pittsburgh (

  10. Steam Generator Component Model in a Combined Cycle of Power Conversion Unit for Very High Temperature Gas-Cooled Reactor

    SciTech Connect (OSTI)

    Oh, Chang H; Han, James; Barner, Robert; Sherman, Steven R

    2007-06-01

    The Department of Energy and the Idaho National Laboratory are developing a Next Generation Nuclear Plant (NGNP), Very High Temperature Gas-Cooled Reactor (VHTR) to serve as a demonstration of state-of-the-art nuclear technology. The purpose of the demonstration is two fold 1) efficient low cost energy generation and 2) hydrogen production. Although a next generation plant could be developed as a single-purpose facility, early designs are expected to be dual-purpose. While hydrogen production and advanced energy cycles are still in its early stages of development, research towards coupling a high temperature reactor, electrical generation and hydrogen production is under way. A combined cycle is considered as one of the power conversion units to be coupled to the very high-temperature gas-cooled reactor (VHTR). The combined cycle configuration consists of a Brayton top cycle coupled to a Rankine bottoming cycle by means of a steam generator. A detailed sizing and pressure drop model of a steam generator is not available in the HYSYS processes code. Therefore a four region model was developed for implementation into HYSYS. The focus of this study was the validation of a HYSYS steam generator model of two phase flow correlations. The correlations calculated the size and heat exchange of the steam generator. To assess the model, those calculations were input into a RELAP5 model and its results were compared with HYSYS results. The comparison showed many differences in parameters such as the heat transfer coefficients and revealed the different methods used by the codes. Despite differences in approach, the overall results of heat transfer were in good agreement.

  11. Gasification world database 2007. Current industry status

    SciTech Connect (OSTI)

    NONE

    2007-10-15

    Information on trends and drivers affecting the growth of the gasification industry is provided based on information in the USDOE NETL world gasification database (available on the www.netl.doe.gov website). Sectors cover syngas production in 2007, growth planned through 2010, recent industry changes, and beyond 2010 - strong growth anticipated in the United States. A list of gasification-based power plant projects, coal-to-liquid projects and coal-to-SNG projects under consideration in the USA is given.

  12. Wet Gasification of Ethanol Residue: A Preliminary Assessment

    SciTech Connect (OSTI)

    Brown, Michael D.; Elliott, Douglas C.

    2008-09-22

    A preliminary technoeconomic assessment has been made of several options for the application of catalytic hydrothermal gasification (wet gasification) to ethanol processing residues.

  13. EIS-0412: TX Energy, LLC, Industrial Gasification Facility Near...

    Office of Environmental Management (EM)

    2: TX Energy, LLC, Industrial Gasification Facility Near Beaumont, TX EIS-0412: TX Energy, LLC, Industrial Gasification Facility Near Beaumont, TX February 18, 2009 EIS-0412:...

  14. Enabling Small-Scale Biomass Gasification for Liquid Fuel Production...

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

    Enabling Small-Scale Biomass Gasification for Liquid Fuel Production Enabling Small-Scale Biomass Gasification for Liquid Fuel Production Breakout Session 2A-Conversion...

  15. Thermochemical Ethanol via Indirect Gasification and Mixed Alcohol...

    Office of Environmental Management (EM)

    Ethanol via Indirect Gasification and Mixed Alcohol Synthesis of Lignocellulosic Biomass Thermochemical Ethanol via Indirect Gasification and Mixed Alcohol Synthesis of...

  16. Underground coal gasification using oxygen and steam

    SciTech Connect (OSTI)

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

    2009-07-01

    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.

  17. Plasma gasification of coal in different oxidants

    SciTech Connect (OSTI)

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

    2008-12-15

    Oxidant selection is the highest priority for advanced coal gasification-process development. This paper presents comparative analysis of the Powder River Basin bituminous-coal gasification processes for entrained-flow plasma gasifier. Several oxidants, which might be employed for perspective commercial applications, have been chosen, including air, steam/carbon-dioxide blend, carbon dioxide, steam, steam/air, steam/oxygen, and oxygen. Synthesis gas composition, carbon gasification degree, specific power consumptions, and power efficiency for these processes were determined. The influence of the selected oxidant composition on the gasification-process main characteristics have been investigated.

  18. Current Gasification Research | Department of Energy

    Broader source: Energy.gov (indexed) [DOE]

    gasification R&D projects. Sponsored by the U.S. Department of Energy, the...

  19. Effective Renewable Energy Policy: Leave It to the States?

    E-Print Network [OSTI]

    Weissman, Steven

    2011-01-01

    gas, fuel produced by coal gasification or liquefaction,solid waste, or coal integrated gasification combined cycle.gasification combined cycle technologies, waste coal, and

  20. Combined Cycle Combustion Turbines

    E-Print Network [OSTI]

    and baseload · Can provide support for renewable power and serve as coal replacement · Becoming more flexible, Oregon and Washington ­ along with a few selected NERC regions: NPCC ­ the Northeastern US and Canada WECC - the West (the Northwest is included) TRE - most of Texas MRO ­ the upper Midwest US and Canada

  1. Hydrogen Production Cost Estimate Using Biomass Gasification

    E-Print Network [OSTI]

    Hydrogen Production Cost Estimate Using Biomass Gasification National Renewable Energy Laboratory Panel, Hydrogen Production Cost Estimate Using Biomass Gasification To: Mr. Mark Ruth, NREL, DOE dollars. Costs for a pioneer plant [a 1st plant with a capacity of 500 dry ton per day (dtpd) biomass

  2. Improved catalysts for carbon and coal gasification

    DOE Patents [OSTI]

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

    1984-05-25

    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.

  3. Molten salt coal gasification process development unit. Phase 1. Volume 2. Commercial plant study. Final report

    SciTech Connect (OSTI)

    Kohl, Arthur L.

    1980-05-01

    This report summarizes the results of a test program conducted on the Molten Salt Coal Gasification Process, which included the design, construction, and operation of a Process Development Unit (PDU). This process, coal is gasified by contacting it with air in a turbulent pool of molten sodium carbonate. Sulfur and ash are retained in the melt, and a small stream is continuously removed from the gasifier for regeneration of the salt. The process can handle a wide variety of feed materials, including highly caking coals, and produces a gas relatively free from tars and other impurities. The gasification step is carried out at approximately 1800/sup 0/F. The PDU was designed to process 1 ton per hour of coal at pressures up to 20 atm. It is a completely integrated facility including systems for feeding solids to the gasifier, regenerating sodium carbonate for reuse, and removing sulfur and ash in forms suitable for disposal. Five extended test runs were made. The observed product gas composition was quite close to that predicted on the basis of earlier small-scale tests and thermodynamic considerations. All plant systems were operated in an integrated manner. Test data and discussions regarding plant equipment and process performance are presented. The program also included a commercial plant study which showed the process to be attractive for use in a combined cycle, electric power plant. The report is presented in two volumes, Volume 1, PDU Operations, and Volume 2, Commercial Plant Study.

  4. ENCOAL Mild Coal Gasification Project

    SciTech Connect (OSTI)

    Not Available

    1992-02-01

    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.

  5. The Development of a Hydrothermal Method for Slurry Feedstock Preparation for Gasification Technology

    E-Print Network [OSTI]

    He, Wei

    2011-01-01

    Affairs, Carbon and coal gasification: science andand B.F. Towler, Coal Gasification and Its Applications .Coal Chars , in Coal Gasification . 1974, AMERICAN CHEMICAL

  6. The Development of a Hydrothermal Method for Slurry Feedstock Preparation for Gasification Technology

    E-Print Network [OSTI]

    He, Wei

    2011-01-01

    and J. Ahrenfeldt, Handbook biomass gasification . 2005: BTGAllen, S.G. , et al. , Biomass Gasification in SupercriticalHydrogen production by biomass gasification in supercritical

  7. The Development of a Hydrothermal Method for Slurry Feedstock Preparation for Gasification Technology

    E-Print Network [OSTI]

    He, Wei

    2011-01-01

    Higman, C. and M. Burgt, Gasification . 2003: Elsevier/Gulfand N.P. Cheremisinoff, Gasification technologies: a primerbiomass (part 3): gasification technologies. Bioresource

  8. A Generalized Pyrolysis Model for Simulating Charring, Intumescent, Smoldering, and Noncharring Gasification

    E-Print Network [OSTI]

    Lautenberger, Chris; Fernandez-Pello, Carlos

    2006-01-01

    on Nonflaming Transient Gasification of PMMA and PE duringT. , & Werner, K. , “Wood Gasification at Fire Level HeatConcentration on Nonflaming Gasification Rates and Evolved

  9. The Development of a Hydrothermal Method for Slurry Feedstock Preparation for Gasification Technology

    E-Print Network [OSTI]

    He, Wei

    2011-01-01

    that may arise with gasification biomass feedstocks. 1.2and J. Ahrenfeldt, Handbook biomass gasification . 2005: BTGM. Sciazko, Co-gasification of biomass and coal for methanol

  10. Apparatus for solar coal gasification

    DOE Patents [OSTI]

    Gregg, D.W.

    1980-08-04

    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.

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

    SciTech Connect (OSTI)

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

    2012-12-31

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

  12. Fluidized bed catalytic coal gasification process

    DOE Patents [OSTI]

    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)

    1984-01-01

    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.

  13. Catalysts for carbon and coal gasification

    DOE Patents [OSTI]

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

    1985-01-01

    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.

  14. Underground Coal Gasification at Tennessee Colony 

    E-Print Network [OSTI]

    Garrard, C. W.

    1979-01-01

    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...

  15. Development of an Integrated Multi-Contaminant Removal Process Applied to Warm Syngas Cleanup for Coal-Based Advanced Gasification Systems

    SciTech Connect (OSTI)

    Howard Meyer

    2010-11-30

    This project met the objective to further the development of an integrated multi-contaminant removal process in which H2S, NH3, HCl and heavy metals including Hg, As, Se and Cd present in the coal-derived syngas can be removed to specified levels in a single/integrated process step. The process supports the mission and goals of the Department of Energyâ??s Gasification Technologies Program, namely to enhance the performance of gasification systems, thus enabling U.S. industry to improve the competitiveness of gasification-based processes. The gasification program will reduce equipment costs, improve process environmental performance, and increase process reliability and flexibility. Two sulfur conversion concepts were tested in the laboratory under this project, i.e., the solventbased, high-pressure University of California Sulfur Recovery Process â?? High Pressure (UCSRP-HP) and the catalytic-based, direct oxidation (DO) section of the CrystaSulf-DO process. Each process required a polishing unit to meet the ultra-clean sulfur content goals of <50 ppbv (parts per billion by volume) as may be necessary for fuel cells or chemical production applications. UCSRP-HP was also tested for the removal of trace, non-sulfur contaminants, including ammonia, hydrogen chloride, and heavy metals. A bench-scale unit was commissioned and limited testing was performed with simulated syngas. Aspen-Plus®-based computer simulation models were prepared and the economics of the UCSRP-HP and CrystaSulf-DO processes were evaluated for a nominal 500 MWe, coal-based, IGCC power plant with carbon capture. This report covers the progress on the UCSRP-HP technology development and the CrystaSulf-DO technology.

  16. Investigation of plasma-aided bituminous coal gasification

    SciTech Connect (OSTI)

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

    2009-04-15

    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.

  17. Utilization of char from biomass gasification in catalytic applications

    E-Print Network [OSTI]

    Columbia University

    Utilization of char from biomass gasification in catalytic applications Naomi Klinghoffer Submitted Utilization of char from biomass gasification in catalytic applications Naomi Klinghoffer Utilization takes place during catalytic decomposition. This thesis focuses on the utilization of char as a catalyst

  18. Modeling, Optimization and Economic Evaluation of Residual Biomass Gasification 

    E-Print Network [OSTI]

    Georgeson, Adam

    2012-02-14

    and product options are available for gasification along with combinations thereof. The objective of this work is to create a systematic method for optimizing the design of a residual biomass gasification unit. In detail, this work involves development...

  19. Thermochemical Conversion Research and Development: Gasification and Pyrolysis (Fact Sheet)

    SciTech Connect (OSTI)

    Not Available

    2009-09-01

    Biomass gasification and pyrolysis research and development activities at the National Renewable Energy Laboratory and Pacific Northwest National Laboratory.

  20. Apparatus for fixed bed coal gasification

    DOE Patents [OSTI]

    Sadowski, Richard S. (Greenville, SC)

    1992-01-01

    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.

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

    E-Print Network [OSTI]

    Short Communication Catalytic coal gasification: use of calcium versus potassium* Ljubisa R on the gasification in air and 3.1 kPa steam of North Dakota lignitic chars prepared under slow and rapid pyrolysis of calcium is related to its sintering via crystallite growth. (Keywords: coal; gasification; catalysis

  2. Energy efficiency improvement and cost saving opportunities for petroleum refineries

    E-Print Network [OSTI]

    Worrell, Ernst; Galitsky, Christina

    2005-01-01

    in an entrained bed gasifier. Due to the limited oxygenof power in an Integrated Gasifier Combined Cycle (IGCC). In

  3. Process for fixed bed coal gasification

    DOE Patents [OSTI]

    Sadowski, Richard S. (Greenville, SC)

    1992-01-01

    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.

  4. Biomass Gasification Technology Assessment: Consolidated Report

    SciTech Connect (OSTI)

    Worley, M.; Yale, J.

    2012-11-01

    Harris Group Inc. (HGI) was commissioned by the National Renewable Energy Laboratory to assess gasification and tar reforming technologies. Specifically, the assessments focused on gasification and tar reforming technologies that are capable of producing a syngas suitable for further treatment and conversion to liquid fuels. HGI gathered sufficient information to analyze three gasification and tar reforming systems. This report summarizes the equipment, general arrangement of the equipment, operating characteristics, and operating severity for each technology. The order of magnitude capital cost estimates are supported by a basis-of-estimate write-up, which is also included in this report. The report also includes Microsoft Excel workbook models, which can be used to design and price the systems. The models can be used to analyze various operating capacities and pressures. Each model produces a material balance, equipment list, capital cost estimate, equipment drawings and preliminary general arrangement drawings. Example outputs of each model are included in the Appendices.

  5. Production of Hydrogen from Underground Coal Gasification

    DOE Patents [OSTI]

    Upadhye, Ravindra S. (Pleasanton, CA)

    2008-10-07

    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.

  6. A big leap forward for biomass gasification

    SciTech Connect (OSTI)

    Moon, S.

    1995-12-31

    This article describes the McNeil Generating Station in Vermont, the first industrial scale-up of Battelle Columbus Laboratory`s biomass gasification process. The plant is part of a major US DOE initiative to demonstrate gasification of renewable biomass for electricity production. The project will integrate the Battelle high-through-put gasifier with a high-effiency gas turbine. The history of the project is described, along with an overview of the technology and the interest and resources available in Vermont that will help insure a successful project.

  7. Molten salt coal gasification process development unit. Phase 1. Volume 1. PDU operations. Final report

    SciTech Connect (OSTI)

    Kohl, A.L.

    1980-05-01

    This report summarizes the results of a test program conducted on the Molten Salt Coal Gasification Process, which included the design, construction, and operation of a Process Development Unit. In this process, coal is gasified by contacting it with air in a turbulent pool of molten sodium carbonate. Sulfur and ash are retained in the melt, and a small stream is continuously removed from the gasifier for regeneration of sodium carbonate, removal of sulfur, and disposal of the ash. The process can handle a wide variety of feed materials, including highly caking coals, and produces a gas relatively free from tars and other impurities. The gasification step is carried out at approximately 1800/sup 0/F. The PDU was designed to process 1 ton per hour of coal at pressures up to 20 atm. It is a completely integrated facility including systems for feeding solids to the gasifier, regenerating sodium carbonate for reuse, and removing sulfur and ash in forms suitable for disposal. Five extended test runs were made. The observed product gas composition was quite close to that predicted on the basis of earlier small-scale tests and thermodynamic considerations. All plant systems were operated in an integrated manner during one of the runs. The principal problem encountered during the five test runs was maintaining a continuous flow of melt from the gasifier to the quench tank. Test data and discussions regarding plant equipment and process performance are presented. The program also included a commercial plant study which showed the process to be attractive for use in a combined-cycle, electric power plant. The report is presented in two volumes, Volume 1, PDU Operations, and Volume 2, Commercial Plant Study.

  8. Low Thermal Conductivity, High Durability Thermal Barrier Coatings for IGCC Environments

    SciTech Connect (OSTI)

    Jordan, Eric; Gell, Maurice

    2015-01-15

    Advanced thermal barrier coatings (TBC) are crucial to improved energy efficiency in next generation gas turbine engines. The use of traditional topcoat materials, e.g. yttria-stabilized zirconia (YSZ), is limited at elevated temperatures due to (1) the accelerated undesirable phase transformations and (2) corrosive attacks by calcium-magnesium-aluminum-silicate (CMAS) deposits and moisture. The first goal of this project is to use the Solution Precursor Plasma Spray (SPPS) process to further reduce the thermal conductivity of YSZ TBCs by introducing a unique microstructural feature of layered porosity, called inter-pass boundaries (IPBs). Extensive process optimization accompanied with hundreds of spray trials as well as associated SEM cross-section and laser-flash measurements, yielded a thermal conductivity as low as 0.62 Wm?¹K?¹ in SPPS YSZ TBCs, approximately 50% reduction of APS TBCs; while other engine critical properties, such as cyclic durability, erosion resistance and sintering resistance, were characterized to be equivalent or better than APS baselines. In addition, modifications were introduced to SPPS TBCs so as to enhance their resistance to CMAS under harsh IGCC environments. Several mitigation approaches were explored, including doping the coatings with Al?O? and TiO?, applying a CMAS infiltration-inhibiting surface layer, and filling topcoat cracks with blocking substances. The efficacy of all these modifications was assessed with a set of novel CMAS-TBC interaction tests, and the moisture resistance was tested in a custom-built high-temperature moisture rig. In the end, the optimal low thermal conductivity TBC system was selected based on all evaluation tests and its processing conditions were documented. The optimal coating consisted on a thick inner layer of YSZ coating made by the SPPS process having a thermal conductivity 50% lower than standard YSZ coatings topped with a high temperature tolerant CMAS resistant gadolinium zirconate Coating made by the SPPS process. Noteworthy was the fact that the YSZ to GZO interface made by the SPPS process was not the failure location as had been observed in APS coatings.

  9. The heat recovery steam generator (HRSG) is a key component of Combined Cycle Power Plants (CCPP). The exhaust (flue gas) from the CCPP gas turbine flows through the HRSG -this gas typically contains a high

    E-Print Network [OSTI]

    The heat recovery steam generator (HRSG) is a key component of Combined Cycle Power Plants (CCPP). The exhaust (flue gas) from the CCPP gas turbine flows through the HRSG - this gas typically contains a high

  10. World Gasification Database Now Available from DOE

    Broader source: Energy.gov [DOE]

    A database just released by the U.S. Department of Energy documents the worldwide growth of gasification, the expected technology of choice for future coal-based plants that produce power, fuels, and/or chemicals with near-zero emissions.

  11. Wabash River Coal Gasification Repowering Project

    SciTech Connect (OSTI)

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

    1992-01-01

    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.

  12. Wabash River Coal Gasification Repowering Project

    SciTech Connect (OSTI)

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

    1992-11-01

    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.

  13. Biomass Gasification at The Evergreen State College

    E-Print Network [OSTI]

    Biomass Gasification at The Evergreen State College Written by Students of the Winter 2011 Program "Applied Research: Biomass, Energy, and Environmental Justice" At The Evergreen State College, Olympia://blogs.evergreen.edu/appliedresearch/ #12; i Table of Contents Chapter 1: Introduction to Biomass at the Evergreen State College by Dani

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

    SciTech Connect (OSTI)

    Agarwal, P.; Frey, H. [North Carolina State Univ., Raleigh, NC (United States); Rubin, E.S. [Carnegie Mellon Univ., Pittsburgh, PA (United States)

    1995-07-01

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

  15. The direct observation of alkali vapor species in biomass combustion and gasification

    SciTech Connect (OSTI)

    French, R.J.; Dayton, D.C.; Milne, T.A.

    1994-01-01

    This report summarizes new data from screening various feedstocks for alkali vapor release under combustion conditions. The successful development of a laboratory flow reactor and molecular beam, mass spectrometer interface is detailed. Its application to several herbaceous and woody feedstocks, as well as a fast-pyrolysis oil, under 800 and 1,100{degrees}C batch combustion, is documented. Chlorine seems to play a large role in the facile mobilization of potassium. Included in the report is a discussion of relevant literature on the alkali problem in combustors and turbines. Highlighted are the phenomena identified in studies on coal and methods that have been applied to alkali speciation. The nature of binding of alkali in coal versus biomass is discussed, together with the implications for the ease of release. Herbaceous species and many agricultural residues appear to pose significant problems in release of alkali species to the vapor at typical combustor temperatures. These problems could be especially acute in direct combustion fired turbines, but may be ameliorated in integrated gasification combined cycles.

  16. Coal properties and system operating parameters for underground coal gasification

    SciTech Connect (OSTI)

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

    2008-07-01

    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.

  17. Advanced Coal Wind Hybrid: Economic Analysis

    E-Print Network [OSTI]

    Phadke, Amol

    2008-01-01

    power plant pulverized coal power plant v Advanced Coal WindMW coal gasification combined cycle power plant equippedMW coal gasification, combined cycle power plant equipped

  18. FEED SYSTEM INNOVATION FOR GASIFICATION OF LOCALLY ECONOMICAL ALTERNATIVE FUELS (FIGLEAF)

    SciTech Connect (OSTI)

    Michael L. Swanson; Mark A. Musich; Darren D. Schmidt

    2001-11-01

    The Feed System Innovation for Gasification of Locally Economical Alternative Fuels (FIGLEAF) project is being conducted by the Energy and Environmental Research Center and Gasification Engineering Corporation of Houston, Texas (a subsidiary of Global Energy Inc., Cincinnati, Ohio), with 80% cofunding from the U.S. Department of Energy. The goal of the project is to identify and evaluate low-value fuels that could serve as alternative feedstocks and to develop a feed system to facilitate their use in integrated gasification combined cycle and gasification coproduction facilities. The long-term goal, to be accomplished in a subsequent project, is to install a feed system for the selected fuels at Global Energy's commercial-scale 262-MW Wabash River Coal Gasification Facility in West Terre Haute, Indiana. The feasibility study undertaken for the project consists of identifying and evaluating the economic feasibility of potential fuel sources, developing a feed system design capable of providing a fuel at 400 psig to the second stage of the E-Gas (Destec) gasifier to be cogasified with coal at up to 30% on a Btu basis, performing bench- and pilot-scale testing to verify concepts and clarify decision-based options, reviewing prior art with respect to high-pressure feed system designs, and determining the economics of cofeeding alternative feedstocks with the conceptual feed system design. Activities and results thus far include the following. Several potential alternative fuels have been obtained for evaluation and testing as potential feedstocks, including sewage sludge, used railroad ties, urban wood waste, municipal solid waste, and used waste tires/tire-derived fuel. Only fuels with potential tipping fees were considered; potential energy crop fuels were not considered since they would have a net positive cost to the plant. Based on the feedstock assessment, sewage sludge has been selected as one of the primary feedstocks for consideration at the Wabash plant. Because of the limited waste heat available for drying and the ability of the gasifier to operate with alternative feedstocks at up to 80% moisture, a decision was made to investigate a pumping system for delivering the as-received fuel across the pressure boundary. High-temperature drop-tube furnace tests were conducted to determine if explosive fragmentation of high-moisture sludge droplets could be expected, but showed that these droplets underwent a shrinking and densification process that implies that the sludge will have to be well dispersed when injected into the gasifier. Fuel dispersion nozzles have been obtained for measuring how well the sludge can be dispersed in the second stage of the gasifier. Future work will include leasing a Schwing America pump to test pumping sewage sludge against 400 psig. In addition, sludge dispersion testing will be completed using two different dispersion nozzles to determine their ability to generate sludge particles small enough to be entrained out of the E-Gas entrained-flow gasifier.

  19. Weighing the Costs and Benefits of Renewables Portfolio Standards: A Comparative Analysis of State-Level Policy Impact Projections

    E-Print Network [OSTI]

    Chen, Cliff; Wiser, Ryan; Bolinger, Mark

    2007-01-01

    integrated gasification combined cycle plants, and measuresrate of a new combined-cycle natural gas generator.displaces natural gas combined- cycle generation, and RPS

  20. Life Cycle Regulation of Transportation Fuels: Uncertainty and its Policy Implications

    E-Print Network [OSTI]

    Plevin, Richard Jay

    2010-01-01

    ethanol; NGCC = natural gas combined-cycle; BIGCC =gasification combined-cycle. P ART III U NCERTAINTY Aaverage, (ii) natural gas combined-cycle (NGCC), (iii) coal

  1. Method for increasing steam decomposition in a coal gasification process

    DOE Patents [OSTI]

    Wilson, Marvin W. (Fairview, WV)

    1988-01-01

    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.

  2. Method for increasing steam decomposition in a coal gasification process

    DOE Patents [OSTI]

    Wilson, M.W.

    1987-03-23

    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.

  3. Solid-Fueled Pressurized Chemical Looping with Flue-Gas Turbine Combined Cycle for Improved Plant Efficiency and CO{sub 2} Capture

    SciTech Connect (OSTI)

    Liu, Kunlei; Chen, Liangyong; Zhang, Yi; Richburg, Lisa; Simpson, James; White, Jay; Rossi, Gianalfredo

    2013-12-31

    The purpose of this document is to report the final result of techno-economic analysis for the proposed 550MWe integrated pressurized chemical looping combustion combined cycle process. An Aspen Plus based model is delivered in this report along with the results from three sensitivity scenarios including the operating pressure, excess air ratio and oxygen carrier performance. A process flow diagram and detailed stream table for the base case are also provided with the overall plant energy balance, carbon balance, sulfur balance and water balance. The approach to the process and key component simulation are explained. The economic analysis (OPEX and CAPX) on four study cases via DOE NETL Reference Case 12 are presented and explained.

  4. Apparatus and methods of reheating gas turbine cooling steam and high pressure steam turbine exhaust in a combined cycle power generating system

    DOE Patents [OSTI]

    Tomlinson, Leroy Omar (Niskayuna, NY); Smith, Raub Warfield (Ballston Lake, NY)

    2002-01-01

    In a combined cycle system having a multi-pressure heat recovery steam generator, a gas turbine and steam turbine, steam for cooling gas turbine components is supplied from the intermediate pressure section of the heat recovery steam generator supplemented by a portion of the steam exhausting from the HP section of the steam turbine, steam from the gas turbine cooling cycle and the exhaust from the HP section of the steam turbine are combined for flow through a reheat section of the HRSG. The reheated steam is supplied to the IP section inlet of the steam turbine. Thus, where gas turbine cooling steam temperature is lower than optimum, a net improvement in performance is achieved by flowing the cooling steam exhausting from the gas turbine and the exhaust steam from the high pressure section of the steam turbine in series through the reheater of the HRSG for applying steam at optimum temperature to the IP section of the steam turbine.

  5. Fluidized bed gasification of extracted coal

    DOE Patents [OSTI]

    Aquino, Dolores C. (Houston, TX); DaPrato, Philip L. (Westfield, NJ); Gouker, Toby R. (Baton Rouge, LA); Knoer, Peter (Houston, TX)

    1986-01-01

    Coal or similar carbonaceous solids are extracted by contacting the solids in an extraction zone (12) with an aqueous solution having a pH above 12.0 at a temperature between 65.degree. C. and 110.degree. C. for a period of time sufficient to remove bitumens from the coal into said aqueous solution and the extracted solids are then gasified at an elevated pressure and temperature in a fluidized bed gasification zone (60) wherein the density of the fluidized bed is maintained at a value above 160 kg/m.sup.3. In a preferred embodiment of the invention, water is removed from the aqueous solution in order to redeposit the extracted bitumens onto the solids prior to the gasification step.

  6. Fluidized bed gasification of extracted coal

    DOE Patents [OSTI]

    Aquino, D.C.; DaPrato, P.L.; Gouker, T.R.; Knoer, P.

    1984-07-06

    Coal or similar carbonaceous solids are extracted by contacting the solids in an extraction zone with an aqueous solution having a pH above 12.0 at a temperature between 65/sup 0/C and 110/sup 0/C for a period of time sufficient to remove bitumens from the coal into said aqueous solution, and the extracted solids are then gasified at an elevated pressure and temperature in a fluidized bed gasification zone (60) wherein the density of the fluidized bed is maintained at a value above 160 kg/m/sup 3/. In a preferred embodiment of the invention, water is removed from the aqueous solution in order to redeposit the extracted bitumens onto the solids prior to the gasification step. 2 figs., 1 tab.

  7. Gas turbine power generation from biomass gasification

    SciTech Connect (OSTI)

    Paisley, M.A.; Litt, R.D.; Overend, R.P.; Bain, R.L.

    1994-12-31

    The Biomass Power Program of the US Department of Energy (DOE) has as a major goal the development of cost-competitive technologies for the production of power from renewable biomass crops. The gasification of biomass provides the potential to meet this goal by efficiently and economically producing a renewable source of a clean gaseous fuel suitable for use in high efficiency gas turbines or as a substitute fuel in other combustion devices such as boilers, kilns, or other natural gas fired equipment. This paper discusses the development of the use of the Battelle high-throughput gasification process for power generation systems. Projected process economics are presented along with a description of current experimental operations coupling a gas turbine power generation system to the research scale gasifier.

  8. Apparatus and method for solar coal gasification

    DOE Patents [OSTI]

    Gregg, David W. (Moraga, CA)

    1980-01-01

    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.

  9. EIS-0383: Southern Company's Orlando Gasification Project, Orlando, FL

    Broader source: Energy.gov [DOE]

    This EIS analyzes DOE's decision to provide cost-shared funding for construction, design, and operation of a new gasification plant in Orlando, Florida.

  10. Gasification performance of switchgrass pretreated with torrefaction and densification

    SciTech Connect (OSTI)

    Jaya Shankar Tumuluru; Various

    2014-08-01

    The purpose of this study was to investigate gasification performance of four switchgrass pretreatments (torrefaction at 230 and 270 °C, densification, and combined torrefaction and densification) and three gasification temperatures (700, 800 and 900 °C). Gasification was performed in a fixed-bed externally heated reactor with air as an oxidizing agent. Switchgrass pretreatment and gasification temperature had significant effects on gasification performance such as gas yields, syngas lower heating value (LHV), and carbon conversion and cold gas efficiencies. With an increase in the gasification temperature, yields of H2 and CO, syngas LHV, and gasifier efficiencies increased whereas CH4, CO2 and N2 yields decreased. Among all switchgrass pretreatments, gasification performance of switchgrass with combined torrefaction and densification was the best followed by that of densified, raw and torrefied switchgrass. Gasification of combined torrefied and densified switchgrass resulted in the highest yields of H2 (0.03 kg/kg biomass) and CO (0.72 kg/kg biomass), highest syngas LHV (5.08 MJ m-3), CCE (92.53%), and CGE (68.40%) at the gasification temperature of 900 °C.

  11. Potential trace element emissions from the gasification of Illinois...

    Office of Scientific and Technical Information (OSTI)

    the gasification of Illinois coals. Duplicate determinations of 34 elements in coal and ash samples Citation Details In-Document Search Title: Potential trace element emissions...

  12. Models of National Energy Systems -focusing on biomass energy

    E-Print Network [OSTI]

    1000000 pacityin[M p g Dam Storage Run of river Fuel Cell Internal Combustion Combined Cycle Gas Turbine Internal Combustion Combined Cycle CO2 Seq. Combined Cycle 200000 400000 I y Gas Turbine Steam Turbine Internal Combustion Combined Cycle Gas Turbine Steam Turbine IGCC CO2 Seq. IGCC 0 2000 BAU 2000 CO2 2010

  13. Fluidized bed injection assembly for coal gasification

    DOE Patents [OSTI]

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

    1981-01-01

    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.

  14. GASIFICATION BASED BIOMASS CO-FIRING

    SciTech Connect (OSTI)

    Babul Patel; Kevin McQuigg; Robert Toerne; John Bick

    2003-01-01

    Biomass gasification offers a practical way to use this widespread fuel source for co-firing traditional large utility boilers. The gasification process converts biomass into a low Btu producer gas that can be used as a supplemental fuel in an existing utility boiler. This strategy of co-firing is compatible with a variety of conventional boilers including natural gas and oil fired boilers, pulverized coal fired conventional and cyclone boilers. Gasification has the potential to address all problems associated with the other types of co-firing with minimum modifications to the existing boiler systems. Gasification can also utilize biomass sources that have been previously unsuitable due to size or processing requirements, facilitating a wider selection of biomass as fuel and providing opportunity in reduction of carbon dioxide emissions to the atmosphere through the commercialization of this technology. This study evaluated two plants: Wester Kentucky Energy Corporation's (WKE's) Reid Plant and TXU Energy's Monticello Plant for technical and economical feasibility. These plants were selected for their proximity to large supply of poultry litter in the area. The Reid plant is located in Henderson County in southwest Kentucky, with a large poultry processing facility nearby. Within a fifty-mile radius of the Reid plant, there are large-scale poultry farms that generate over 75,000 tons/year of poultry litter. The local poultry farmers are actively seeking environmentally more benign alternatives to the current use of the litter as landfill or as a farm spread as fertilizer. The Monticello plant is located in Titus County, TX near the town of Pittsburgh, TX, where again a large poultry processor and poultry farmers in the area generate over 110,000 tons/year of poultry litter. Disposal of this litter in the area is also a concern. This project offers a model opportunity to demonstrate the feasibility of biomass co-firing and at the same time eliminate poultry litter disposal problems for the area's poultry farmers.

  15. Hydrogen Production: Coal Gasification | Department of Energy

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

    AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative Fuels Data Center Home Page on Google Bookmark EERE: Alternative Fuels Data Center Home Page on Delicious Rank EERE:Financing Tool Fits the Bill FinancingDepartment ofPowerScenarioCoal Gasification Hydrogen

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

    E-Print Network [OSTI]

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

    2007-01-01

    economics of the combined cycle gas turbine—an experiencePC) and natural gas combined cycle (NGCC) plants with post-integrated gasi?cation combined cycle (IGCC) plants with

  17. Coal gasification. Quarterly report, July-September 1979

    SciTech Connect (OSTI)

    None

    1980-07-01

    The status of 18 coal gasification pilot plants or supporting projects supported by US DOE is reviewed under the following headings: company involved, location, contract number, funding, gasification process, history, process description, flowsheet and progress in the July-September 1979 quarter. (LTN)

  18. Methods for sequestering carbon dioxide into alcohols via gasification fermentation

    SciTech Connect (OSTI)

    Gaddy, James L; Ko, Ching-Whan; Phillips, J. Randy; Slape, M. Sean

    2013-11-26

    The present invention is directed to improvements in gasification for use with synthesis gas fermentation. Further, the present invention is directed to improvements in gasification for the production of alcohols from a gaseous substrate containing at least one reducing gas containing at least one microorganism.

  19. BIomass GasIfIcaTIon Summary of technology

    E-Print Network [OSTI]

    Mucina, Ladislav

    or coal, into a clean gaseous fuel that can be burned in a gas engine to generate electricity-rankfuels,such as mallee and brown coal, into a clean gaseous fuel with very low tar concentration. This has the capacityBIomass GasIfIcaTIon Summary of technology Gasification converts a solid fuel, such as biomass

  20. Gasification of refuse derived fuel in the Battelle high throughput gasification system

    SciTech Connect (OSTI)

    Paisley, M.A.; Creamer, K.S.; Tweksbury, T.L.; Taylor, D.R. )

    1989-07-01

    This report presents the results of an experimental program to demonstrate the suitability of the Battelle High Throughput Gasification Process to non-wood biomass fuels. An extensive data base on wood gasification was generated during a multi-year experimental program. This data base and subsequent design and economic analysis activities led to the discussion to study the gasification character of other fuels. The specific fuel studied was refuse derived fuel (RDF) which is a prepared municipal solid waste (MSW). The use of RDF, while providing a valuable fuel, can also provide a solution to MSW disposal problems. Gasification of MSW provides advantages over land fill or mass burn technology since a more usable form of energy, medium Btu gas, is produced. Land filling of wastes produces no usable products and mass burning while greatly reducing the volume of wastes for disposal can produce only steam. This steam must be used on site or very nearby this limiting the potential locations for mass burn facilities. Such a gas, if produced from currently available supplies of MSW, can contribute 2 quads to the US energy supply. 3 refs., 12 figs., 7 tabs.

  1. Hybrid Combustion-Gasification Chemical Looping

    SciTech Connect (OSTI)

    Herbert Andrus; Gregory Burns; John Chiu; Gregory Lijedahl; Peter Stromberg; Paul Thibeault

    2009-01-07

    For the past several years Alstom Power Inc. (Alstom), a leading world-wide power system manufacturer and supplier, has been in the initial stages of developing an entirely new, ultra-clean, low cost, high efficiency power plant for the global power market. This new power plant concept is based on a hybrid combustion-gasification process utilizing high temperature chemical and thermal looping technology The process consists of the oxidation, reduction, carbonation, and calcination of calcium-based compounds, which chemically react with coal, biomass, or opportunity fuels in two chemical loops and one thermal loop. The chemical and thermal looping technology can be alternatively configured as (i) a combustion-based steam power plant with CO{sub 2} capture, (ii) a hybrid combustion-gasification process producing a syngas for gas turbines or fuel cells, or (iii) an integrated hybrid combustion-gasification process producing hydrogen for gas turbines, fuel cells or other hydrogen based applications while also producing a separate stream of CO{sub 2} for use or sequestration. In its most advanced configuration, this new concept offers the promise to become the technology link from today's Rankine cycle steam power plants to tomorrow's advanced energy plants. The objective of this work is to develop and verify the high temperature chemical and thermal looping process concept at a small-scale pilot facility in order to enable AL to design, construct and demonstrate a pre-commercial, prototype version of this advanced system. In support of this objective, Alstom and DOE started a multi-year program, under this contract. Before the contract started, in a preliminary phase (Phase 0) Alstom funded and built the required small-scale pilot facility (Process Development Unit, PDU) at its Power Plant Laboratories in Windsor, Connecticut. Construction was completed in calendar year 2003. The objective for Phase I was to develop the indirect combustion loop with CO{sub 2} separation, and also syngas production from coal with the calcium sulfide (CaS)/calcium sulfate (CaSO{sub 4}) loop utilizing the PDU facility. The results of Phase I were reported in Reference 1, 'Hybrid Combustion-Gasification Chemical Looping Coal Power Development Technology Development Phase I Report' The objective for Phase II was to develop the carbonate loop--lime (CaO)/calcium carbonate (CaCO{sub 3}) loop, integrate it with the gasification loop from Phase I, and ultimately demonstrate the feasibility of hydrogen production from the combined loops. The results of this program were reported in Reference 3, 'Hybrid Combustion-Gasification Chemical Looping Coal Power Development Technology Development Phase II Report'. The objective of Phase III is to operate the pilot plant to obtain enough engineering information to design a prototype of the commercial Chemical Looping concept. The activities include modifications to the Phase II Chemical Looping PDU, solids transportation studies, control and instrumentation studies and additional cold flow modeling. The deliverable is a report making recommendations for preliminary design guidelines for the prototype plant, results from the pilot plant testing and an update of the commercial plant economic estimates.

  2. MODELLING THE LOW-TAR BIG GASIFICATION CONCEPT Lars Andersen, Brian Elmegaard, Bjrn Qvale, Ulrik Henriksen

    E-Print Network [OSTI]

    -tar, high-efficient biomass gasification concept for medium- to large-scale power plants has been designed that will lead to a breakthrough of gasification technology. Keywords: Biomass, Gasification, Tar, Steam drying Value DNA Dynamic Network Analysis INTRODUCTION In order to introduce biomass gasification technol- ogy

  3. High Pressure Superheater 1 (HPSH1) is the first heat exchange tube bank inside the Heat Recovery Steam Generator (HRSG) to encounter exhaust flue gas from the gas turbine of a Combined Cycle Power Plant. Steam

    E-Print Network [OSTI]

    Steam Generator (HRSG) to encounter exhaust flue gas from the gas turbine of a Combined Cycle Power Plant. Steam flowing through the HPSH1 gains heat from the flue gas prior to entering the steam turbine changes that occurred, especially in the steam temperature at the HPSH1 entry, and the different rates

  4. Diffusion Coatings for Corrosion-Resistant Components in Coal Gasification Systems

    SciTech Connect (OSTI)

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

    2006-06-30

    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.

  5. REGULATION AND SYSTEM INTERDEPENDENCE: EFFECTS ON THE SITING OF CALIFORNIA ELECTRICAL ENERGY FACILITIES

    E-Print Network [OSTI]

    Kooser, J.C.

    2013-01-01

    Strategies for Siting Coal Gasification Facilities in theStrategies for Siting Coal Gasification Facilities in thea 100 MW integrated coal gasification/ combined cycle

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

    E-Print Network [OSTI]

    2007-01-01

    renewables Integrated coal gasification combined cycle withmethane reforming or coal gasification are well established,central plant) Coal Coal gasification with Carbon Capture

  7. Development and Application of Advanced Models for Steam Hydrogasification: Process Design and Economic Evaluation

    E-Print Network [OSTI]

    Lu, Xiaoming

    2012-01-01

    S. A Survey of Biomass Gasification, 2 nd Ed. The National2011. 54. Reed TE. Biomass gasification: Principles andLife Cycle Assessment of Biomass Gasification Combined Cycle

  8. Probabilistic Modeling and Evaluation of the Performance, Emissions, and Cost of Texaco Gasifier-

    E-Print Network [OSTI]

    Frey, H. Christopher

    - Based Integrated Gasification Combined Cycle Systems Using ASPEN Prepared by: H. Christopher Frey Naveen................................................................................................. 1 1.1 Overview of Gasification Systems.............................................................. 2 1.1.1 Gasification

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

    E-Print Network [OSTI]

    2007-01-01

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

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

    E-Print Network [OSTI]

    Farrell, Alexander E.; Sperling, Dan

    2007-01-01

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

  11. Development and Application of Advanced Models for Steam Hydrogasification: Process Design and Economic Evaluation

    E-Print Network [OSTI]

    Lu, Xiaoming

    2012-01-01

    Life Cycle Assessment of Biomass Gasification Combined Cycle2011. 54. Reed TE. Biomass gasification: Principles andS. A Survey of Biomass Gasification, 2 nd Ed. The National

  12. Results of heat tests of the TGE-435 main boiler in the PGU-190/220 combined-cycle plant of the Tyumen' TETs-2 cogeneration plant

    SciTech Connect (OSTI)

    A.V. Kurochkin; A.L. Kovalenko; V.G. Kozlov; A.I. Krivobok

    2007-01-15

    Special features of operation of a boiler operating as a combined-cycle plant and having its own furnace and burner unit are descried. The flow of flue gases on the boiler is increased due to feeding of exhaust gases of the GTU into the furnace, which intensifies the convective heat exchange. In addition, it is not necessary to preheat air in the convective heating surfaces (the boiler has no air preheater). The convective heating surfaces of the boiler are used for heating the feed water, thus replacing the regeneration extractions of the steam turbine (HPP are absent in the circuit) and partially replacing the preheating of condensate (the LPP in the circuit of the unit are combined with preheaters of delivery water). Regeneration of the steam turbine is primarily used for the district cogeneration heating purposes. The furnace and burner unit of the exhaust-heat boiler (which is a new engineering solution for the given project) ensures utilization of not only the heat of the exhaust gases of the GTU but also of their excess volume, because the latter contains up to 15% oxygen that oxidizes the combustion process in the boiler. Thus, the gas temperature at the inlet to the boiler amounts to 580{sup o}C at an excess air factor a = 3.50; at the outlet these parameters are utilized to T{sub out} = 139{sup o}C and a{sub out} = 1.17. The proportions of the GTU/boiler loads that can actually be organized at the generating unit (and have been checked by testing) are presented and the proportions of loads recommended for the most efficient operation of the boiler are determined. The performance characteristics of the boiler are presented for various proportions of GTU/boiler loads. The operating conditions of the superheater and of the convective trailing heating surfaces are presented as well as the ecological parameters of the generating unit.

  13. Fixed-bed gasification research using US coals. Volume 11. Gasification of Minnesota peat. [Peat pellets and peat sods

    SciTech Connect (OSTI)

    Thimsen, D.; Maurer, R.E.; Pooler, A.R.; Pui, D.; Liu, B.; Kittelson, D.

    1985-05-01

    A single-staged, fixed-bed Wellman-Galusha gasifier coupled with a hot, raw gas combustion system and scrubber has been used to gasify numerous coals from throughout the United States. The gasification test program is organized as a coooperative effort by private industrial participants and governmental agencies. The consortium of participants is organized under the Mining and Industrial Fuel Gas (MIFGa) Group. This report is the eleventh volume in a series of reports describing the atmospheric pressure, fixed-bed gasification of US coals. This specific report describes the gasification of peat pellets and peat sods during 3 different test periods. 2 refs., 20 figs., 13 tabs.

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

    SciTech Connect (OSTI)

    Wang,Ping; Massoudi, Mehrdad

    2011-01-01

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

  15. Underground coal gasification: a brief review of current status

    SciTech Connect (OSTI)

    Shafirovich, E.; Varma, A.

    2009-09-15

    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.

  16. Black Liquor Gasification Process Review and Status Update 

    E-Print Network [OSTI]

    Brown, C.

    1993-01-01

    After more than two decades of research and development, black liquor gasification is poised to become a commercial reality in the 90's. Several promising developments are underway in North America and Europe. In fact, all major recovery boiler...

  17. Gasification and combustion modeling for porous char particles

    E-Print Network [OSTI]

    Singer, Simcha Lev

    2012-01-01

    Gasification and combustion of porous char particles occurs in many industrial applications. Reactor-scale outputs of importance depend critically on processes that occur at the particle-scale. Because char particles often ...

  18. Study of catalysis of coal gasification at elevated pressures...

    Office of Scientific and Technical Information (OSTI)

    Study of catalysis of coal gasification at elevated pressures. Evaluation of 20 compounds at 850sup 0C Citation Details In-Document Search Title: Study of catalysis of coal...

  19. Heat exchanger for coal gasification process

    DOE Patents [OSTI]

    Blasiole, George A. (Greensburg, PA)

    1984-06-19

    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.

  20. Advanced Gasification By-Product Utilization

    SciTech Connect (OSTI)

    Rodney Andrews; Aurora Rubel; Jack Groppo; Brock Marrs; Ari Geertsema; Frank Huggins; M. Mercedes Maroto-Valer; Brandie M. Markley; Zhe Lu; Harold Schobert

    2006-08-31

    With the passing of legislation designed to permanently cap and reduce mercury emissions from coal-fired utilities, it is more important than ever to develop and improve upon methods of controlling mercury emissions. One promising technique is carbon sorbent injection into the flue gas of the coal-fired power plant. Currently, this technology is very expensive as costly commercially activated carbons are used as sorbents. There is also a significant lack of understanding of the interaction between mercury vapor and the carbon sorbent, which adds to the difficulty of predicting the amount of sorbent needed for specific plant configurations. Due to its inherent porosity and adsorption properties as well as on-site availability, carbons derived from gasifiers are potential mercury sorbent candidates. Furthermore, because of the increasing restricted use of landfilling, the coal industry is very interested in finding uses for these materials as an alternative to the current disposal practice. The results of laboratory investigations and supporting technical assessments conducted under DOE Subcontract No. DE-FG26-03NT41795 are reported. This contract was with the University of Kentucky Research Foundation, which supports work with the University of Kentucky Center for Applied Energy Research and The Pennsylvania State University Energy Institute. The worked described was part of a project entitled ''Advanced Gasification By-Product Utilization''. This work involved the development of technologies for the separation and characterization of coal gasification slags from operating gasification units, activation of these materials to increase mercury and nitrogen oxide capture efficiency, assessment of these materials as sorbents for mercury and nitrogen oxides, assessment of the potential for leaching of Hg captured by the carbons, analysis of the slags for cement applications, and characterization of these materials for use as polymer fillers. The objectives of this collaborative effort between the University of Kentucky Center for Applied Energy Research (CAER), The Pennsylvania State University Energy Institute, and industry collaborators supplying gasifier char samples were to investigate the potential use of gasifier slag carbons as a source of low cost sorbent for Hg and NOX capture from combustion flue gas, concrete applications, polymer fillers and as a source of activated carbons. Primary objectives were to determine the relationship of surface area, pore size, pore size distribution, and mineral content on Hg storage of gasifier carbons and to define the site of Hg capture. The ability of gasifier slag carbon to capture NOX and the effect of NOX on Hg adsorption were goals. Secondary goals were the determination of the potential for use of the slags for cement and filler applications. Since gasifier chars have already gone through a devolatilization process in a reducing atmosphere in the gasifier, they only required to be activated to be used as activated carbons. Therefore, the principal objective of the work at PSU was to characterize and utilize gasification slag carbons for the production of activated carbons and other carbon fillers. Tests for the Hg and NOX adsorption potential of these activated gasifier carbons were performed at the CAER. During the course of this project, gasifier slag samples chemically and physically characterized at UK were supplied to PSU who also characterized the samples for sorption characteristics and independently tested for Hg-capture. At the CAER as-received slags were tested for Hg and NOX adsorption. The most promising of these were activated chemically. The PSU group applied thermal and steam activation to a representative group of the gasifier slag samples separated by particle sizes. The activated samples were tested at UK for Hg-sorption and NOX capture and the most promising Hg adsorbers were tested for Hg capture in a simulated flue gas. Both UK and PSU tested the use of the gasifier slag samples as fillers. The CAER analyzed the slags for possible use in cement applications

  1. Gasification Studies Task 4 Topical Report

    SciTech Connect (OSTI)

    Whitty, Kevin; Fletcher, Thomas; Pugmire, Ronald; Smith, Philip; Sutherland, James; Thornock, Jeremy; Boshayeshi, Babak; Hunsacker, Isaac; Lewis, Aaron; Waind, Travis; Kelly, Kerry

    2014-02-01

    A key objective of the Task 4 activities has been to develop simulation tools to support development, troubleshooting and optimization of pressurized entrained-flow coal gasifiers. The overall gasifier models (Subtask 4.1) combine submodels for fluid flow (Subtask 4.2) and heat transfer (Subtask 4.3) with fundamental understanding of the chemical processes (Subtask 4.4) processes that take place as coal particles are converted to synthesis gas and slag. However, it is important to be able to compare predictions from the models against data obtained from actual operating coal gasifiers, and Subtask 4.6 aims to provide an accessible, non-proprietary system, which can be operated over a wide range of conditions to provide well-characterized data for model validation. Highlights of this work include: • Verification and validation activities performed with the Arches coal gasification simulation tool on experimental data from the CANMET gasifier (Subtask 4.1). • The simulation of multiphase reacting flows with coal particles including detailed gas-phase chemistry calculations using an extension of the one-dimensional turbulence model’s capability (Subtask 4.2). • The demonstration and implementation of the Reverse Monte Carlo ray tracing (RMCRT) radiation algorithm in the ARCHES code (Subtask 4.3). • Determination of steam and CO{sub 2} gasification kinetics of bituminous coal chars at high temperature and elevated pressure under entrained-flow conditions (Subtask 4.4). In addition, attempts were made to gain insight into the chemical structure differences between young and mature coal soot, but both NMR and TEM characterization efforts were hampered by the highly reacted nature of the soot. • The development, operation, and demonstration of in-situ gas phase measurements from the University of Utah’s pilot-scale entrained-flow coal gasifier (EFG) (Subtask 4.6). This subtask aimed at acquiring predictable, consistent performance and characterizing the environment within the gasifier.

  2. Modeling of contaminant transport in underground coal gasification

    SciTech Connect (OSTI)

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

    2009-01-15

    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.

  3. Solar coal gasification reactor with pyrolysis gas recycle

    DOE Patents [OSTI]

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

    1983-01-01

    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.

  4. Subtask 4.2 - Coal Gasification Short Course

    SciTech Connect (OSTI)

    Kevin Galbreath

    2009-06-30

    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.

  5. Assessment of advanced coal-gasification processes. [AVCO high throughput gasification in process; Bell High Mass Flux process; CS-R process; and Exxon Gasification process

    SciTech Connect (OSTI)

    McCarthy, J.; Ferrall, J.; Charng, T.; Houseman, J.

    1981-06-01

    This report represents a technical assessment of the following advanced coal gasification processes: AVCO High Throughput Gasification (HTG) Process, Bell Single - Stage High Mass Flux (HMF) Process, Cities Service/Rockwell (CS/R) Hydrogasification Process, and the Exxon Catalytic Coal Gasification (CCG) Process. Each process is evaluated for its potential to produce SNG from a bituminous coal. In addition to identifying the new technology these processes represent, key similarities/differences, strengths/weaknesses, and potential improvements to each process are identified. The AVCO HTG and the Bell HMF gasifiers share similarities with respect to: short residence time (SRT), high throughput rate, slagging and syngas as the initial raw product gas. The CS/R Hydrogasifier is also SRT but is non-slagging and produces a raw gas high in methane content. The Exxon CCG gasifier is a long residence time, catalytic fluidbed reactor producing all of the raw product methane in the gasifier.

  6. Influence of pressure on coal pyrolysis and char gasification

    SciTech Connect (OSTI)

    Haiping Yang; Hanping Chen; Fudong Ju; Rong Yan; Shihong Zhang [Huazhong University of Science and Technology, Wuhan (China). State Key Laboratory of Coal Combustion

    2007-12-15

    Coal char structure varied greatly with pyrolysis pressure, which has a significant influence on the gasification reactivity. In this study, the influence of pressure on the behavior of coal pyrolysis and physicochemical structure and gasification characteristics of the resultant coal char was investigated using a pressurized thermogravimetric analyzer combined with an ambient thermogravimetric analyzer. First, the pyrolysis of Shenfu (SF) bituminous coal was performed in a pressurized thermogravimetric analyzer (TGA) at different pressures (0.1, 0.8, 1.5, 3, and 5 MPa). The volatile mainly evolved out at 400-800{sup o}C. The gas products are mainly CO{sub 2}, CO, CH{sub 4}, and light aliphatics with some water. It was observed that the pyrolysis of coal was shifted to lower temperature (50{sup o}C) with pressure increasing from ambient to 5 MPa, and the devolatilization rate of coal pyrolysis was decreased and the coal char yield was increased slightly. The structure of solid coal char was analyzed using FTIR, ASAP2020, and CNHS. In the solid char, the main organic functional groups are mainly CO, C-C (alkane), C-H ar, C-O-C, and C=C ar. The carbon content was increased while H content decreased. Finally, the gasification of the solid char was preformed at ambient pressure with CO{sub 2} as gasify agent. The gasification process of coal char can be divided into postpyrolysis and char gasification. Higher pressure accelerated the initial stage of char gasification, and higher gasification reactivity was observed for char derived at 5 MPa. 23 refs., 8 figs., 5 tabs.

  7. Aerodynamics and Heat Transfer Studies of Parameters Specific to the IGCC-Requirements: Endwall Contouring, Leading Edge and Blade Tip Ejection under Rotating Turbine Conditions

    SciTech Connect (OSTI)

    Schobeiri, Meinhard; Han, Je-Chin

    2014-09-30

    This report deals with the specific aerodynamics and heat transfer problematic inherent to high pressure (HP) turbine sections of IGCC-gas turbines. Issues of primary relevance to a turbine stage operating in an IGCC-environment are: (1) decreasing the strength of the secondary flow vortices at the hub and tip regions to reduce (a), the secondary flow losses and (b), the potential for end wall deposition, erosion and corrosion due to secondary flow driven migration of gas flow particles to the hub and tip regions, (2) providing a robust film cooling technology at the hub and that sustains high cooling effectiveness less sensitive to deposition, (3) investigating the impact of blade tip geometry on film cooling effectiveness. The document includes numerical and experimental investigations of above issues. The experimental investigations were performed in the three-stage multi-purpose turbine research facility at the Turbomachinery Performance and Flow Research Laboratory (TPFL), Texas A&M University. For the numerical investigations a commercial Navier-Stokes solver was utilized.

  8. The Development of a Hydrothermal Method for Slurry Feedstock Preparation for Gasification Technology

    E-Print Network [OSTI]

    He, Wei

    2011-01-01

    production processes, such as gasification, favor a continuousProcess Configuration..119 Fig 5.2 Continuous Slurry Production

  9. Enhanced durability and reactivity for zinc ferrite desulfurization sorbent. Quarterly technical progress report 8, July--September 1988

    SciTech Connect (OSTI)

    Jha, M.C.; Berggren, M.H.

    1988-11-14

    AMAX Research & Development Center (AMAX R&D) has been investigating methods for enhancing the reactivity and durability of the zinc ferrite desulfurization sorbent. Zinc ferrite sorbents are intended for use in desulfurization of hot coal gas in integrated gasification combined cycle (IGCC) or molten carbonate fuel cell (MCFC) applications. For the present program, the reactivity of the sorbent may be defined as its sulfur sorption capacity at the breakthrough point and at saturation in a bench-scale, fixed-bed reactor. Durability may be defined as the ability of the sorbent to maintain important physical characteristics such As size, strength, and specific surface area during 10 cycles of sulfidation and oxidation.

  10. Enhanced durability and reactivity for zinc ferrite desulfurization sorbent. Quarterly technical progress report 9, October--December 1988

    SciTech Connect (OSTI)

    Jha, M.C.; Berggren, M.H.

    1989-03-06

    AMAX Research & Development Center (AMAX R&D) has been investigating methods for enhancing the reactivity and durability of the zinc ferrite desulfurization sorbent. Zinc ferrite sorbents are intended for use in desulfurization of hot coal gas in integrated gasification combined cycle (IGCC) or molten carbonate fuel cell (MCFC) applications. For the present program, the reactivity of the sorbent may be defined as its sulfur sorption capacity at the breakthrough point and at saturation in a bench-scale, fixed-bed reactor. Durability may be defined as the ability of the sorbent to maintain important physical characteristics such As size, strength, and specific surface area during 10 cycles of sulfidation and oxidation.

  11. Enhanced durability and reactivity for zinc ferrite desulfurization sorbent

    SciTech Connect (OSTI)

    Jha, M.C.; Berggren, M.H.

    1989-05-02

    AMAX Research Development Center (AMAX R D) has been investigating methods for enhancing the reactivity and durability of the zinc ferrite desulfurization sorbent. Zinc ferrite sorbents are intended for use in desulfurization of hot coal gas in integrated gasification combined cycle (IGCC) or molten carbonate fuel cell (MCFC) applications. For the present program, the reactivity of the sorbent may be defined as its sulfur sorption capacity at the breakthrough point and at saturation in a bench-scale, fixed-bed reactor. Durability may be defined as the ability of the sorbent to maintain important physical characteristics such As size, strength, and specific surface area during 10 cycles of sulfidation and oxidation.

  12. Enhanced durability and reactivity for zinc ferrite desulfurization sorbent

    SciTech Connect (OSTI)

    Jha, M.C.; Berggren, M.H.

    1988-11-14

    AMAX Research Development Center (AMAX R D) has been investigating methods for enhancing the reactivity and durability of the zinc ferrite desulfurization sorbent. Zinc ferrite sorbents are intended for use in desulfurization of hot coal gas in integrated gasification combined cycle (IGCC) or molten carbonate fuel cell (MCFC) applications. For the present program, the reactivity of the sorbent may be defined as its sulfur sorption capacity at the breakthrough point and at saturation in a bench-scale, fixed-bed reactor. Durability may be defined as the ability of the sorbent to maintain important physical characteristics such As size, strength, and specific surface area during 10 cycles of sulfidation and oxidation.

  13. Enhanced durability and reactivity for zinc ferrite desulfurization sorbent

    SciTech Connect (OSTI)

    Jha, M.C.; Berggren, M.H.

    1989-03-06

    AMAX Research Development Center (AMAX R D) has been investigating methods for enhancing the reactivity and durability of the zinc ferrite desulfurization sorbent. Zinc ferrite sorbents are intended for use in desulfurization of hot coal gas in integrated gasification combined cycle (IGCC) or molten carbonate fuel cell (MCFC) applications. For the present program, the reactivity of the sorbent may be defined as its sulfur sorption capacity at the breakthrough point and at saturation in a bench-scale, fixed-bed reactor. Durability may be defined as the ability of the sorbent to maintain important physical characteristics such As size, strength, and specific surface area during 10 cycles of sulfidation and oxidation.

  14. Enhanced durability and reactivity for zinc ferrite desulfurization sorbent. Quarterly technical progress report No. 3, April--June 1987

    SciTech Connect (OSTI)

    Jha, M.C.; Baltich, L.K.; Berggren, M.H.

    1987-08-28

    AMAX Research & Development Center (AMAX R&D) has been investigating methods for enhancing the reactivity and durability of the zinc ferrite desulfurization sorbent. Zinc ferrite sorbents are intended for use in desulfurization of hot coal gas in integrated gasification combined cycle (IGCC) or molten carbonate fuel cell (MCFC) applications. For the present program, the reactivity of the sorbent may be defined as its sulfur sorption capacity at the breakthrough point and at saturation in a bench-scale, fixed-bed reactor. Durability may be defined as the ability of the sorbent to maintain important physical characteristics such As size, strength, and specific surface area during 10 cycles of sulfidation and oxidation.

  15. Enhanced durability and reactivity for zinc ferrite desulfurization sorbent. Quarterly technical progress report 2, January--March 1987

    SciTech Connect (OSTI)

    Jha, M.C.; Baltich, L.K.; Berggren, M.H.

    1987-05-18

    AMAX Research & Development Center (AMAX R&D) has been investigating methods for enhancing the reactivity and durability of the zinc ferrite desulfurization sorbent. Zinc ferrite sorbents are intended for use in desulfurization of hot coal gas in integrated gasification combined cycle (IGCC) or molten carbonate fuel cell (MCFC) applications. For the present program, the reactivity of the sorbent may be defined as its sulfur sorption capacity at the breakthrough point and at saturation in a bench-scale, fixed-bed reactor. Durability may be defined as the ability of the sorbent to maintain important physical characteristics such As size, strength, and specific surface area during 10 cycles of sulfidation and oxidation.

  16. Enhanced durability and reactivity for zinc ferrite desulfurization sorbent. Volume 1, Bench-scale testing and analysis

    SciTech Connect (OSTI)

    Jha, M.C.; Berggren, M.H.

    1989-05-02

    AMAX Research & Development Center (AMAX R&D) has been investigating methods for enhancing the reactivity and durability of the zinc ferrite desulfurization sorbent. Zinc ferrite sorbents are intended for use in desulfurization of hot coal gas in integrated gasification combined cycle (IGCC) or molten carbonate fuel cell (MCFC) applications. For the present program, the reactivity of the sorbent may be defined as its sulfur sorption capacity at the breakthrough point and at saturation in a bench-scale, fixed-bed reactor. Durability may be defined as the ability of the sorbent to maintain important physical characteristics such As size, strength, and specific surface area during 10 cycles of sulfidation and oxidation.

  17. Enhanced durability and reactivity for zinc ferrite desulfurization sorbent

    SciTech Connect (OSTI)

    Jha, M.C.; Berggren, M.H.

    1988-08-19

    AMAX Research Development Center (AMAX R D) has been investigating methods for enhancing the reactivity and durability of the zinc ferrite desulfurization sorbent. Zinc ferrite sorbents are intended for use in desulfurization of hot coal gas in integrated gasification combined cycle (IGCC) or molten carbonate fuel cell (MCFC) applications. For the present program, the reactivity of the sorbent may be defined as its sulfur sorption capacity at the breakthrough point and at saturation in a bench-scale, fixed-bed reactor. Durability may be defined as the ability of the sorbent to maintain important physical characteristics such As size, strength, and specific surface area during 10 cycles of sulfidation and oxidation.

  18. Enhanced durability and reactivity for zinc ferrite desulfurization sorbent

    SciTech Connect (OSTI)

    Jha, M.C.; Baltich, L.K.; Berggren, M.H.

    1987-05-18

    AMAX Research Development Center (AMAX R D) has been investigating methods for enhancing the reactivity and durability of the zinc ferrite desulfurization sorbent. Zinc ferrite sorbents are intended for use in desulfurization of hot coal gas in integrated gasification combined cycle (IGCC) or molten carbonate fuel cell (MCFC) applications. For the present program, the reactivity of the sorbent may be defined as its sulfur sorption capacity at the breakthrough point and at saturation in a bench-scale, fixed-bed reactor. Durability may be defined as the ability of the sorbent to maintain important physical characteristics such As size, strength, and specific surface area during 10 cycles of sulfidation and oxidation.

  19. Enhanced durability and reactivity for zinc ferrite desulfurization sorbent

    SciTech Connect (OSTI)

    Jha, M.C.; Baltich, L.K.; Berggren, M.H.

    1987-08-28

    AMAX Research Development Center (AMAX R D) has been investigating methods for enhancing the reactivity and durability of the zinc ferrite desulfurization sorbent. Zinc ferrite sorbents are intended for use in desulfurization of hot coal gas in integrated gasification combined cycle (IGCC) or molten carbonate fuel cell (MCFC) applications. For the present program, the reactivity of the sorbent may be defined as its sulfur sorption capacity at the breakthrough point and at saturation in a bench-scale, fixed-bed reactor. Durability may be defined as the ability of the sorbent to maintain important physical characteristics such As size, strength, and specific surface area during 10 cycles of sulfidation and oxidation.

  20. Enhanced durability and reactivity for zinc ferrite desulfurization sorbent. Quarterly technical progress report 7, April--June 1988

    SciTech Connect (OSTI)

    Jha, M.C.; Berggren, M.H.

    1988-08-19

    AMAX Research & Development Center (AMAX R&D) has been investigating methods for enhancing the reactivity and durability of the zinc ferrite desulfurization sorbent. Zinc ferrite sorbents are intended for use in desulfurization of hot coal gas in integrated gasification combined cycle (IGCC) or molten carbonate fuel cell (MCFC) applications. For the present program, the reactivity of the sorbent may be defined as its sulfur sorption capacity at the breakthrough point and at saturation in a bench-scale, fixed-bed reactor. Durability may be defined as the ability of the sorbent to maintain important physical characteristics such As size, strength, and specific surface area during 10 cycles of sulfidation and oxidation.

  1. Accelerating progress toward operational excellence of fossil energy plants with CO2 capture

    SciTech Connect (OSTI)

    Zitney, S.; Liese, E.; Mahapatra, P.; Turton, R. Bhattacharyya, D.

    2012-01-01

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

  2. Tunable Diode Laser Sensors to Monitor Temperature and Gas Composition in High-Temperature Coal Gasifiers

    SciTech Connect (OSTI)

    Hanson, Ronald; Whitty, Kevin

    2014-12-01

    The integrated gasification combined cycle (IGCC) when combined with carbon capture and storage can be one of the cleanest methods of extracting energy from coal. Control of coal and biomass gasification processes to accommodate the changing character of input-fuel streams is required for practical implementation of integrated gasification combined-cycle (IGCC) technologies. Therefore a fast time-response sensor is needed for real-time monitoring of the composition and ideally the heating value of the synthesis gas (here called syngas) as it exits the gasifier. The goal of this project was the design, construction, and demonstration an in situ laserabsorption sensor to monitor multiple species in the syngas output from practical-scale coal gasifiers. This project investigated the hypothesis of using laser absorption sensing in particulateladen syngas. Absorption transitions were selected with design rules to optimize signal strength while minimizing interference from other species. Successful in situ measurements in the dusty, high-pressure syngas flow were enabled by Stanford’s normalized and scanned wavelength modulation strategy. A prototype sensor for CO, CH4, CO2, and H2O was refined with experiments conducted in the laboratory at Stanford University, a pilot-scale at the University of Utah, and an engineering-scale gasifier at DoE’s National Center for Carbon Capture with the demonstration of a prototype sensor with technical readiness level 6 in the 2014 measurement campaign.

  3. Cyclic flow underground coal gasification process

    DOE Patents [OSTI]

    Bissett, Larry A. (Morgantown, WV)

    1978-01-01

    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.

  4. Pneumatic solids feeder for coal gasification reactor

    SciTech Connect (OSTI)

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

    1991-12-31

    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.

  5. Pulsed combustion process for black liquor gasification

    SciTech Connect (OSTI)

    Durai-Swamy, K.; Mansour, M.N.; Warren, D.W.

    1991-02-01

    The objective of this project is to test an energy efficient, innovative black liquor recovery system on an industrial scale. In the MTCI recovery process, black liquor is sprayed directly onto a bed of sodium carbonate solids which is fluidized by steam. Direct contact of the black liquor with hot bed solids promotes high rates of heating and pyrolysis. Residual carbon, which forms as a deposit on the particle surface, is then gasified by reaction with steam. Heat is supplied from pulse combustor resonance tubes which are immersed within the fluid bed. A portion of the gasifier product gas is returned to the pulse combustors to provide the energy requirements of the reactor. Oxidized sulfur species are partially reduced by reaction with the gasifier products, principally carbon monoxide and hydrogen. The reduced sulfur decomposed to solid sodium carbonate and gaseous hydrogen sulfide (H{sub 2}S). Sodium values are recovered by discharging a dry sodium carbonate product from the gasifier. MTCI's indirectly heated gasification technology for black liquor recovery also relies on the scrubbing of H{sub 2}S for product gases to regenerate green liquor for reuse in the mill circuit. Due to concerns relative to the efficiency of sulfur recovery in the MTCI integrated process, an experimental investigation was undertaken to establish performance and design data for this portion of the system.

  6. Survey of biomass gasification. Volume III. Current technology and research

    SciTech Connect (OSTI)

    None

    1980-04-01

    This survey of biomass gasification was written to aid the Department of Energy and the Solar Energy Research Institute Biological and Chemical Conversion Branch in determining the areas of gasification that are ready for commercialization now and those areas in which further research and development will be most productive. Chapter 8 is a survey of gasifier types. Chapter 9 consists of a directory of current manufacturers of gasifiers and gasifier development programs. Chapter 10 is a sampling of current gasification R and D programs and their unique features. Chapter 11 compares air gasification for the conversion of existing gas/oil boiler systems to biomass feedstocks with the price of installing new biomass combustion equipment. Chapter 12 treats gas conditioning as a necessary adjunct to all but close-coupled gasifiers, in which the product is promptly burned. Chapter 13 evaluates, technically and economically, synthesis-gas processes for conversion to methanol, ammonia, gasoline, or methane. Chapter 14 compiles a number of comments that have been assembled from various members of the gasifier community as to possible roles of the government in accelerating the development of gasifier technology and commercialization. Chapter 15 includes recommendations for future gasification research and development.

  7. Biomass Gasification using Solar Thermal Energy M. Munzinger and K. Lovegrove

    E-Print Network [OSTI]

    Biomass Gasification using Solar Thermal Energy M. Munzinger and K. Lovegrove Solar Thermal Group technical pathways for biomass gasification and shows their advantages and disadvantages especially in connection with the use of solar heat as energy source for the conversion reaction. Biomass gasification

  8. Modelling Rates of Gasification of a Char Particle in Chemical Looping Combustion

    E-Print Network [OSTI]

    Saucedo, Marco A.; Dennis, John S.; Scott, Stuart A.

    2014-07-15

    Rates of gasification of lignite char were compared when gasification with CO2 was undertaken in a fluidised bed of either (i) an active Fe-based oxygen carrier used for chemical looping or (ii) inert sand. The kinetics of the gasification were...

  9. Formation of CO precursors during char gasification with O2, CO2 and H2O

    E-Print Network [OSTI]

    Truong, Thanh N.

    Formation of CO precursors during char gasification with O2, CO2 and H2O Alejandro Montoya a are presented to get insight into an unified mechanism of uncatalyzed carbon gasification. D 2002 Elsevier Science B.V. All rights reserved. Keywords: Gasification; Chemisorption; Molecular simulation; Surface

  10. Thermophysical models of underground coal gasification and FEM analysis

    SciTech Connect (OSTI)

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

    2007-11-15

    In this study, mathematical models of the coupled thermohydromechanical process of coal rock mass in an underground coal gasification panel are established. Combined with the calculation example, the influence of heating effects on the observed values and simulated values for pore water pressure, stress, and displacement in the gasification panel are fully discussed and analyzed. Calculation results indicate that 38, 62, and 96 days after the experiment, the average relative errors for the calculated values and measured values for the temperature and water pressure were between 8.51-11.14% and 3-10%, respectively; with the passage of gasification time, the calculated errors for the vertical stress and horizontal stress gradually declined, but the simulated errors for the horizontal and vertical displacements both showed a rising trend. On the basis of the research results, the calculated values and the measured values agree with each other very well.

  11. Fuel-Flexible Gasification-Combustion Technology for Production of H2 and Sequestration-Ready CO2

    SciTech Connect (OSTI)

    George Rizeq; Parag Kulkarni; Wei Wei; Arnaldo Frydman; Thomas McNulty; Roger Shisler

    2005-11-01

    It is expected that in the 21st century the Nation will continue to rely on fossil fuels for electricity, transportation, and chemicals. It will be necessary to improve both the process efficiency and environmental impact performance of fossil fuel utilization. GE Global Research is developing an innovative fuel-flexible Unmixed Fuel Processor (UFP) technology to produce H{sub 2}, power, and sequestration-ready CO{sub 2} from coal and other solid fuels. The UFP module offers the potential for reduced cost, increased process efficiency relative to conventional gasification and combustion systems, and near-zero pollutant emissions including NO{sub x}. GE was awarded a contract from U.S. DOE NETL to develop the UFP technology. Work on the Phase I program started in October 2000, and work on the Phase II effort started in April 2005. In the UFP technology, coal and air are simultaneously converted into separate streams of (1) high-purity hydrogen that can be utilized in fuel cells or turbines, (2) sequestration-ready CO{sub 2}, and (3) high temperature/pressure vitiated air to produce electricity in a gas turbine. The process produces near-zero emissions with an estimated efficiency higher than IGCC with conventional CO2 separation. The Phase I R&D program established the feasibility of the integrated UFP technology through lab-, bench- and pilot-scale testing and investigated operating conditions that maximize separation of CO{sub 2} and pollutants from the vent gas, while simultaneously maximizing coal conversion efficiency and hydrogen production. The Phase I effort integrated experimental testing, modeling and preliminary economic studies to demonstrate the UFP technology. The Phase II effort will focus on three high-risk areas: economics, sorbent attrition and lifetime, and product gas quality for turbines. The economic analysis will include estimating the capital cost as well as the costs of hydrogen and electricity for a full-scale UFP plant. These costs will be benchmarked with IGCC polygen costs for plants of similar size. Sorbent attrition and lifetime will be addressed via bench-scale experiments that monitor sorbent performance over time and by assessing materials interactions at operating conditions. The product gas from the third reactor (high-temperature vitiated air) will be evaluated to assess the concentration of particulates, pollutants and other impurities relative to the specifications required for gas turbine feed streams. This is the eighteenth quarterly technical progress report for the UFP program, which is supported by U.S. DOE NETL (Contract No. DE-FC26-00FT40974) and GE. This report summarizes program accomplishments for the Phase II period starting July 01, 2005 and ending September 30, 2005. The report includes an introduction summarizing the UFP technology, main program tasks, and program objectives; it also provides a summary of program activities and accomplishments covering progress in tasks including process modeling, scale-up and economic analysis.

  12. Wood Gasification: Where It's At, Where It's Going 

    E-Print Network [OSTI]

    Murphy, M. L.

    1981-01-01

    the proven combustion system. With other applications such as the firing of lime kilns in the pul p and pape r indus try where the opti ons, other than fossil fuel s and gasification, are non existent and the economics for gasification are very similar... in biomass gasifi cation. As early as 1839, processes were in operation on coal, wood or other residues in which a combustible off-gas, or producer gas as it was aptly dubbed, was generated by the incomplete fuel oxidatior, \

  13. High-pressure gasification of Montana subbituminous coal

    SciTech Connect (OSTI)

    Goyal, A.; Bryan, B.; Rehmat, A.

    1991-01-01

    A data base for the fluidized-bed gasification of different coals at elevated pressures has been developed at the Institute of Gas Technology (IGT) with different ranks of coal at pressures up to 450 psig and at temperatures dictated by the individual coals. Adequate data have been obtained to characterize the effect of pressure on the gasification of Montana Rosebud subbituminous coal and North Dakota lignite. The results obtained with Montana Rosebud subbituminous coal are presented here. This program was funded by the Gas Research Institute. 9 refs., 10 figs., 3 tabs.

  14. Hydrogen Production Cost Estimate Using Biomass Gasification: Independent Review

    SciTech Connect (OSTI)

    2011-10-01

    This independent review is the conclusion arrived at from data collection, document reviews, interviews and deliberation from December 2010 through April 2011 and the technical potential of Hydrogen Production Cost Estimate Using Biomass Gasification. The Panel reviewed the current H2A case (Version 2.12, Case 01D) for hydrogen production via biomass gasification and identified four principal components of hydrogen levelized cost: CapEx; feedstock costs; project financing structure; efficiency/hydrogen yield. The panel reexamined the assumptions around these components and arrived at new estimates and approaches that better reflect the current technology and business environments.

  15. Mass transfer effects in a gasification riser

    SciTech Connect (OSTI)

    Breault, Ronald W [U.S. DOE; Li, Tingwen [URS; Nicoletti, Phillip [URS

    2013-01-01

    In the development of multiphase reacting computational fluid dynamics (CFD) codes, a number of simplifications were incorporated into the codes and models. One of these simplifications was the use of a simplistic mass transfer correlation for the faster reactions and omission of mass transfer effects completely on the moderate speed and slow speed reactions such as those in a fluidized bed gasifier. Another problem that has propagated is that the mass transfer correlation used in the codes is not universal and is being used far from its developed bubbling fluidized bed regime when applied to circulating fluidized bed (CFB) riser reactors. These problems are true for the major CFD codes. To alleviate this problem, a mechanistic based mass transfer coefficient algorithm has been developed based upon an earlier work by Breault et al. This fundamental approach uses the local hydrodynamics to predict a local, time varying mass transfer coefficient. The predicted mass transfer coefficients and the corresponding Sherwood numbers agree well with literature data and are typically about an order of magnitude lower than the correlation noted above. The incorporation of the new mass transfer model gives the expected behavior for all the gasification reactions evaluated in the paper. At the expected and typical design values for the solid flow rate in a CFB riser gasifier an ANOVA analysis has shown the predictions from the new code to be significantly different from the original code predictions. The new algorithm should be used such that the conversions are not over predicted. Additionally, its behaviors with changes in solid flow rate are consistent with the changes in the hydrodynamics.

  16. BIOMASS COGASIFICATION AT POLK POWER STATION

    SciTech Connect (OSTI)

    John McDaniel

    2002-05-01

    Part of a closed loop biomass crop was recently harvested to produce electricity in Tampa Electric's Polk Power Station Unit No.1. No technical impediments to incorporating a small percentage of biomass into Polk Power Station's fuel mix were identified. Appropriate dedicated storage and handling equipment would be required for routine biomass use. Polk Unit No.1 is an integrated gasification combined cycle (IGCC) power plant. IGCC is a new approach to generating electricity cleanly from solid fuels such as coal, petroleum coke, The purpose of this experiment was to demonstrate the Polk Unit No.1 could process biomass as a fraction of its fuel without an adverse impact on availability and plant performance. The biomass chosen for the test was part of a crop of closed loop Eucalyptus trees.

  17. Performance and cost models for the direct sulfur recovery process. Task 1 Topical report, Volume 3

    SciTech Connect (OSTI)

    Frey, H.C. [North Carolina State Univ., Raleigh, NC (United States); Williams, R.B. [Carneigie Mellon Univ., Pittsburgh, PA (United States)

    1995-09-01

    The purpose of this project is to develop performance and cost models of the Direct Sulfur Recovery Process (DSRP). The DSRP is an emerging technology for sulfur recovery from advanced power generation technologies such as Integrated Gasification Combined Cycle (IGCC) systems. In IGCC systems, sulfur present in the coal is captured by gas cleanup technologies to avoid creating emissions of sulfur dioxide to the atmosphere. The sulfur that is separated from the coal gas stream must be collected. Leading options for dealing with the sulfur include byproduct recovery as either sulfur or sulfuric acid. Sulfur is a preferred byproduct, because it is easier to handle and therefore does not depend as strongly upon the location of potential customers as is the case for sulfuric acid. This report describes the need for new sulfur recovery technologies.

  18. EIS-0072: Great Plains Gasification Project, Mercer County, North Dakota

    Broader source: Energy.gov [DOE]

    The Office of Fossil Energy prepared this EIS to evaluate the impacts of a project to construct a 125 million cubic feet per day coal gasification facility located in Mercer County, North Dakota. The Office of Fossil Energy adopted three environmental impact evaluation documents prepared by other Federal agencies to develop this EIS.

  19. Power Systems Development Facility Gasification Test Campaign TC22

    SciTech Connect (OSTI)

    Southern Company Services

    2008-11-01

    In support of technology development to utilize coal for efficient, affordable, and environmentally clean power generation, the Power Systems Development Facility (PSDF), located in Wilsonville, Alabama, routinely demonstrates gasification technologies using various types of coals. The PSDF is an engineering scale demonstration of key features of advanced coal-fired power systems, including a KBR Transport Gasifier, a hot gas particulate control device, advanced syngas cleanup systems, and high-pressure solids handling systems. This report summarizes the results of TC22, the first test campaign using a high moisture lignite from Mississippi as the feedstock in the modified Transport Gasifier configuration. TC22 was conducted from March 24 to April 17, 2007. The gasification process was operated for 543 hours, increasing the total gasification operation at the PSDF to over 10,000 hours. The PSDF gasification process was operated in air-blown mode with a total of about 1,080 tons of coal. Coal feeder operation was challenging due to the high as-received moisture content of the lignite, but adjustments to the feeder operating parameters reduced the frequency of coal feeder trips. Gasifier operation was stable, and carbon conversions as high as 98.9 percent were demonstrated. Operation of the PCD and other support equipment such as the recycle gas compressor and ash removal systems operated reliably.

  20. Energy Optimization of Bioethanol Production via Gasification of Switchgrass

    E-Print Network [OSTI]

    Grossmann, Ignacio E.

    with membrane-PSA or water gas shift. Membrane separation, absorption with ethanol-amines and PSA are considered gasification, followed by steam reforming or partial oxidation. Next, the gas composition is adjusted greenhouse gas (GHG) emissions, as well as potentially provide higher net fossil fuel displacement

  1. EIS-0007: Low Btu Coal Gasification Facility and Industrial Park

    Broader source: Energy.gov [DOE]

    The U.S. Department of Energy (DOE) prepared this draft environmental impact statement that evaluates the potential environmental impacts that may be associated with the construction and operation of a low-Btu coal gasification facility and the attendant industrial park in Georgetown, Scott County, Kentucky. DOE cancelled this project after publication of the draft.

  2. Prospects for the Gasification of Refuse-Derived Fuel (RDF) 

    E-Print Network [OSTI]

    Woodruff, K. L.; Guard, R. F. W.

    1983-01-01

    Fluidized-bed gasification of wood waste is now a commercially proven technology. An Omnifuel gasifier in Hearst, Ontario, has been in operation since early 1981. It produces a low-BTU gas which is used to displace natural gas in existing boilers...

  3. 1 / 217 / 10 / 2014 The development of biomass gasification at

    E-Print Network [OSTI]

    Ahrendt, Wolfgang

    )-boilers could be retrofitted and turned into indirect gasification units at a significantly lower cost than, a technique that was less costly and potentially quick to commercialise. In addition the Chalmers researchers at a relatively low overall cost (10MSEK). The demonstration plant was built by Valmet Power AB and commissioned

  4. NREL: Energy Analysis - NREL Releases First Annual Technology...

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

    Conventional Coal Coal with Carbon Capture and Sequestration Integrated Gasification Combined Cycle Coal Natural Gas Combustion Turbines Natural Gas Combined Cycle...

  5. Techno Economic Analysis of Hydrogen Production by gasification of biomass

    SciTech Connect (OSTI)

    Francis Lau

    2002-12-01

    Biomass represents a large potential feedstock resource for environmentally clean processes that produce power or chemicals. It lends itself to both biological and thermal conversion processes and both options are currently being explored. Hydrogen can be produced in a variety of ways. The majority of the hydrogen produced in this country is produced through natural gas reforming and is used as chemical feedstock in refinery operations. In this report we will examine the production of hydrogen by gasification of biomass. Biomass is defined as organic matter that is available on a renewable basis through natural processes or as a by-product of processes that use renewable resources. The majority of biomass is used in combustion processes, in mills that use the renewable resources, to produce electricity for end-use product generation. This report will explore the use of hydrogen as a fuel derived from gasification of three candidate biomass feedstocks: bagasse, switchgrass, and a nutshell mix that consists of 40% almond nutshell, 40% almond prunings, and 20% walnut shell. In this report, an assessment of the technical and economic potential of producing hydrogen from biomass gasification is analyzed. The resource base was assessed to determine a process scale from feedstock costs and availability. Solids handling systems were researched. A GTI proprietary gasifier model was used in combination with a Hysys(reg. sign) design and simulation program to determine the amount of hydrogen that can be produced from each candidate biomass feed. Cost estimations were developed and government programs and incentives were analyzed. Finally, the barriers to the production and commercialization of hydrogen from biomass were determined. The end-use of the hydrogen produced from this system is small PEM fuel cells for automobiles. Pyrolysis of biomass was also considered. Pyrolysis is a reaction in which biomass or coal is partially vaporized by heating. Gasification is a more general term, and includes heating as well as the injection of other ''ingredients'' such as oxygen and water. Pyrolysis alone is a useful first step in creating vapors from coal or biomass that can then be processed in subsequent steps to make liquid fuels. Such products are not the objective of this project. Therefore pyrolysis was not included in the process design or in the economic analysis. High-pressure, fluidized bed gasification is best known to GTI through 30 years of experience. Entrained flow, in contrast to fluidized bed, is a gasification technology applied at much larger unit sizes than employed here. Coal gasification and residual oil gasifiers in refineries are the places where such designs have found application, at sizes on the order of 5 to 10 times larger than what has been determined for this study. Atmospheric pressure gasification is also not discussed. Atmospheric gasification has been the choice of all power system pilot plants built for biomass to date, except for the Varnamo plant in Sweden, which used the Ahlstrom (now Foster Wheeler) pressurized gasifier. However, for fuel production, the disadvantage of the large volumetric flows at low pressure leads to the pressurized gasifier being more economical.

  6. Assessment of the SRI Gasification Process for Syngas Generation with HTGR Integration -- White Paper

    SciTech Connect (OSTI)

    A.M. Gandrik

    2012-04-01

    This white paper is intended to compare the technical and economic feasibility of syngas generation using the SRI gasification process coupled to several high-temperature gas-cooled reactors (HTGRs) with more traditional HTGR-integrated syngas generation techniques, including: (1) Gasification with high-temperature steam electrolysis (HTSE); (2) Steam methane reforming (SMR); and (3) Gasification with SMR with and without CO2 sequestration.

  7. Co-gasification of municipal solid waste and material recovery in a large-scale gasification and melting system

    SciTech Connect (OSTI)

    Tanigaki, Nobuhiro; Manako, Kazutaka; Osada, Morihiro

    2012-04-15

    Highlights: Black-Right-Pointing-Pointer This study evaluates the effects of co-gasification of MSW with MSW bottom ash. Black-Right-Pointing-Pointer No significant difference between MSW treatment with and without MSW bottom ash. Black-Right-Pointing-Pointer PCDD/DFs yields are significantly low because of the high carbon conversion ratio. Black-Right-Pointing-Pointer Slag quality is significantly stable and slag contains few hazardous heavy metals. Black-Right-Pointing-Pointer The final landfill amount is reduced and materials are recovered by DMS process. - Abstract: This study evaluates the effects of co-gasification of municipal solid waste with and without the municipal solid waste bottom ash using two large-scale commercial operation plants. From the viewpoint of operation data, there is no significant difference between municipal solid waste treatment with and without the bottom ash. The carbon conversion ratios are as high as 91.7% and 95.3%, respectively and this leads to significantly low PCDD/DFs yields via complete syngas combustion. The gross power generation efficiencies are 18.9% with the bottom ash and 23.0% without municipal solid waste bottom ash, respectively. The effects of the equivalence ratio are also evaluated. With the equivalence ratio increasing, carbon monoxide concentration is decreased, and carbon dioxide and the syngas temperature (top gas temperature) are increased. The carbon conversion ratio is also increased. These tendencies are seen in both modes. Co-gasification using the gasification and melting system (Direct Melting System) has a possibility to recover materials effectively. More than 90% of chlorine is distributed in fly ash. Low-boiling-point heavy metals, such as lead and zinc, are distributed in fly ash at rates of 95.2% and 92.0%, respectively. Most of high-boiling-point heavy metals, such as iron and copper, are distributed in metal. It is also clarified that slag is stable and contains few harmful heavy metals such as lead. Compared with the conventional waste management framework, 85% of the final landfill amount reduction is achieved by co-gasification of municipal solid waste with bottom ash and incombustible residues. These results indicate that the combined production of slag with co-gasification of municipal solid waste with the bottom ash constitutes an ideal approach to environmental conservation and resource recycling.

  8. Biomass gasification for gas turbine-based power generation

    SciTech Connect (OSTI)

    Paisley, M.A.; Anson, D.

    1998-04-01

    The Biomass Power Program of the US Department of Energy (DOE) has as a major goal the development of cost-competitive technologies for the production of power from renewable biomass crops. The gasification of biomass provides the potential to meet this goal by efficiently and economically producing a renewable source of a clean gaseous fuel suitable for use in high-efficiency gas turbines. This paper discusses the development and first commercial demonstration of the Battelle high-throughput gasification process for power generation systems. Projected process economics are presented along with a description of current experimental operations coupling a gas turbine power generation system to the research scale gasifier and the process scaleup activities in Burlington, Vermont.

  9. Methods and apparatus for catalytic hydrothermal gasification of biomass

    DOE Patents [OSTI]

    Elliott, Douglas C.; Butner, Robert Scott; Neuenschwander, Gary G.; Zacher, Alan H.; Hart, Todd R.

    2012-08-14

    Continuous processing of wet biomass feedstock by catalytic hydrothermal gasification must address catalyst fouling and poisoning. One solution can involve heating the wet biomass with a heating unit to a temperature sufficient for organic constituents in the feedstock to decompose, for precipitates of inorganic wastes to form, for preheating the wet feedstock in preparation for subsequent separation of sulfur contaminants, or combinations thereof. Treatment further includes separating the precipitates out of the wet feedstock, removing sulfur contaminants, or both using a solids separation unit and a sulfur separation unit, respectively. Having removed much of the inorganic wastes and the sulfur that can cause poisoning and fouling, the wet biomass feedstock can be exposed to the heterogeneous catalyst for gasification.

  10. NETL, USDA design coal-stabilized biomass gasification unit

    SciTech Connect (OSTI)

    2008-09-30

    Coal, poultry litter, contaminated corn, rice hulls, moldly hay, manure sludge - these are representative materials that could be tested as fuel feedstocks in a hybrid gasification/combustion concept studied in a recent US Department of Energy (DOE) design project. DOE's National Energy Technology Laboratory (NETL) and the US Department of Agriculture (USDA) collaborated to develop a design concept of a power system that incorporates Hybrid Biomass Gasification. This system would explore the use of a wide range of biomass and agricultural waste products as gasifier feedstocks. The plant, if built, would supply one-third of electrical and steam heating needs at the USDA's Beltsville (Maryland) Agricultural Research Center. 1 fig., 1 photo.

  11. Carter, L.D. 20 FOSSIL-FUELED POWER PLANTS; COAL GASIFICATION...

    Office of Scientific and Technical Information (OSTI)

    carbon capture, utilisation, and storage Carter, L.D. 20 FOSSIL-FUELED POWER PLANTS; COAL GASIFICATION; POWER GENERATION; CARBON DIOXIDE; CAPTURE; STORAGE; USA; ENHANCED...

  12. Hydrogen Production from Biomass via Indirect Gasification: The Impact of NREL Process Development Unit Gasifier Correlations

    SciTech Connect (OSTI)

    Kinchin, C. M.; Bain, R. L.

    2009-05-01

    This report describes a set of updated gasifier correlations developed by NREL to predict biomass gasification products and Minimum Hydrogen Selling Price.

  13. The Development of a Hydrothermal Method for Slurry Feedstock Preparation for Gasification Technology

    E-Print Network [OSTI]

    He, Wei

    2011-01-01

    biomass gasification/pyrolysis: An overview. Renewable andfor the Study of Biomass Pyrolysis Chemistry at High HeatingA. Ganesh, and K.C. Khilar, Pyrolysis characteristics of

  14. Characterizing a lignite formation before and after an underground coal gasification experiment 

    E-Print Network [OSTI]

    Ahmed, Usman

    1981-01-01

    ) . Grid Break Up System for the Areal Model Pressure Drawdown (Semi-log Plot) on Well 9 (Post-Gasification). 24 25 27 31 16 Ei-Function Plot. Drawdown on Well 9 and Inter- ference on Wells 10, 13 and 18 (Post-Gasification) . . 32 17 Pressure... Drawdown (Semi-log Plot) on Well 10 (Post-Gasification). 34 18 Ei-Function Plot. Drawdown on Well 10 and Inter- ference on Wells 9, 13 and 18 (Post-Gasification). . . 35 ~Fi ure 19 LIST OF FIGURES (Continued) Pressure Drawdown (Semi-log Plot) on Well...

  15. Market Assessment of Biomass Gasification and Combustion Technology for Small- and Medium-Scale Applications

    SciTech Connect (OSTI)

    Peterson, D.; Haase, S.

    2009-07-01

    This report provides a market assessment of gasification and direct combustion technologies that use wood and agricultural resources to generate heat, power, or combined heat and power (CHP) for small- to medium-scale applications. It contains a brief overview of wood and agricultural resources in the U.S.; a description and discussion of gasification and combustion conversion technologies that utilize solid biomass to generate heat, power, and CHP; an assessment of the commercial status of gasification and combustion technologies; a summary of gasification and combustion system economics; a discussion of the market potential for small- to medium-scale gasification and combustion systems; and an inventory of direct combustion system suppliers and gasification technology companies. The report indicates that while direct combustion and close-coupled gasification boiler systems used to generate heat, power, or CHP are commercially available from a number of manufacturers, two-stage gasification systems are largely in development, with a number of technologies currently in demonstration. The report also cites the need for a searchable, comprehensive database of operating combustion and gasification systems that generate heat, power, or CHP built in the U.S., as well as a national assessment of the market potential for the systems.

  16. Fluidized bed gasification ash reduction and removal system

    DOE Patents [OSTI]

    Schenone, Carl E. (Madison, PA); Rosinski, Joseph (Vanderbilt, PA)

    1984-02-28

    In a fluidized bed gasification system an ash removal system to reduce the particulate ash to a maximum size or smaller, allow the ash to cool to a temperature lower than the gasifier and remove the ash from the gasifier system. The system consists of a crusher, a container containing level probes and a means for controlling the rotational speed of the crusher based on the level of ash within the container.

  17. Fluidized bed gasification ash reduction and removal process

    DOE Patents [OSTI]

    Schenone, Carl E. (Madison, PA); Rosinski, Joseph (Vanderbilt, PA)

    1984-12-04

    In a fluidized bed gasification system an ash removal system to reduce the particulate ash to a maximum size or smaller, allow the ash to cool to a temperature lower than the gasifier and remove the ash from the gasifier system. The system consists of a crusher, a container containing level probes and a means for controlling the rotational speed of the crusher based on the level of ash within the container.

  18. Pressurized pyrolysis and gasification of Chinese typical coal samples

    SciTech Connect (OSTI)

    Hanping Chen; Zhiwu Luo; Haiping Yang; Fudong Ju; Shihong Zhang [Huazhong University of Science and Technology, Wuhan (China). State Key Laboratory of Coal Combustion

    2008-03-15

    This paper aims to understand the pyrolysis and gasification behavior of different Chinese coal samples at different pressures. First, the pyrolysis of four typical Chinese coals samples (Xiaolongtan brown coal, Shenfu bituminous coal, Pingzhai anthracite coal, and Heshan lean coal) were carried out using a pressurized thermogravimetric analyzer at ambient pressure and 3 MPa, respectively. The surface structure and elemental component of the resultant char were measured with an automated gas adsorption apparatus and element analyzer. It was observed that higher pressure suppressed the primary pyrolysis, while the secondary pyrolysis of coal particles was promoted. With respect to the resultant solid char, the carbon content increased while H content decreased; however, the pore structure varied greatly with increasing pressure for different coal samples. For Xiaolongtan brown coal (XLT) char, it decreased greatly, while it increased obviously for the other three char types. Then, the isothermal gasification behavior of solid char particles was investigated using an ambient thermal analyzer with CO{sub 2} as the gasifying agent at 1000{sup o}C. The gasification reactivity of solid char was decreased greatly with increasing pyrolysis pressure. However, the extent of change displayed a vital relation with the characteristics of the original coal sample. 26 refs., 5 figs., 5 tabs.

  19. Method for using fast fluidized bed dry bottom coal gasification

    DOE Patents [OSTI]

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

    1983-01-01

    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.

  20. Power Systems Development Facility Gasification Test Campaign TC17

    SciTech Connect (OSTI)

    Southern Company Services

    2004-11-30

    In support of technology development to utilize coal for efficient, affordable, and environmentally clean power generation, the Power Systems Development Facility (PSDF) located in Wilsonville, Alabama, routinely demonstrates gasification technologies using various types of coals. The PSDF is an engineering scale demonstration of key features of advanced coal-fired power systems, including a KBR (formerly Kellogg Brown & Root) Transport Gasifier, a hot gas particulate control device, advanced syngas cleanup systems, and high-pressure solids handling systems. This report summarizes the results gasification operation with Illinois Basin bituminous coal in PSDF test campaign TC17. The test campaign was completed from October 25, 2004, to November 18, 2004. System startup and initial operation was accomplished with Powder River Basin (PRB) subbituminous coal, and then the system was transitioned to Illinois Basin coal operation. The major objective for this test was to evaluate the PSDF gasification process operational stability and performance using the Illinois Basin coal. The Transport Gasifier train was operated for 92 hours using PRB coal and for 221 hours using Illinois Basin coal.

  1. Power Systems Development Facility Gasification Test Campaing TC18

    SciTech Connect (OSTI)

    Southern Company Services

    2005-08-31

    In support of technology development to utilize coal for efficient, affordable, and environmentally clean power generation, the Power Systems Development Facility (PSDF) located in Wilsonville, Alabama, routinely demonstrates gasification technologies using various types of coals. The PSDF is an engineering scale demonstration of key features of advanced coal-fired power systems, including a KBR Transport Gasifier, a hot gas particulate control device (PCD), advanced syngas cleanup systems, and high pressure solids handling systems. This report details Test Campaign TC18 of the PSDF gasification process. Test campaign TC18 began on June 23, 2005, and ended on August 22, 2005, with the gasifier train accumulating 1,342 hours of operation using Powder River Basin (PRB) subbituminous coal. Some of the testing conducted included commissioning of a new recycle syngas compressor for gasifier aeration, evaluation of PCD filter elements and failsafes, testing of gas cleanup technologies, and further evaluation of solids handling equipment. At the conclusion of TC18, the PSDF gasification process had been operated for more than 7,750 hours.

  2. UTILIZATION OF LIGHTWEIGHT MATERIALS MADE FROM COAL GASIFICATION SLAGS

    SciTech Connect (OSTI)

    Vas Choudhry; Stephen Kwan; Steven R. Hadley

    2001-07-01

    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.

  3. Carbon-catalyzed gasification of organic feedstocks in supercritical water

    SciTech Connect (OSTI)

    Xu, X.; Matsumura, Y.; Stenberg, J.; Antal, M.J. Jr. [Univ. of Hawaii, Honolulu, HI (United States). Hawaii Natural Energy Inst.] [Univ. of Hawaii, Honolulu, HI (United States). Hawaii Natural Energy Inst.

    1996-08-01

    Spruce wood charcoal, macadamia shell charcoal, coal activated carbon, and coconut shell activated carbon catalyze the gasification of organic compounds in supercritical water. Feedstocks studied in this paper include glycerol, glucose, cellobiose, whole biomass feedstocks (depithed bagasse liquid extract and sewage sludge), and representative Department of Defense (DoD) wastes (methanol, methyl ethyl ketone, ethylene glycol, acetic acid, and phenol). The effects of temperature, pressure, reactant concentration, weight hourly space velocity, and the type of catalyst on the gasification of glucose are reported. Complete conversion of glucose (22% by weight in water) to a hydrogen-rich synthesis gas was realized at a weight hourly space velocity (WHSV) of 22.2 h{sup {minus}1} in supercritical water at 600 C, 34.5 MPa. Complete conversions of the whole biomass feeds were also achieved at the same temperature and pressure. The destruction efficiencies for the representative DoD wastes were also high. Deactivation of the carbon catalyst was observed after 4 h of operation without swirl in the entrance region of the reactor, but the carbon gasification efficiency remained near 100% for more than 6 h when a swirl generator was employed in the entrance of the reactor.

  4. Study of JET Soft Housekeeping Waste Volume Reduction by Plasma Arc Centrifuge and Gasification in Countercurrent Regime Methods

    E-Print Network [OSTI]

    Study of JET Soft Housekeeping Waste Volume Reduction by Plasma Arc Centrifuge and Gasification in Countercurrent Regime Methods

  5. Development of an advanced, continuous mild gasification process for the production of co-products: Topical report

    SciTech Connect (OSTI)

    Cha, C.Y.; Merriam, N.W.; Jha, M.C.; Breault, R.W.

    1988-06-01

    Research on mild gasification is discussed. The report is divided into three sections: literature survey of mild gasification processes; literature survey of char, condensibles, and gas upgrading and utilization methods; and industrial market assessment of products of mild gasification. Recommendations are included in each section. (CBS) 248 refs., 58 figs., 62 tabs.

  6. Coal gasification. Quarterly report, January-March 1979. [US DOE supported

    SciTech Connect (OSTI)

    None

    1980-01-01

    Progress in DOE-supported coal gasification pilot plant projects is reported: company, location, contract number, funding, process description, history and progress in the current quarter. Two support projects are discussed: preparation of a technical data book and mathematical modeling of gasification reactors. (LTN)

  7. Damage monitoring of refractory wall in a generic entrained-bed slagging gasification system

    E-Print Network [OSTI]

    Ray, Asok

    INTRODUCTION Modern day gasification plants offer a versatile and clean way to convert coal and other that gasification will be a major source of clean-fuel technology (e.g. US Department of Energy's Future- Gen.Forexample,a carbon-based feedstock (e.g. coal) is typically exposed to hot steam and carefully controlled amounts

  8. Techno-economic analysis of wastewater sludge gasification: A decentralized urban perspective

    E-Print Network [OSTI]

    : Gasification Techno-economic analysis Sewage sludge Thermochemical conversion Renewable energy a b s t r a c or high energy costs. A new approach considers converting sludge to fuel which can be used to produce to energy. Thermal systems analysis of air-blown and steam gasification of waste water sludge. Techno

  9. Instrumentation and Evaluation of a Pilot Scale Fluidized Bed Biomass Gasification System 

    E-Print Network [OSTI]

    Maglinao, Amado L

    2009-12-04

    DAQ. ...................................................... 11 Table 2 Bulk density and loading factor ........................................................ 18 Table 3 Sample gasification data readings ..................................................... 22 Table 4 Properties of the three... BED BIOMASS GASIFICATION SYSTEM OVERVIEW The conversion of biomass into energy (also called bioenergy) encompasses wide range of different types and sources of biomass, conversion options and end-use applications. These can be done through either...

  10. Computational fluid dynamics modeling of coal gasification in a pressurized spout-fluid bed

    SciTech Connect (OSTI)

    Zhongyi Deng; Rui Xiao; Baosheng Jin; He Huang; Laihong Shen; Qilei Song; Qianjun Li [Southeast University, Nanjing (China). Key Laboratory of Clean Coal Power Generation and Combustion Technology of Ministry of Education

    2008-05-15

    Computational fluid dynamics (CFD) modeling, which has recently proven to be an effective means of analysis and optimization of energy-conversion processes, has been extended to coal gasification in this paper. A 3D mathematical model has been developed to simulate the coal gasification process in a pressurized spout-fluid bed. This CFD model is composed of gas-solid hydrodynamics, coal pyrolysis, char gasification, and gas phase reaction submodels. The rates of heterogeneous reactions are determined by combining Arrhenius rate and diffusion rate. The homogeneous reactions of gas phase can be treated as secondary reactions. A comparison of the calculated and experimental data shows that most gasification performance parameters can be predicted accurately. This good agreement indicates that CFD modeling can be used for complex fluidized beds coal gasification processes. 37 refs., 7 figs., 5 tabs.

  11. Comparison of Preanode and Postanode Carbon Dioxide Separation for IGFC Systems

    SciTech Connect (OSTI)

    Eric Liese

    2010-01-01

    This paper examines the arrangement of a solid oxide fuel cell (SOFC) within a coal gasification cycle, this combination generally being called an integrated gasification fuel cell cycle. This work relies on a previous study performed by the National Energy Technology Laboratory (NETL) that details thermodynamic simulations of integrated gasification combined cycle (IGCC) systems and considers various gasifier types and includes cases for 90% CO2 capture (2007, “Cost and Performance Baseline for Fossil Energy Plants, Vol. 1: Bituminous Coal and Natural Gas to Electricity,” National Energy Technology Laboratory Report No. DOE/NETL-2007/1281). All systems in this study assume a Conoco Philips gasifier and cold-gas clean up conditions for the coal gasification system (Cases 3 and 4 in the NETL IGCC report). Four system arrangements, cases, are examined. Cases 1 and 2 remove the CO2 after the SOFC anode. Case 3 assumes steam addition, a water-gas-shift (WGS) catalyst, and a Selexol process to remove the CO2 in the gas cleanup section, sending a hydrogen-rich gas to the fuel cell anode. Case 4 assumes Selexol in the cold-gas cleanup section as in Case 3; however, there is no steam addition, and the WGS takes places in the SOFC and after the anode. Results demonstrate significant efficiency advantages compared with IGCC with CO2 capture. The hydrogen-rich case (Case 3) has better net electric efficiency compared with typical postanode CO2 capture cases (Cases 1 and 2), with a simpler arrangement but at a lower SOFC power density, or a lower efficiency at the same power density. Case 4 gives an efficiency similar to Case 3 but also at a lower SOFC power density. Carbon deposition concerns are also discussed

  12. Advancement of High Temperature Black Liquor Gasification Technology

    SciTech Connect (OSTI)

    Craig Brown; Ingvar Landalv; Ragnar Stare; Jerry Yuan; Nikolai DeMartini; Nasser Ashgriz

    2008-03-31

    Weyerhaeuser operates the world's only commercial high-temperature black liquor gasifier at its pulp mill in New Bern, NC. The unit was started-up in December 1996 and currently processes about 15% of the mill's black liquor. Weyerhaeuser, Chemrec AB (the gasifier technology developer), and the U.S. Department of Energy recognized that the long-term, continuous operation of the New Bern gasifier offered a unique opportunity to advance the state of high temperature black liquor gasification toward the commercial-scale pressurized O2-blown gasification technology needed as a foundation for the Forest Products Bio-Refinery of the future. Weyerhaeuser along with its subcontracting partners submitted a proposal in response to the 2004 joint USDOE and USDA solicitation - 'Biomass Research and Development Initiative'. The Weyerhaeuser project 'Advancement of High Temperature Black Liquor Gasification' was awarded USDOE Cooperative Agreement DE-FC26-04NT42259 in November 2004. The overall goal of the DOE sponsored project was to utilize the Chemrec{trademark} black liquor gasification facility at New Bern as a test bed for advancing the development status of molten phase black liquor gasification. In particular, project tasks were directed at improvements to process performance and reliability. The effort featured the development and validation of advanced CFD modeling tools and the application of these tools to direct burner technology modifications. The project also focused on gaining a fundamental understanding and developing practical solutions to address condensate and green liquor scaling issues, and process integration issues related to gasifier dregs and product gas scrubbing. The Project was conducted in two phases with a review point between the phases. Weyerhaeuser pulled together a team of collaborators to undertake these tasks. Chemrec AB, the technology supplier, was intimately involved in most tasks, and focused primarily on the design, specification and procurement of facility upgrades. Chemrec AB is also operating a pressurized, O2-blown gasifier pilot facility in Piteaa, Sweden. There was an exchange of knowledge with the pressurized projects including utilization of the experimental results from facilities in Piteaa, Sweden. Resources at the Georgia Tech Research Corporation (GTRC, a.k.a., the Institute of Paper Science and Technology) were employed primarily to conduct the fundamental investigations on scaling and plugging mechanisms and characterization of green liquor dregs. The project also tapped GTRC expertise in the development of the critical underlying black liquor gasification rate subroutines employed in the CFD code. The actual CFD code development and application was undertaken by Process Simulation, Ltd (PSL) and Simulent, Ltd. PSL focused on the overall integrated gasifier CFD code, while Simulent focused on modeling the black liquor nozzle and description of the black liquor spray. For nozzle development and testing Chemrec collaborated with ETC (Energy Technology Centre) in Piteae utilizing their test facility for nozzle spray investigation. GTI (Gas Technology Institute), Des Plains, IL supported the team with advanced gas analysis equipment during the gasifier test period in June 2005.

  13. FUEL CELL/MICRO-TURBINE COMBINED CYCLE

    SciTech Connect (OSTI)

    Larry J. Chaney; Mike R. Tharp; Tom W. Wolf; Tim A. Fuller; Joe J. Hartvigson

    1999-12-01

    A wide variety of conceptual design studies have been conducted that describe ultra-high efficiency fossil power plant cycles. The most promising of these ultra-high efficiency cycles incorporate high temperature fuel cells with a gas turbine. Combining fuel cells with a gas turbine increases overall cycle efficiency while reducing per kilowatt emissions. This study has demonstrated that the unique approach taken to combining a fuel cell and gas turbine has both technical and economic merit. The approach used in this study eliminates most of the gas turbine integration problems associated with hybrid fuel cell turbine systems. By using a micro-turbine, and a non-pressurized fuel cell the total system size (kW) and complexity has been reduced substantially from those presented in other studies, while maintaining over 70% efficiency. The reduced system size can be particularly attractive in the deregulated electrical generation/distribution environment where the market may not demand multi-megawatt central stations systems. The small size also opens up the niche markets to this high efficiency, low emission electrical generation option.

  14. Fossil fuel combined cycle power generation method

    DOE Patents [OSTI]

    Labinov, Solomon D [Knoxville, TN; Armstrong, Timothy R [Clinton, TN; Judkins, Roddie R [Knoxville, TN

    2008-10-21

    A method for converting fuel energy to electricity includes the steps of converting a higher molecular weight gas into at least one mixed gas stream of lower average molecular weight including at least a first lower molecular weight gas and a second gas, the first and second gases being different gases, wherein the first lower molecular weight gas comprises H.sub.2 and the second gas comprises CO. The mixed gas is supplied to at least one turbine to produce electricity. The mixed gas stream is divided after the turbine into a first gas stream mainly comprising H.sub.2 and a second gas stream mainly comprising CO. The first and second gas streams are then electrochemically oxidized in separate fuel cells to produce electricity. A nuclear reactor can be used to supply at least a portion of the heat the required for the chemical conversion process.

  15. Fossil fuel combined cycle power system

    DOE Patents [OSTI]

    Labinov, Solomon Davidovich; Armstrong, Timothy Robert; Judkins, Roddie Reagan

    2006-10-10

    A system for converting fuel energy to electricity includes a reformer for converting a higher molecular weight gas into at least one lower molecular weight gas, at least one turbine to produce electricity from expansion of at least one of the lower molecular weight gases, and at least one fuel cell. The system can further include at least one separation device for substantially dividing the lower molecular weight gases into at least two gas streams prior to the electrochemical oxidization step. A nuclear reactor can be used to supply at least a portion of the heat the required for the chemical conversion process.

  16. Generating Resources Combined Cycle Combustion Turbine

    E-Print Network [OSTI]

    diverse sources and robust gas infrastructure. 3. Cost and Uncertainty Stable capital cost estimate capital costs, but costs have been declining rapidly, requiring a forecast of future cost declines (MW) Normalized overnight capital cost ($/kW) O&M costs fixed ($/kW-yr) and variable ($/MWh

  17. Wood Burning Combined Cycle Power Plant 

    E-Print Network [OSTI]

    Culley, J. W.; Bourgeois, H. S.

    1984-01-01

    of the major components of the power plant. The cycle configuration is based on maximum fuel efficiency with minimum capital equipment risk. The cycle discussion includes design point performance of the power plant. The design represents a significant step...

  18. Coal gasification. Quarterly report, April-June 1979

    SciTech Connect (OSTI)

    None

    1980-04-01

    In DOE's program for the conversion of coal to gaseous fuels both high-and low-Btu gasification processes are being developed. High-Btu gas can be distributed economically to consumers in the same pipeline systems now used to carry natural gas. Low-Btu gas, the cheapest of the gaseous fuels produced from coal, can be used economically only on site, either for electric power generation or by industrial and petrochemical plants. High-Btu natural gas has a heating value of 950 to 1000 Btu per standard cubic foot, is composed essentially of methane, and contains virtually no sulfur, carbon monoxide, or free hydrogen. The conversion of coal to High-Btu gas requires a chemical and physical transformation of solid coal. Coals have widely differing chemical and physical properties, depending on where they are mined, and are difficult to process. Therefore, to develop the most suitable techniques for gasifying coal, DOE, together with the American Gas Association (AGA), is sponsoring the development of several advanced conversion processes. Although the basic coal-gasification chemical reactions are the same for each process, each of the processes under development have unique characteristics. A number of the processes for converting coal to high-Btu gas have reached the pilot plant Low-Btu gas, with a heating value of up to 350 Btu per standard cubic foot, is an economical fuel for industrial use as well as for power generation in combined gas-steam turbine power cycles. Because different low-Btu gasification processes are optimum for converting different types of coal, and because of the need to provide commercially acceptable processes at the earliest possible date, DOE is sponsoring the concurrent development of several basic types of gasifiers (fixed-bed, fluidized-bed, and entrained-flow).

  19. Black liquor gasification phase 2D final report

    SciTech Connect (OSTI)

    Kohl, A.L.; Stewart, A.E.

    1988-06-01

    This report covers work conducted by Rockwell International under Amendment 5 to Subcontract STR/DOE-12 of Cooperative Agreement DE-AC-05-80CS40341 between St. Regis Corporation (now Champion International) and the Department of Energy (DOE). The work has been designated Phase 2D of the overall program to differentiate it from prior work under the same subcontract. The overall program is aimed at demonstrating the feasibility of and providing design data for the Rockwell process for gasifying Kraft black liquor. In this process, concentrated black liquor is converted into low-Btu fuel gas and reduced melt by reaction with air in a specially designed gasification reactor.

  20. Mississippi Ethanol Gasification Project, Final Scientific / Technical Report

    SciTech Connect (OSTI)

    Pearson, Larry, E.

    2007-04-30

    The Mississippi Ethanol (ME) Project is a comprehensive effort to develop the conversion of biomass to ethanol utilizing a proprietary gasification reactor technology developed by Mississippi Ethanol, LLC. Tasks were split between operation of a 1/10 scale unit at the Diagnostic Instrumentation and Analysis Laboratory (DIAL) of Mississippi State University (MSU) and the construction, development, and operation of a full scale pilot unit located at the ME facility in Winona, Mississippi. In addition to characterization of the ME reactor gasification system, other areas considered critical to the operational and economic viability of the overall ME concept were evaluated. These areas include syngas cleanup, biological conversion of syngas to alcohol, and effects of gasification scale factors. Characterization of run data from the Pre-Pilot and Pilot Units has allowed development of the factors necessary for scale-up from the small unit to the larger unit. This scale range is approximately a factor of 10. Particulate and tar sampling gave order of magnitude values for preliminary design calculations. In addition, sampling values collected downstream of the ash removal system show significant reductions in observed loadings. These loading values indicate that acceptable particulate and tar loading rates could be attained with standard equipment additions to the existing configurations. Overall operation both the Pre-Pilot and Pilot Units proceeded very well. The Pilot Unit was operated as a system, from wood receiving to gas flaring, several times and these runs were used to address possible production-scale concerns. Among these, a pressure feed system was developed to allow feed of material against gasifier system pressure with little or no purge requirements. Similarly, a water wash system, with continuous ash collection, was developed, installed, and tested. Development of a biological system for alcohol production was conducted at Mississippi State University with much progress. However, the current state of biological technology is not deemed to be ready commercially. A preliminary estimate of capital and operating costs of a 12000 gallon per day gasification/biological facility was developed for comparison purposes. In addition, during the biological organism screening and testing, some possible alternative products were identified. One such possibility is the biological production of bio-diesel. Additional research is necessary for further evaluation of all of the biological concepts.

  1. Small Business Research | Department of Energy

    Energy Savers [EERE]

    Resources (Oil Shale, Methane Hydrates, etc.) Gasification (IGCC, Coal and Biomass) Algae to Fuels Solid Oxide Fuel Cells Turbines Sensors and Controls for Coal-Fired Power...

  2. NETL F 451.1/1-1, Categorical Exclusion Designation Form

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

    Skies Consulting - Charlotte, NC FESCCAESD Darryl Shockley Chem. Looping Coal Gasification Sub-Pilot Unit Demo & Econ Assessment for IGCC Complete detailed design, construct...

  3. vision clean power | netl.doe.gov

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

    the left of this page. 1. Important products using CO2 as feedstock include urea and methanol Power Commercial Power Production based on Gasification Typical IGCC Configuration...

  4. Pyrolysis and gasification of coal at high temperatures

    SciTech Connect (OSTI)

    Zygourakis, K.

    1988-01-01

    Coals of different ranks will be pyrolyzed in a microscope hot-stage reactor using inert and reacting atmospheres. The macropore structure of the produced chars will be characterized using video microscopy and digital image processing techniques to obtain pore size distributions. Comparative studies will quantify the effect of pyrolysis conditions (heating rates, final heat treatment temperatures, particle size and inert or reacting atmosphere) on the pore structure of the devolatilized chars. The devolatilized chars will be gasified in the regime of strong intraparticle diffusional limitations using O{sub 2}/N{sub 2} and O{sub 2}/H{sub 2}O/N{sub 2}2 mixtures. Constant temperature and programmed-temperature experiments in a TGA will be used for these studies. Additional gasification experiments performed in the hot-stage reactor will be videotaped and selected images will be analyzed to obtain quantitative data on particle shrinkage and fragmentation. Discrete mathematical models will be developed and validated using the experimental gasification data.

  5. Power Systems Development Facility Gasification Test Campaign TC21

    SciTech Connect (OSTI)

    Southern Company Services

    2007-01-30

    In support of technology development to utilize coal for efficient, affordable, and environmentally clean power generation, the Power Systems Development Facility (PSDF), located in Wilsonville, Alabama, routinely demonstrates gasification technologies using various types of coal. The PSDF is an engineering scale demonstration of key features of advanced coal-fired power systems, including a Transport Gasifier, a hot gas particulate control device (PCD), advanced syngas cleanup systems, and high-pressure solids handling systems. This report summarizes the results of the first demonstration of gasification operation with lignite coal following the 2006 gasifier configuration modifications. This demonstration took place during test campaign TC21, occurring from November 7, 2006, through January 26, 2007. The test campaign began with low sodium lignite fuel, and after 304 hours of operation, the fuel was changed to high sodium lignite, for 34 additional hours of operation. Both fuels were from the North Dakota Freedom mine. Stable operation with low sodium lignite was maintained for extended periods, although operation with high sodium lignite was problematic due to agglomeration formation in the gasifier restricting solids circulation.

  6. Modeling and comparative assessment of municipal solid waste gasification for energy production

    SciTech Connect (OSTI)

    Arafat, Hassan A. Jijakli, Kenan

    2013-08-15

    Highlights: • Study developed a methodology for the evaluation of gasification for MSW treatment. • Study was conducted comparatively for USA, UAE, and Thailand. • Study applies a thermodynamic model (Gibbs free energy minimization) using the Gasify software. • The energy efficiency of the process and the compatibility with different waste streams was studied. - Abstract: Gasification is the thermochemical conversion of organic feedstocks mainly into combustible syngas (CO and H{sub 2}) along with other constituents. It has been widely used to convert coal into gaseous energy carriers but only has been recently looked at as a process for producing energy from biomass. This study explores the potential of gasification for energy production and treatment of municipal solid waste (MSW). It relies on adapting the theory governing the chemistry and kinetics of the gasification process to the use of MSW as a feedstock to the process. It also relies on an equilibrium kinetics and thermodynamics solver tool (Gasify®) in the process of modeling gasification of MSW. The effect of process temperature variation on gasifying MSW was explored and the results were compared to incineration as an alternative to gasification of MSW. Also, the assessment was performed comparatively for gasification of MSW in the United Arab Emirates, USA, and Thailand, presenting a spectrum of socioeconomic settings with varying MSW compositions in order to explore the effect of MSW composition variance on the products of gasification. All in all, this study provides an insight into the potential of gasification for the treatment of MSW and as a waste to energy alternative to incineration.

  7. Biomass waste gasification - Can be the two stage process suitable for tar reduction and power generation?

    SciTech Connect (OSTI)

    Sulc, Jindrich; Stojdl, Jiri; Richter, Miroslav; Popelka, Jan [Faculty of the Environment, Jan Evangelista Purkyne University in Usti nad Labem, Kralova Vysina 7, 400 96 Usti nad Labem (Czech Republic); Svoboda, Karel, E-mail: svoboda@icpf.cas.cz [Faculty of the Environment, Jan Evangelista Purkyne University in Usti nad Labem, Kralova Vysina 7, 400 96 Usti nad Labem (Czech Republic); Institute of Chemical Process Fundamentals of the ASCR, v.v.i., Rozvojova 135, 165 02 Prague 6 (Czech Republic); Smetana, Jiri; Vacek, Jiri [D.S.K. Ltd., Ujezdecek - Dukla 264, 415 01 Teplice I (Czech Republic); Skoblja, Siarhei; Buryan, Petr [Dept. of Gas, Coke and Air protection, Institute of Chemical Technol., Technicka 5, 166 28 Prague 6 (Czech Republic)

    2012-04-15

    Highlights: Black-Right-Pointing-Pointer Comparison of one stage (co-current) and two stage gasification of wood pellets. Black-Right-Pointing-Pointer Original arrangement with grate-less reactor and upward moving bed of the pellets. Black-Right-Pointing-Pointer Two stage gasification leads to drastic reduction of tar content in gas. Black-Right-Pointing-Pointer One stage gasification produces gas with higher LHV at lower overall ER. Black-Right-Pointing-Pointer Content of ammonia in gas is lower in two stage moving bed gasification. - Abstract: A pilot scale gasification unit with novel co-current, updraft arrangement in the first stage and counter-current downdraft in the second stage was developed and exploited for studying effects of two stage gasification in comparison with one stage gasification of biomass (wood pellets) on fuel gas composition and attainable gas purity. Significant producer gas parameters (gas composition, heating value, content of tar compounds, content of inorganic gas impurities) were compared for the two stage and the one stage method of the gasification arrangement with only the upward moving bed (co-current updraft). The main novel features of the gasifier conception include grate-less reactor, upward moving bed of biomass particles (e.g. pellets) by means of a screw elevator with changeable rotational speed and gradual expanding diameter of the cylindrical reactor in the part above the upper end of the screw. The gasifier concept and arrangement are considered convenient for thermal power range 100-350 kW{sub th}. The second stage of the gasifier served mainly for tar compounds destruction/reforming by increased temperature (around 950 Degree-Sign C) and for gasification reaction of the fuel gas with char. The second stage used additional combustion of the fuel gas by preheated secondary air for attaining higher temperature and faster gasification of the remaining char from the first stage. The measurements of gas composition and tar compound contents confirmed superiority of the two stage gasification system, drastic decrease of aromatic compounds with two and higher number of benzene rings by 1-2 orders. On the other hand the two stage gasification (with overall ER = 0.71) led to substantial reduction of gas heating value (LHV = 3.15 MJ/Nm{sup 3}), elevation of gas volume and increase of nitrogen content in fuel gas. The increased temperature (>950 Degree-Sign C) at the entrance to the char bed caused also substantial decrease of ammonia content in fuel gas. The char with higher content of ash leaving the second stage presented only few mass% of the inlet biomass stream.

  8. Synthesis Gas Production by Rapid Solar Thermal Gasification of Corn Stover

    SciTech Connect (OSTI)

    Perkins, C. M.; Woodruff, B.; Andrews, L.; Lichty, P.; Lancaster, B.; Weimer, A. W.; Bingham, C.

    2008-03-01

    Biomass resources hold great promise as renewable fuel sources for the future, and there exists great interest in thermochemical methods of converting these resources into useful fuels. The novel approach taken by the authors uses concentrated solar energy to efficiently achieve temperatures where conversion and selectivity of gasification are high. Use of solar energy removes the need for a combustion fuel and upgrades the heating value of the biomass products. The syngas product of the gasification can be transformed into a variety of fuels useable with today?s infrastructure. Gasification in an aerosol reactor allows for rapid kinetics, allowing efficient utilization of the incident solar radiation and high solar efficiency.

  9. Integration of stripping of fines slurry in a coking and gasification process

    DOE Patents [OSTI]

    DeGeorge, Charles W. (Chester, NJ)

    1980-01-01

    In an integrated fluid coking and gasification process wherein a stream of fluidized solids is passed from a fluidized bed coking zone to a second fluidized bed and wherein entrained solid fines are recovered by a wet scrubbing process and wherein the resulting solids-liquid slurry is stripped to remove acidic gases, the stripped vapors of the stripping zone are sent to the gas cleanup stage of the gasification product gas. The improved stripping integration is particularly useful in the combination coal liquefaction process, fluid coking of bottoms of the coal liquefaction zone and gasification of the product coke.

  10. Status of health and environmental research relative to coal gasification 1976 to the present

    SciTech Connect (OSTI)

    Wilzbach, K.E.; Reilly, C.A. Jr.

    1982-10-01

    Health and environmental research relative to coal gasification conducted by Argonne National Laboratory, the Inhalation Toxicology Research Institute, and Oak Ridge National Laboratory under DOE sponsorship is summarized. The studies have focused on the chemical and toxicological characterization of materials from a range of process streams in five bench-scale, pilot-plant and industrial gasifiers. They also address ecological effects, industrial hygiene, environmental control technology performance, and risk assessment. Following an overview of coal gasification technology and related environmental concerns, integrated summaries of the studies and results in each area are presented and conclusions are drawn. Needed health and environmental research relative to coal gasification is identified.

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

    DOE Patents [OSTI]

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

    1981-09-14

    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.

  12. Method and system for controlling a gasification or partial oxidation process

    DOE Patents [OSTI]

    Rozelle, Peter L; Der, Victor K

    2015-02-10

    A method and system for controlling a fuel gasification system includes optimizing a conversion of solid components in the fuel to gaseous fuel components, controlling the flux of solids entrained in the product gas through equipment downstream of the gasifier, and maximizing the overall efficiencies of processes utilizing gasification. A combination of models, when utilized together, can be integrated with existing plant control systems and operating procedures and employed to develop new control systems and operating procedures. Such an approach is further applicable to gasification systems that utilize both dry feed and slurry feed.

  13. The ENCOAL Mild Coal Gasification Project, A DOE Assessment

    SciTech Connect (OSTI)

    National Energy Technology Laboratory

    2002-03-15

    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.

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

    Broader source: Energy.gov [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.

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

    SciTech Connect (OSTI)

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

    2009-07-01

    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.

  16. Development of a Segregated Municipal Solid Waste Gasification System for Electrical Power Generation 

    E-Print Network [OSTI]

    Maglinao, Amado Latayan

    2013-04-11

    Gasification technologies are expected to play a key role in the future of solid waste management since the conversion of municipal and industrial solid wastes to a gaseous fuel significantly increases its value. Municipal solid waste (MSW...

  17. Applied research and evaluation of process concepts for liquefaction and gasification of western coals. Final report

    SciTech Connect (OSTI)

    Wiser, W. H.

    1980-09-01

    Fourteen sections, including five subsections, of the final report covering work done between June 1, 1975 to July 31, 1980 on research programs in coal gasification and liquefaction have been entered individually into EDB and ERA. (LTN)

  18. Integrated Process Configuration for High-Temperature Sulfur Mitigation during Biomass Conversion via Indirect Gasification

    SciTech Connect (OSTI)

    Dutta. A.; Cheah, S.; Bain, R.; Feik, C.; Magrini-Bair, K.; Phillips, S.

    2012-06-20

    Sulfur present in biomass often causes catalyst deactivation during downstream operations after gasification. Early removal of sulfur from the syngas stream post-gasification is possible via process rearrangements and can be beneficial for maintaining a low-sulfur environment for all downstream operations. High-temperature sulfur sorbents have superior performance and capacity under drier syngas conditions. The reconfigured process discussed in this paper is comprised of indirect biomass gasification using dry recycled gas from downstream operations, which produces a drier syngas stream and, consequently, more-efficient sulfur removal at high temperatures using regenerable sorbents. A combination of experimental results from NREL's fluidizable Ni-based reforming catalyst, fluidizable Mn-based sulfur sorbent, and process modeling information show that using a coupled process of dry gasification with high-temperature sulfur removal can improve the performance of Ni-based reforming catalysts significantly.

  19. Biomass characterization and reduced order modeling of mixed-feedstock gasification

    E-Print Network [OSTI]

    Chapman, Alex J. (Alex Jacob)

    2011-01-01

    There has been much effort to characterize and model coal for use in combustion and gasification. This work seeks to delineate the differences and similarities between biomass and coal, with emphasis on the state of the ...

  20. Thermochemical Ethanol via Direct Gasification and Mixed Alcohol Synthesis of Lignocellulosic Biomass

    SciTech Connect (OSTI)

    Dutta, A.; Phillips, S. D.

    2009-07-01

    This report evaluates process design and technoeconomic criteria for a direct gasification process for conversion of biomass to ethanol. Follow-up to NREL/TP-510-41168.

  1. Proceedings of the ninth annual underground coal gasification symposium

    SciTech Connect (OSTI)

    Wieber, P.R.; Martin, J.W.; Byrer, C.W.

    1983-12-01

    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.

  2. Method for gasification of deep, thin coal seams

    DOE Patents [OSTI]

    Gregg, David W. (Moraga, CA)

    1982-01-01

    A method of gasification of coal in deep, thin seams by using controlled bending subsidence to confine gas flow to a region close to the unconsumed coal face. The injection point is moved sequentially around the perimeter of a coal removal area from a production well to sweep out the area to cause the controlled bending subsidence. The injection holes are drilled vertically into the coal seam through the overburden or horizontally into the seam from an exposed coal face. The method is particularly applicable to deep, thin seams found in the eastern United States and at abandoned strip mines where thin seams were surface mined into a hillside or down a modest dip until the overburden became too thick for further mining.

  3. Method for gasification of deep, thin coal seams. [DOE patent

    DOE Patents [OSTI]

    Gregg, D.W.

    1980-08-29

    A method of gasification of coal in deep, thin seams by using controlled bending subsidence to confine gas flow to a region close to the unconsumed coal face is given. The injection point is moved sequentially around the perimeter of a coal removal area from a production well to sweep out the area to cause the controlled bending subsidence. The injection holes are drilled vertically into the coal seam through the overburden or horizontally into the seam from an exposed coal face. The method is particularly applicable to deep, thin seams found in the eastern United States and at abandoned strip mines where thin seams were surface mined into a hillside or down a modest dip until the overburden became too thick for further mining.

  4. Baseload coal investment decisions under uncertain carbon legislation

    SciTech Connect (OSTI)

    Joule A. Bergerson; Lester B. Lave

    2007-05-15

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

  5. Effects of effluents of coal combustion and gasification upon lung structure and function. Annual report

    SciTech Connect (OSTI)

    Hinton, D.E.

    1980-01-01

    The overall objective of the proposed research is to correlate both structural and functional alterations in cells and tissues of the lung brought about by exposure to fluidized bed combustion and fixed bed gasification effluents and reagent grade oxides of metals known to be associated with coal combustion gasification. Projected milestones are described. Progress during the first year in setting up aerosol exposure facilities, intratracheal instillations, pulmonary mechanics, and morphometric examinations is reported. (DMC)

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

    SciTech Connect (OSTI)

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

    2011-10-15

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

  7. Technical analysis of advanced wastewater-treatment systems for coal-gasification plants

    SciTech Connect (OSTI)

    Not Available

    1981-03-31

    This analysis of advanced wastewater treatment systems for coal gasification plants highlights the three coal gasification demonstration plants proposed by the US Department of Energy: The Memphis Light, Gas and Water Division Industrial Fuel Gas Demonstration Plant, the Illinois Coal Gasification Group Pipeline Gas Demonstration Plant, and the CONOCO Pipeline Gas Demonstration Plant. Technical risks exist for coal gasification wastewater treatment systems, in general, and for the three DOE demonstration plants (as designed), in particular, because of key data gaps. The quantities and compositions of coal gasification wastewaters are not well known; the treatability of coal gasification wastewaters by various technologies has not been adequately studied; the dynamic interactions of sequential wastewater treatment processes and upstream wastewater sources has not been tested at demonstration scale. This report identifies key data gaps and recommends that demonstration-size and commercial-size plants be used for coal gasification wastewater treatment data base development. While certain advanced treatment technologies can benefit from additional bench-scale studies, bench-scale and pilot plant scale operations are not representative of commercial-size facility operation. It is recommended that coal gasification demonstration plants, and other commercial-size facilities that generate similar wastewaters, be used to test advanced wastewater treatment technologies during operation by using sidestreams or collected wastewater samples in addition to the plant's own primary treatment system. Advanced wastewater treatment processes are needed to degrade refractory organics and to concentrate and remove dissolved solids to allow for wastewater reuse. Further study of reverse osmosis, evaporation, electrodialysis, ozonation, activated carbon, and ultrafiltration should take place at bench-scale.

  8. Active sites in char gasification: Final technical report

    SciTech Connect (OSTI)

    Wojtowicz, M.; Lilly, W.D.; Perkins, M.T.; Hradil, G.; Calo, J.M.; Suuberg, E.M.

    1987-09-01

    Among the key variables in the design of gasifiers and combustors is the reactivity of the chars which must be gasified or combusted. Significant loss of unburned char is unacceptable in virtually any process; the provision of sufficient residence time for complete conversion is essential. A very wide range of reactivities are observed, depending upon the nature of the char in a process. The current work focuses on furthering the understanding of gasification reactivities of chars. It has been well established that the reactivity of char to gasification generally depends upon three principal factors: (1) the concentration of ''active sites'' in the char; (2) mass transfer within the char; and (3) the type and concentration of catalytic impurities in the char. The present study primarily addresses the first factor. The subject of this research is the origin, nature, and fate of active sites in chars derived from parent hydrocarbons with coal-like structure. The nature and number of the active sites and their reactivity towards oxygen are examined in ''model'' chars derived from phenol-formaldehyde type resins. How the active sites are lost by the process of thermal annealing during heat treatment of chars are studied, and actual rate for the annealing process is derived. Since intrinsic char reactivities are of primary interest in the present study, a fair amount of attention was given to the model char synthesis and handling so that the effect of catalytic impurities and oxygen-containing functional groups in the chemical structure of the material were minimized, if not completely eliminated. The project would not be considered complete without comparing characteristic features of synthetic chars with kinetic behavior exhibited by natural chars, including coal chars.

  9. Effect of steam partial pressure on gasification rate and gas composition of product gas from catalytic steam gasification of HyperCoal

    SciTech Connect (OSTI)

    Atul Sharma; Ikuo Saito; Toshimasa Takanohashi [National Institute of Advanced Industrial Science and Technology, Ibaraki (Japan). Advanced Fuel Group

    2009-09-15

    HyperCoal was produced from coal by a solvent extraction method. The effect of the partial pressure of steam on the gasification rate and gas composition at temperatures of 600, 650, 700, and 750{sup o}C was examined. The gasification rate decreased with decreasing steam partial pressure. The reaction order with respect to steam partial pressure was between 0.2 and 0.5. The activation energy for the K{sub 2}CO{sub 3}-catalyzed HyperCoal gasification was independent of the steam partial pressure and was about 108 kJ/mol. The gas composition changed with steam partial pressure and H{sub 2} and CO{sub 2} decreased and CO increased with decreasing steam partial pressure. By changing the partial pressure of the steam, the H{sub 2}/CO ratio of the synthesis gas can be controlled. 18 refs., 7 figs., 2 tabs.

  10. Gasification characteristics of an activated carbon catalyst during the decomposition of hazardous waste materials in supercritical water

    SciTech Connect (OSTI)

    Matsumura, Yukihiko; Nuessle, F.W.; Antal, M.J. Jr. [Univ. of Hawaii at Manoa, Honolulu, HI (United States)

    1996-10-01

    Recently, carbonaceous materials were proved to be effective catalysts for hazardous waste decomposition in supercritical water. Gasification of the carbonaceous catalyst itself is also expected, however, under supercritical conditions. Thus, it is essential to determine the gasification rate of the carbonaceous materials during this process to determine the active lifetime of the catalysts. For this purpose, the gasification characteristics of granular coconut shell activated carbon in supercritical water alone (600-650{degrees}C, 25.5-34.5 MPa) were investigated. The gasification rate at subatmospheric pressure agreed well with the gasification rate at supercritical conditions, indicating the same reaction mechanism. Methane generation under these conditions is via pyrolysis, and thus is not affected by the water pressure. An iodine number increase of 25% was observed as a result of the supercritical water gasification.

  11. Advanced Coal Wind Hybrid: Economic Analysis

    E-Print Network [OSTI]

    Phadke, Amol

    2008-01-01

    ACWH consists of a 3,000 MW coal gasification combined cycleconsists of a 3,000 MW coal gasification, combined cycleless expensive in a coal gasification, combined cycle power

  12. Advanced High-Temperature, High-Pressure Transport Reactor Gasification

    SciTech Connect (OSTI)

    Michael Swanson; Daniel Laudal

    2008-03-31

    The U.S. Department of Energy (DOE) National Energy Technology Laboratory Office of Coal and Environmental Systems has as its mission to develop advanced gasification-based technologies for affordable, efficient, zero-emission power generation. These advanced power systems, which are expected to produce near-zero pollutants, are an integral part of DOE's Vision 21 Program. DOE has also been developing advanced gasification systems that lower the capital and operating costs of producing syngas for chemical production. A transport reactor has shown potential to be a low-cost syngas producer compared to other gasification systems since its high-throughput-per-unit cross-sectional area reduces capital costs. This work directly supports the Power Systems Development Facility utilizing the KBR transport reactor located at the Southern Company Services Wilsonville, Alabama, site. Over 2800 hours of operation on 11 different coals ranging from bituminous to lignite along with a petroleum coke has been completed to date in the pilot-scale transport reactor development unit (TRDU) at the Energy & Environmental Research Center (EERC). The EERC has established an extensive database on the operation of these various fuels in both air-blown and oxygen-blown modes utilizing a pilot-scale transport reactor gasifier. This database has been useful in determining the effectiveness of design changes on an advanced transport reactor gasifier and for determining the performance of various feedstocks in a transport reactor. The effects of different fuel types on both gasifier performance and the operation of the hot-gas filter system have been determined. It has been demonstrated that corrected fuel gas heating values ranging from 90 to 130 Btu/scf have been achieved in air-blown mode, while heating values up to 230 Btu/scf on a dry basis have been achieved in oxygen-blown mode. Carbon conversions up to 95% have also been obtained and are highly dependent on the oxygen-coal ratio. Higher-reactivity (low-rank) coals appear to perform better in a transport reactor than the less reactive bituminous coals. Factors that affect TRDU product gas quality appear to be coal type, temperature, and air/coal ratios. Testing with a higher-ash, high-moisture, low-rank coal from the Red Hills Mine of the Mississippi Lignite Mining Company has recently been completed. Testing with the lignite coal generated a fuel gas with acceptable heating value and a high carbon conversion, although some drying of the high-moisture lignite was required before coal-feeding problems were resolved. No ash deposition or bed material agglomeration issues were encountered with this fuel. In order to better understand the coal devolatilization and cracking chemistry occurring in the riser of the transport reactor, gas and solid sampling directly from the riser and the filter outlet has been accomplished. This was done using a baseline Powder River Basin subbituminous coal from the Peabody Energy North Antelope Rochelle Mine near Gillette, Wyoming.

  13. Hydrogen production by high-temperature steam gasification of biomass and coal

    SciTech Connect (OSTI)

    Kriengsak, S.N.; Buczynski, R.; Gmurczyk, J.; Gupta, A.K. [University of Maryland, College Park, MD (United States). Dept. of Mechanical Engineering

    2009-04-15

    High-temperature steam gasification of paper, yellow pine woodchips, and Pittsburgh bituminous coal was investigated in a batch-type flow reactor at temperatures in the range of 700 to 1,200{sup o}C at two different ratios of steam to feedstock molar ratios. Hydrogen yield of 54.7% for paper, 60.2% for woodchips, and 57.8% for coal was achieved on a dry basis, with a steam flow rate of 6.3 g/min at steam temperature of 1,200{sup o}C. Yield of both the hydrogen and carbon monoxide increased while carbon dioxide and methane decreased with the increase in gasification temperature. A 10-fold reduction in tar residue was obtained at high-temperature steam gasification, compared to low temperatures. Steam and gasification temperature affects the composition of the syngas produced. Higher steam-to-feedstock molar ratio had negligible effect on the amount of hydrogen produced in the syngas in the fixed-batch type of reactor. Gasification temperature can be used to control the amounts of hydrogen or methane produced from the gasification process. This also provides mean to control the ratio of hydrogen to CO in the syngas, which can then be processed to produce liquid hydrocarbon fuel since the liquid fuel production requires an optimum ratio between hydrogen and CO. The syngas produced can be further processed to produce pure hydrogen. Biomass fuels are good source of renewable fuels to produce hydrogen or liquid fuels using controlled steam gasification.

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

    SciTech Connect (OSTI)

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

    2009-07-01

    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.

  15. Integrated Biomass Gasification with Catalytic Partial Oxidation for Selective Tar Conversion

    SciTech Connect (OSTI)

    Zhang, Lingzhi; Wei, Wei; Manke, Jeff; Vazquez, Arturo; Thompson, Jeff; Thompson, Mark

    2011-05-28

    Biomass gasification is a flexible and efficient way of utilizing widely available domestic renewable resources. Syngas from biomass has the potential for biofuels production, which will enhance energy security and environmental benefits. Additionally, with the successful development of low Btu fuel engines (e.g. GE Jenbacher engines), syngas from biomass can be efficiently used for power/heat co-generation. However, biomass gasification has not been widely commercialized because of a number of technical/economic issues related to gasifier design and syngas cleanup. Biomass gasification, due to its scale limitation, cannot afford to use pure oxygen as the gasification agent that used in coal gasification. Because, it uses air instead of oxygen, the biomass gasification temperature is much lower than well-understood coal gasification. The low temperature leads to a lot of tar formation and the tar can gum up the downstream equipment. Thus, the biomass gasification tar removal is a critical technology challenge for all types of biomass gasifiers. This USDA/DOE funded program (award number: DE-FG36-O8GO18085) aims to develop an advanced catalytic tar conversion system that can economically and efficiently convert tar into useful light gases (such as syngas) for downstream fuel synthesis or power generation. This program has been executed by GE Global Research in Irvine, CA, in collaboration with Professor Lanny Schmidt's group at the University of Minnesota (UoMn). Biomass gasification produces a raw syngas stream containing H2, CO, CO2, H2O, CH4 and other hydrocarbons, tars, char, and ash. Tars are defined as organic compounds that are condensable at room temperature and are assumed to be largely aromatic. Downstream units in biomass gasification such as gas engine, turbine or fuel synthesis reactors require stringent control in syngas quality, especially tar content to avoid plugging (gum) of downstream equipment. Tar- and ash-free syngas streams are a critical requirement for commercial deployment of biomass-based power/heat co-generation and biofuels production. There are several commonly used syngas clean-up technologies: (1) Syngas cooling and water scrubbing has been commercially proven but efficiency is low and it is only effective at small scales. This route is accompanied with troublesome wastewater treatment. (2) The tar filtration method requires frequent filter replacement and solid residue treatment, leading to high operation and capital costs. (3) Thermal destruction typically operates at temperatures higher than 1000oC. It has slow kinetics and potential soot formation issues. The system is expensive and materials are not reliable at high temperatures. (4) In-bed cracking catalysts show rapid deactivation, with durability to be demonstrated. (5) External catalytic cracking or steam reforming has low thermal efficiency and is faced with problematic catalyst coking. Under this program, catalytic partial oxidation (CPO) is being evaluated for syngas tar clean-up in biomass gasification. The CPO reaction is exothermic, implying that no external heat is needed and the system is of high thermal efficiency. CPO is capable of processing large gas volume, indicating a very compact catalyst bed and a low reactor cost. Instead of traditional physical removal of tar, the CPO concept converts tar into useful light gases (eg. CO, H2, CH4). This eliminates waste treatment and disposal requirements. All those advantages make the CPO catalytic tar conversion system a viable solution for biomass gasification downstream gas clean-up. This program was conducted from October 1 2008 to February 28 2011 and divided into five major tasks. - Task A: Perform conceptual design and conduct preliminary system and economic analysis (Q1 2009 ~ Q2 2009) - Task B: Biomass gasification tests, product characterization, and CPO tar conversion catalyst preparation. This task will be conducted after completing process design and system economics analysis. Major milestones include identification of syngas cleaning requirements for proposed system

  16. Low-temperature catalytic gasification of wet industrial wastes

    SciTech Connect (OSTI)

    Elliott, D C; Neuenschwander, G G; Baker, E G; Sealock, Jr, L J; Butner, R S

    1991-04-01

    Bench-scale reactor tests are in progress at Pacific Northwest Laboratory to develop a low-temperature, catalytic gasification system. The system, licensed under the trade name Thermochemical Environmental Energy System (TEES{reg sign}), is designed for treating a wide variety of feedstocks ranging from dilute organics in water to waste sludges from food processing. This report describes a test program which used a continuous-feed tubular reactor. This test program is an intermediate stage in the process development. The reactor is a laboratory-scale version of the commercial concept as currently envisioned by the process developers. An energy benefit and economic analysis was also completed on the process. Four conceptual commercial installations of the TEES process were evaluated for three food processing applications and one organic chemical manufacturing application. Net energy production (medium-Btu gas) was achieved in all four cases. The organic chemical application was found to be economically attractive in the present situation. Based on sensitivity studies included in the analysis, the three food processing cases will likely become attractive in the near future as waste disposal regulations tighten and disposal costs increase. 21 refs., 2 figs., 9 tabs.

  17. Two-stage coal gasification and desulfurization apparatus

    DOE Patents [OSTI]

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

    1991-01-01

    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.

  18. Effect of pulsation on black liquor gasification. Final report

    SciTech Connect (OSTI)

    Zinn, B.T.; Jagoda, J.; Jeong, H.; Kushari, A.; Rosen, L.J.

    1998-12-01

    Pyrolysis is an endothermic process. The heat of reaction is provided either by partial combustion of the waste or by heat transfer from an external combustion process. In one proposed system black liquor is pyrolized in a fluidized bed to which heat is added through a series of pulse combustor tail pipes submerged in the bed material. This system appears promising because of the relatively high heat transfer in pulse combustors and in fluidized beds. Other advantages of pulse combustors are discussed elsewhere. The process is, however, only economically viable if a part of the pyrolysis products can be used to fire the pulse combustors. The overall goals of this study were to determine: (1) which is the limiting heat transfer rate in the process of transferring heat from the hot combustion products to the pipe, through the pipe, from the tail pipe to the bed and through the bed; i.e., whether increased heat transfer within the pulse combustor will significantly increase the overall heat transfer rate; (2) whether the heat transfer benefits of the pulse combustor can be utilized while maintaining the temperature in the bed within the narrow temperature range required by the process without generating hot spots in the bed; and (3) whether the fuel gas produced during the gasification process can be used to efficiently fire the pulse combustor.

  19. Gasification Characteristics of Coal/Biomass Mixed Fuels

    SciTech Connect (OSTI)

    Mitchell, Reginald

    2013-09-30

    A research project was undertaken that had the overall objective of developing the models needed to accurately predict conversion rates of coal/biomass mixtures to synthesis gas under conditions relevant to a commercially-available coal gasification system configured to co- produce electric power as well as chemicals and liquid fuels. In our efforts to accomplish this goal, experiments were performed in an entrained flow reactor in order to produce coal and biomass chars at high heating rates and temperatures, typical of the heating rates and temperatures fuel particles experience in real systems. Mixed chars derived from coal/biomass mixtures containing up to 50% biomass and the chars of the pure coal and biomass components were subjected to a matrix of reactivity tests in a pressurized thermogravimetric analyzer (TGA) in order to obtain data on mass loss rates as functions of gas temperature, pressure and composition as well as to obtain information on the variations in mass specific surface area during char conversion under kinetically-limited conditions. The experimental data were used as targets when determining the unknown parameters in the chemical reactivity and specific surface area models developed. These parameters included rate coefficients for the reactions in the reaction mechanism, enthalpies of formation and absolute entropies of adsorbed species formed on the carbonaceous surfaces, and pore structure coefficients in the model used to describe how the mass specific surface area of the char varies with conversion. So that the reactivity models can be used at high temperatures when mass transport processes impact char conversion rates, Thiele modulus – effectiveness factor relations were also derived for the reaction mechanisms developed. In addition, the reactivity model and a mode of conversion model were combined in a char-particle gasification model that includes the effects of chemical reaction and diffusion of reactive gases through particle pores and energy exchange between the particle and its environment. This char-particle gasification model is capable of predicting the average mass loss rates, sizes, apparent densities, specific surface areas, and temperatures of the char particles produced when co-firing coal and biomass to the type environments established in entrained flow gasifiers operating at high temperatures and elevated pressures. A key result of this work is the finding that the reactivities of the mixed chars were not always in between the reactivities of the pure component chars at comparable gasification conditions. Mixed char reactivity to CO{sub 2} was lower than the reactivities of both the pure Wyodak coal and pure corn stover chars to CO{sub 2}. In contrast, mixed char reactivity to H{sub 2}O was higher than the reactivities of both the pure Wyodak coal and pure corn stover chars to H{sub 2}O. This was found to be in part, a consequence of the reduced mass specific surface areas of the coal char particles formed during devolatilization when the coal and biomass particles are co-fired. The biomass particles devolatilize prior to the coal particles, impacting the temperature and the composition of the environment in which the coal particles devolatilize. This situation results in coal char particles within the mixed char that differ in specific surface area and reactivity from the coal char particles produced in the absence of the devolatilizing biomass particles. Due to presence of this “affected” coal char, it was not possible to develop a mixed char reactivity model that uses linear mixing rules to determine the reactivity of a mixed char from only the reactivities of the pure mixture components. However, it was possible to predict both mixed char specific surface area and reactivity for a wide range of fuel mixture rat os provided the specific surface area and reactivity of the affected coal char particles are known. Using the kinetic parameters determined for the Wyodak coal and corn stover chars, the model was found to adequately predict the observed conversion times a

  20. Corrosion and mechanical behavior of materials for coal gasification applications

    SciTech Connect (OSTI)

    Natesan, K.

    1980-05-01

    A state-of-the-art review is presented on the corrosion and mechanical behavior of materials at elevated temperatures in coal-gasification environments. The gas atmosphere in coal-conversion processes are, in general, complex mixtures which contain sulfur-bearing components (H/sub 2/S, SO/sub 2/, and COS) as well as oxidants (CO/sub 2//CO and H/sub 2/O/H/sub 2/). The information developed over the last five years clearly shows sulfidation to be the major mode of material degradation in these environments. The corrosion behavior of structural materials in complex gas environments is examined to evaluate the interrelationships between gas chemistry, alloy chemistry, temperature, and pressure. Thermodynamic aspects of high-temperature corrosion processes that pertain to coal conversion are discussed, and kinetic data are used to compare the behavior of different commercial materials of interest. The influence of complex gas environments on the mechanical properties such as tensile, stress-rupture, and impact on selected alloys is presented. The data have been analyzed, wherever possible, to examine the role of environment on the property variation. The results from ongoing programs on char effects on corrosion and on alloy protection via coatings, cladding, and weld overlay are presented. Areas of additional research with particular emphasis on the development of a better understanding of corrosion processes in complex environments and on alloy design for improved corrosion resistance are discussed. 54 references, 65 figures, 24 tables.

  1. Techno-Economic Analysis of Biofuels Production Based on Gasification

    SciTech Connect (OSTI)

    Swanson, R. M.; Platon, A.; Satrio, J. A.; Brown, R. C.; Hsu, D. D.

    2010-11-01

    This study compares capital and production costs of two biomass-to-liquid production plants based on gasification. The first biorefinery scenario is an oxygen-fed, low-temperature (870?C), non-slagging, fluidized bed gasifier. The second scenario is an oxygen-fed, high-temperature (1,300?C), slagging, entrained flow gasifier. Both are followed by catalytic Fischer-Tropsch synthesis and hydroprocessing to naphtha-range (gasoline blend stock) and distillate-range (diesel blend stock) liquid fractions. Process modeling software (Aspen Plus) is utilized to organize the mass and energy streams and cost estimation software is used to generate equipment costs. Economic analysis is performed to estimate the capital investment and operating costs. Results show that the total capital investment required for nth plant scenarios is $610 million and $500 million for high-temperature and low-temperature scenarios, respectively. Product value (PV) for the high-temperature and low-temperature scenarios is estimated to be $4.30 and $4.80 per gallon of gasoline equivalent (GGE), respectively, based on a feedstock cost of $75 per dry short ton. Sensitivity analysis is also performed on process and economic parameters. This analysis shows that total capital investment and feedstock cost are among the most influential parameters affecting the PV.

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

    SciTech Connect (OSTI)

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

    2008-07-01

    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.

  3. Effects of temporally varying liquid-phase mass diffusivity in multicomponent droplet gasification

    SciTech Connect (OSTI)

    Zhang, Huiqiang [Department of Mechanical and Aerospace Engineering, Princeton University, Princeton, NJ 08544 (United States); Department of Engineering Mechanics, Tsinghua University, Beijing, 100084 (China); Law, Chung K. [Department of Mechanical and Aerospace Engineering, Princeton University, Princeton, NJ 08544 (United States)

    2008-06-15

    The relative roles of liquid-phase diffusional resistance and volatility differential in multicomponent droplet gasification are revisited, recognizing that liquid-phase mass diffusivities can be substantially increased as the droplet is progressively heated upon initiation of gasification, leading to a corresponding substantial weakening of the diffusional resistance. Calculations performed using realistic and temperature-dependent thermal and mass diffusivities indeed substantiate this influence. In particular, the calculated results agree with the literature experimental data, indicating that the gasification mechanism of multicomponent fuels is intermediate between diffusion and distillation limits. Investigation was also performed on gasification at elevated pressures, recognizing that the liquid boiling point and hence the attainable droplet temperature would increase with increasing pressure, causing further weakening of the liquid-phase diffusional resistance. This possibility was again verified through calculated results, suggesting further departure from diffusion limit toward distillation limit behavior for gasification at high pressures. The study also found that diffusional resistance is stronger for the lighter, gasoline-like fuels as compared to the heavier, diesel-like fuels because the former have overall lower boiling points, lower attainable droplet temperatures, and hence lower mass diffusivities in spite of their lower molecular weights. (author)

  4. Analysis of energy recovery potential using innovative technologies of waste gasification

    SciTech Connect (OSTI)

    Lombardi, Lidia; Carnevale, Ennio; Corti, Andrea

    2012-04-15

    Highlights: Black-Right-Pointing-Pointer Energy recovery from waste by gasification was simulated. Black-Right-Pointing-Pointer Two processes: high temperature gasification and gasification associated to plasma. Black-Right-Pointing-Pointer Two types of feeding waste: Refuse Derived Fuel (RDF) and pulper residues. Black-Right-Pointing-Pointer Different configurations for the energy cycles were considered. Black-Right-Pointing-Pointer Comparison with performances from conventional Waste-to-Energy process. - Abstract: In this paper, two alternative thermo-chemical processes for waste treatment were analysed: high temperature gasification and gasification associated to plasma process. The two processes were analysed from the thermodynamic point of view, trying to reconstruct two simplified models, using appropriate simulation tools and some support data from existing/planned plants, able to predict the energy recovery performances by process application. In order to carry out a comparative analysis, the same waste stream input was considered as input to the two models and the generated results were compared. The performances were compared with those that can be obtained from conventional combustion with energy recovery process by means of steam turbine cycle. Results are reported in terms of energy recovery performance indicators as overall energy efficiency, specific energy production per unit of mass of entering waste, primary energy source savings, specific carbon dioxide production.

  5. Plasma Treatments and Biomass Gasification This article has been downloaded from IOPscience. Please scroll down to see the full text article.

    E-Print Network [OSTI]

    Boyer, Edmond

    Plasma Treatments and Biomass Gasification This article has been downloaded from IOPscience. Please Treatments and Biomass Gasification J Luche1 , Q Falcoz2 , T Bastien2 , J P Leninger2 , K Arabi1 , O Aubry1 various methods of biomass processing. Gasification is one of the ways to recover energy from biomass

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

    E-Print Network [OSTI]

    Qiao, Li

    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

  7. Chemical Processing in High-Pressure Aqueous Environments. 7. Process Development for Catalytic Gasification of Wet Biomass

    E-Print Network [OSTI]

    Gasification of Wet Biomass Feedstocks Douglas C. Elliott,* Gary G. Neuenschwander, Todd R. Hart, R. Scott catalyst, gasification of wet biomass can be accomplished with high levels of carbon conversion to gas of the organic structure of biomass to gases has been achieved in the presence of a ruthenium metal catalyst

  8. Development of an advanced, continuous mild gasification process for the production of co-products (Task 1), Volume 1

    SciTech Connect (OSTI)

    Knight, R.A.; Gissy, J.L.; Onischak, M.; Babu, S.P.; Carty, R.H. ); Duthie, R.G. ); Wootten, J.M. )

    1991-09-01

    Under US DOE sponsorship, a project team consisting of the Institute of Gas Technology, Peabody Holding Company, and Bechtel Group, Inc. has been developing an advanced, mild gasification process to process all types of coal and to produce solid and condensable liquid co-products that can open new markets for coal. The three and a half year program (September 1987 to June 1991) consisted of investigations in four main areas. These areas are: (1) Literature Survey of Mild Gasification Processes, Co-Product Upgrading and Utilization, and Market Assessment; (2) Mild Gasification Technology Development: Process Research Unit Tests Using Slipstream Sampling; (3) Bench-Scale Char Upgrading Study; (4) Mild Gasification Technology Development: System Integration Studies. In this report, the literature and market assessment of mild gasification processes are discussed.

  9. Utilization of solid wastes from the gasification of coal-water slurries

    SciTech Connect (OSTI)

    M.Y. Shpirt; N.P. Goryunova

    2009-07-01

    It was found that only fly and bottom ashes are the solid wastes of water-coal slurry gasification in a direct-flow gasifier. The yields and chemical compositions of fly and bottom ashes obtained after the gasification of water-coal slurries prepared using brown (B) and long-flame (D) coals from the Berezovskii and Mokhovskii strip mines (Kansk-Achinsk and Kuznetsk Basins, respectively) were characterized. Based on an analysis of currently available information, the areas of utilization of fly and bottom ashes after water-coal slurry gasification with dry ash removal were summarized. The use of these wastes in the construction of high-ways and earthwork structures (for the parent coals of B and D grades) and in the manufacture of ash concrete (for the parent coal of D grade) is most promising.

  10. Transformation of alkali metals during pyrolysis and gasification of a lignite

    SciTech Connect (OSTI)

    Xiaofang Wei; Jiejie Huang; Tiefeng Liu; Yitian Fang; Yang Wang [Chinese Academy of Sciences, Taiyuan (China). Institute of Coal Chemistry

    2008-05-15

    Transformation of Na and K in a lignite was investigated during pyrolysis and gasification in a fixed-bed by using a serial dissolution method with H{sub 2}O, CH{sub 3}COONH{sub 4}, and HCl solutions. The evolution of the fractions of four forms in solid and alkali volatilization during pyrolysis and gasification was determined. The results show that a different mode of occurrence between Na and of K in coal existed. Na in coal can be nearly completely dissolved by H{sub 2}O, CH{sub 3}COONH{sub 4}, and HCl solution. However, K in coal exists almost in the stable forms. Both H{sub 2}O soluble and CH{sub 3}COONH{sub 4} soluble Na and K fractions decline during pyrolysis and early gasification stage and increase a little with the process of char gasification. The stable form Na in the char produced during pyrolysis is transferred to other forms during char gasification via the pore opening and a series of chemical reactions. Na{sub 2}SO{sub 4} (K{sub 2}SO{sub 4}) may play an important role in producing stable forms such as Na{sub 2}O.Al{sub 2}O{sub 3}2SiO{sub 2} and K{sub 2}O.Al{sub 2}O{sub 3}.2SiO{sub 2} during pyrolysis. The fraction of HCl soluble K increases during pyrolysis but decreases markedly during the early gasification stage. 20 refs., 7 figs., 1 tabs.

  11. Production of Medium BTU Gas by In Situ Gasification of Texas Lignite 

    E-Print Network [OSTI]

    Edgar, T. F.

    1979-01-01

    ~vity planned for the mining of lignite by 1985, at which time Texas is projected to becom~ the seventh largest coal mining state. However, the deep basin lignite cannot be economically recovered by strip or shaft mining. For this lignite there is great...-770652, 1977. 11. Gregg, D. W., and T. F. Edgar, "Underground Coal Gasification," AIChE J., ~, 753 (1978) ? 12. Gregg, D. W., R. W. Hill, and D. U. Olness, "An Overview of the Soviet Effort in Underground Coal Gasification," Lawrence Livermore...

  12. Characterization of Texas lignite and numerical modeling of its in-situ gasification 

    E-Print Network [OSTI]

    Wang, Yih-Jy

    1983-01-01

    Modeling Site selection for in-situ gasification projects normally involves application of site screen1ng criteria. Some of these cr1teria were discussed by Russell et al. (1983). Numerical simulation may play an important role in s1te selection...CHARACTERIZATION OF TEXAS LIGNITE AND NUMERICAL MODELING OF ITS IN-SITU GASIFICATION A Thesis by YIH-JY WANG Submitted to the Graduate College of Texas A&M University in partial fulfillment of the requirements for the degree of MASTER...

  13. Power Systems Development Facility Gasification Test Run TC08

    SciTech Connect (OSTI)

    Southern Company Services

    2002-06-30

    This report discusses Test Campaign TC08 of the Kellogg Brown & Root, Inc. (KBR) Transport Gasifier train with a Siemens Westinghouse Power Corporation (Siemens Westinghouse) particle filter system at the Power Systems Development Facility (PSDF) located in Wilsonville, Alabama. The Transport Gasifier is an advanced circulating fluidized-bed gasifier designed to operate as either a combustor or a gasifier in air- or oxygen-blown mode using a particulate control device (PCD). The Transport Gasifier was operated as a pressurized gasifier in air- and oxygen-blown modes during TC08. Test Run TC08 was started on June 9, 2002 and completed on June 29. Both gasifier and PCD operations were stable during the test run with a stable baseline pressure drop. The oxygen feed supply system worked well and the transition from air to oxygen blown was smooth. The gasifier temperature was varied between 1,710 and 1,770 F at pressures from 125 to 240 psig. The gasifier operates at lower pressure during oxygen-blown mode due to the supply pressure of the oxygen system. In TC08, 476 hours of solid circulation and 364 hours of coal feed were attained with 153 hours of pure oxygen feed. The gasifier and PCD operations were stable in both enriched air and 100 percent oxygen blown modes. The oxygen concentration was slowly increased during the first transition to full oxygen-blown operations. Subsequent transitions from air to oxygen blown could be completed in less than 15 minutes. Oxygen-blown operations produced the highest synthesis gas heating value to date, with a projected synthesis gas heating value averaging 175 Btu/scf. Carbon conversions averaged 93 percent, slightly lower than carbon conversions achieved during air-blown gasification.

  14. Enhanced durability and reactivity for zinc ferrite desulfurization sorbent

    SciTech Connect (OSTI)

    Jha, M.C.; Berggren, M.H.

    1987-10-27

    AMAX Research Development Center (AMAX R D) has been investigating methods for improving the reactivity and durability of the zinc ferrite desulfurization sorbent. Zinc ferrite sorbents are intended for use in desulfurization of hog coal gas in integrated gasification combined cycle (IGCC) or molten carbonate fuel cell (MCFC) applications. The reactivity of the sorbent may be defined as its sulfur sorption capacity at the breakthrough point in a bench-scale fixed-bed reactor. The durability may be defined as the ability of the sorbent to maintain its reactivity and other important physical characteristics such as size, strength, and specific surface area during 10 cycles of sulfidation and regeneration. Two base case sorbents, spherical pellets and cylindrical extrudes used in related METC sponsored projects, are being used to provide a basis for the comparison of physical characteristics and chemical reactivity.

  15. Enhanced durability and reactivity for zinc ferrite desulfurization sorbent. Quarterly technical progress report 4, July--September 1987

    SciTech Connect (OSTI)

    Jha, M.C.; Berggren, M.H.

    1987-10-27

    AMAX Research & Development Center (AMAX R&D) has been investigating methods for improving the reactivity and durability of the zinc ferrite desulfurization sorbent. Zinc ferrite sorbents are intended for use in desulfurization of hog coal gas in integrated gasification combined cycle (IGCC) or molten carbonate fuel cell (MCFC) applications. The reactivity of the sorbent may be defined as its sulfur sorption capacity at the breakthrough point in a bench-scale fixed-bed reactor. The durability may be defined as the ability of the sorbent to maintain its reactivity and other important physical characteristics such as size, strength, and specific surface area during 10 cycles of sulfidation and regeneration. Two base case sorbents, spherical pellets and cylindrical extrudes used in related METC sponsored projects, are being used to provide a basis for the comparison of physical characteristics and chemical reactivity.

  16. Data summary report for M.W. Kellog zinc titanite test series: ZTSC-01, ZTSC-02, ZTSC-03, ZTSC-04, ZTSC-05, ZTSC-06, ZTSC-07, ZTSC-08, ZTMC-01, ZTMC-02, ZTMC-03, ZTMC-05. CRADA 92-008 Final report

    SciTech Connect (OSTI)

    Everett, C.E.; Monaco, S.J.

    1994-05-01

    A series of tests were undertaken from August 6, 1992 through July 6, 1993 at METC`s High Pressure Bench-Scale Hot Gas Desulfurization Unit to support a Cooperative Research and Development Agreement (CRADA) between METC`s Sorbent Development Cluster and M.W. Kellogg. The M.W. Kellogg Company is currently developing a commercial offering of a hot gas clean-up system to be used in Integrated Gasification Combined Cycle (IGCC) systems. The intent of the CRADA agreement was to identify a suitable zinc-based desulfurization sorbent for the Sierra Pacific Power Company Clean Coal Technology Project, to identify optimum operating conditions for the sorbent, and to estimate potential sorbent loss per year. Task 1 of the CRADA agreement was to conduct fixed-bed zinc titanate sorbent testing. The results of Task 1 testing are presented in this report.

  17. Computational Design and Experimental Validation of New Thermal Barrier Systems

    SciTech Connect (OSTI)

    Guo, Shengmin; Yang, Shizhong; Khosravi, Ebrahim

    2012-10-01

    This project (10/01/2010-9/30/2013), “Computational Design and Experimental Validation of New Thermal Barrier Systems”, originates from Louisiana State University (LSU) Mechanical Engineering Department and Southern University (SU) Department of Computer Science. This project will directly support the technical goals specified in DEFOA- 0000248, Topic Area 3: Turbine Materials, by addressing key technologies needed to enable the development of advanced turbines and turbine-based systems that will operate safely and efficiently using coal-derived synthesis gases. We will develop and implement novel molecular dynamics method to improve the efficiency of simulation on novel TBC materials; perform high performance computing (HPC) on complex TBC structures to screen the most promising TBC compositions; perform material characterizations and oxidation/corrosion tests; and demonstrate our new thermal barrier coating (TBC) systems experimentally under integrated gasification combined cycle (IGCC) environments. The durability of the coating will be examined using the proposed Durability Test Rig.

  18. Computational Design and Experimental Validation of New Thermal Barrier Systems

    SciTech Connect (OSTI)

    Guo, Shengmin; Yang, Shizhong; Khosravi, Ebrahim

    2014-04-01

    This project (10/01/2010-9/30/2014), “Computational Design and Experimental Validation of New Thermal Barrier Systems”, originates from Louisiana State University (LSU) Mechanical Engineering Department and Southern University (SU) Department of Computer Science. This project will directly support the technical goals specified in DE-FOA-0000248, Topic Area 3: Turbine Materials, by addressing key technologies needed to enable the development of advanced turbines and turbine-based systems that will operate safely and efficiently using coal-derived synthesis gases. In this project, the focus is to develop and implement novel molecular dynamics method to improve the efficiency of simulation on novel TBC materials; perform high performance computing (HPC) on complex TBC structures to screen the most promising TBC compositions; perform material characterizations and oxidation/corrosion tests; and demonstrate our new thermal barrier coating (TBC) systems experimentally under integrated gasification combined cycle (IGCC) environments.

  19. Data summary report for M.W. Kellogg Z-sorb sorbent tests. CRADA 92-008 Final report

    SciTech Connect (OSTI)

    Everett, C.E.; Monaco, S.J.

    1994-05-01

    A series of tests were undertaken from August 6, 1992 through July 6, 1993 at METC`s High Pressure Bench-Scale Hot Gas Desulfurization Unit to support a Cooperative Research and Development Agreement (CRADA) between METC`s Sorbent Development Cluster and M.W. Kellogg. The M.W. Kellogg Company is currently developing a commercial offering of a hot gas clean-up system to be used in Integrated Gasification Combined Cycle (IGCC) systems. The intent of the CRADA agreement was to identify a suitable zinc-based desulfurization sorbent for the Sierra Pacific Power Company Clean Coal Technology Project, to identify optimum operating conditions for the sorbent, and to estimate potential sorbent loss per year. This report presents results pertaining to Phillips Petroleum`s Z-Sorb III sorbent.

  20. Gasification characteristics of an activated carbon catalyst during the decomposition of hazardous waste material in supercritical water

    SciTech Connect (OSTI)

    Matsumura, Yukihiko; Nuessle, F.W.; Antal, M.J. Jr. [Univ. of Hawaii at Manoa, Honolulu, HI (United States)

    1996-12-31

    Recently, carbonaceous materials including activated carbon were proven to be effective catalysts for hazardous waste gasification in supercritical water. Using coconut shell activated carbon catalyst, complete decomposition of industrial organic wastes including methanol and acetic acid was achieved. During this process, the total mass of the activated carbon catalyst changes by two competing processes: a decrease in weight via gasification of the carbon by supercritical water, or an increase in weight by deposition of carbonaceous materials generated by incomplete gasification of the biomass feedstocks. The deposition of carbonaceous materials does not occur when complete gasification is realized. Gasification of the activated carbon in supercritical water is often favored, resulting in changes in the quality and quantity of the catalyst. To thoroughly understand the hazardous waste decomposition process, a more complete understanding of the behavior of activated carbon in pure supercritical water is needed. The gasification rate of carbon by water vapor at subcritical pressures was studied in relation to coal gasification and generating activated carbon.

  1. Process and technological aspects of municipal solid waste gasification. A review

    SciTech Connect (OSTI)

    Arena, Umberto

    2012-04-15

    Highlights: Black-Right-Pointing-Pointer Critical assessment of the main commercially available MSW gasifiers. Black-Right-Pointing-Pointer Detailed discussion of the basic features of gasification process. Black-Right-Pointing-Pointer Description of configurations of gasification-based waste-to-energy units. Black-Right-Pointing-Pointer Environmental performance analysis, on the basis of independent sources data. - Abstract: The paper proposes a critical assessment of municipal solid waste gasification today, starting from basic aspects of the process (process types and steps, operating and performance parameters) and arriving to a comparative analysis of the reactors (fixed bed, fluidized bed, entrained bed, vertical shaft, moving grate furnace, rotary kiln, plasma reactor) as well as of the possible plant configurations (heat gasifier and power gasifier) and the environmental performances of the main commercially available gasifiers for municipal solid wastes. The analysis indicates that gasification is a technically viable option for the solid waste conversion, including residual waste from separate collection of municipal solid waste. It is able to meet existing emission limits and can have a remarkable effect on reduction of landfill disposal option.

  2. The Mansfield Two-Stage, Low BTU Gasification System: Report of Operations 

    E-Print Network [OSTI]

    Blackwell, L. T.; Crowder, J. T.

    1983-01-01

    The least expensive way to produce gas from coal is by low Btu gasification, a process by which coal is converted to carbon monoxide and hydrogen by reacting it with air and steam. Low Btu gas, which is used near its point of production, eliminates...

  3. Effects of coal combustion and gasification upon lung structure and function. Quarterly progress report

    SciTech Connect (OSTI)

    Hinton, Dr., David E.

    1980-12-12

    The effects on lungs of emissions from fluidized-bed combustion and coal gasification on man are being studied by inhalation experiments and intratracheal administration of fly ash to hamsters. The hamsters are sacrificed at 1, 3, 6, 9 and 30 days and the lungs examined by methods which are described. (LTN)

  4. ELECTRICITY FROM WOOD-FIRED GASIFICATION IN UGANDA -A 250 AND 10KW CASE STUDY

    E-Print Network [OSTI]

    Vermont, University of

    electricity at US$ 0.18 and 0.34/kWh, respectively. A stable electricity demand close to the rated capacityELECTRICITY FROM WOOD-FIRED GASIFICATION IN UGANDA - A 250 AND 10KW CASE STUDY Thomas Buchholza their potential to compete economically with diesel generated electricity when operating close to the rated

  5. Design Case Summary: Production of Mixed Alcohols from Municipal Solid Waste via Gasification

    SciTech Connect (OSTI)

    None

    2010-03-01

    The Biomass Program develops design cases to understand the current state of conversion technologies and to determine where improvements need to take place in the future. This design case establishes cost targets for converting MSW to ethanol and other mixed alcohols via gasification.

  6. Bench-scale development of mild gasification char desulfurization. Technical report, 1 March--31 May 1994

    SciTech Connect (OSTI)

    Knight, R.A. [Inst. of Gas Technology, Chicago, IL (United States)

    1994-09-01

    The goal of this project is to scale up a process, developed under a previous ICCI grant, for desulfurization of mild gasification char by treatment with hydrogen-rich process-derived fuel gas at 650--760 C and 7--15 atm. The char can be converted into a low-sulfur metallurgical form coke. In the prior study, IBC-105 coal with 4.0 wt% sulfur was converted to chars with less than 1.0 wt% sulfur in a laboratory-scale batch reactor. The susceptibility of the char to desulfurization was correlated with physicochemical char properties and mild gasification conditions. Acid pretreatment of the coal prior to mild gasification was also shown to significantly enhance subsequent sulfur removal. In this study, IGT is conducting continuous bench-scale tests in a 1-lb/h fluidized-bed reactor to determine the preferred process conditions and obtain steady-state data necessary for process design and scale-up. The desulfurized chars are to be used to produce low-sulfur form coke, which will be evaluated for density, reactivity, and strength properties relevant to utilization in blast furnaces. This quarter, 2,500 g of mild gasification char was produced from untreated IBC-105 coal in the bench-scale reactor. Half of this char will be subjected to sulfuric acid treatment to enhance subsequent desulfurization. Char-producing runs were also initiated with acid-pretreated coal, which will produce about 1,250 g of char.

  7. Original Research Article Evaluating air-blown gasification for energy recovery from wastewater

    E-Print Network [OSTI]

    implementation is the low energy efficiency associated with small treatment plants and the lack of available wastewater sol- ids to energy at small wastewater resource recovery facilities (WRRF). A model developedOriginal Research Article Evaluating air-blown gasification for energy recovery from wastewater

  8. Gasification of Low Ash Partially Composted Dairy Biomass with Enriched Air Mixture 

    E-Print Network [OSTI]

    Thanapal, Siva Sankar

    2012-02-14

    gasification medium. The peak temperature increased from 988°C to 1192°C as the oxygen concentration increased from 21% to 28% at ER=2.1. The upper limit on oxygen concentration is limited to 28% due to high peak temperature and resulting ash agglomeration...

  9. EARLY ENTRANCE CO-PRODUCTION PLANT - DECENTRALIZED GASIFICATION COGENERATION TRANSPORTATION FUELS AND STEAM FROM AVAILABLE FEEDSTOCKS

    SciTech Connect (OSTI)

    Unknown

    2001-12-01

    Waste Processors Management, Inc. (WMPI), along with its subcontractors Texaco Power & Gasification, SASOL Technology Ltd., and Nexant Inc. entered into a Cooperative Agreement DE-FC26-00NT40693 with the US Department of Energy (DOE), National Energy Technology Laboratory (NETL) to assess the techno-economic viability of building an Early Entrance Co-Production Plant (EECP) in the US to produce ultra clean Fischer-Tropsch (FT) transportation fuels with either power or steam as the major co-product. The EECP designs emphasize on recovery and gasification of low-cost coal waste (culm) from coal clean operations and will assess blends of the culm and coal or petroleum coke as feedstocks. The project is being carried out in three phases. Phase I involves definition of concept and engineering feasibility study to identify areas of technical, environmental and financial risk. Phase II consists of an experimental testing program designed to validate the coal waste mixture gasification performance. Phase III involves updating the original EECP design, based on results from Phase II, to prepare a preliminary engineering design package and financial plan for obtaining private funding to build a 5,000 BPD coal gasification/liquefaction plant next to an existing co-generation plant in Gilberton, Schuylkill County, Pennsylvania.

  10. EARLY ENTRANCE CO-PRODUCTION PLANT - DECENTRALIZED GASIFICATION COGENERATION TRANSPORTATION FUELS AND STEAM FROM AVAILABLE FEEDSTOCKS

    SciTech Connect (OSTI)

    Unknown

    2003-01-01

    Waste Processors Management, Inc. (WMPI), along with its subcontractors Texaco Power & Gasification (now ChevronTexaco), SASOL Technology Ltd., and Nexant Inc. entered into a Cooperative Agreement DE-FC26-00NT40693 with the U. S. Department of Energy (DOE), National Energy Technology Laboratory (NETL) to assess the technoeconomic viability of building an Early Entrance Co-Production Plant (EECP) in the United States to produce ultra clean Fischer-Tropsch (FT) transportation fuels with either power or steam as the major co-product. The EECP design includes recovery and gasification of low-cost coal waste (culm) from physical coal cleaning operations and will assess blends of the culm with coal or petroleum coke. The project has three phases. Phase I is the concept definition and engineering feasibility study to identify areas of technical, environmental and financial risk. Phase II is an experimental testing program designed to validate the coal waste mixture gasification performance. Phase III updates the original EECP design based on results from Phase II, to prepare a preliminary engineering design package and financial plan for obtaining private funding to build a 5,000 barrel per day (BPD) coal gasification/liquefaction plant next to an existing co-generation plant in Gilberton, Schuylkill County, Pennsylvania. The current report covers the period performance from July 1, 2002 through September 30, 2002.

  11. Differences in gasification behaviors and related properties between entrained gasifier fly ash and coal char

    SciTech Connect (OSTI)

    Jing Gu; Shiyong Wu; Youqing Wu; Ye Li; Jinsheng Gao

    2008-11-15

    In the study, two fly ash samples from Texaco gasifiers were compared to coal char and the physical and chemical properties and reactivity of samples were investigated by scanning electron microscopy (SEM), SEM-energy-dispersive spectrometry (EDS), X-ray diffraction (XRD), N{sub 2} and CO{sub 2} adsorption method, and isothermal thermogravimetric analysis. The main results were obtained. The carbon content of gasified fly ashes exhibited 31-37%, which was less than the carbon content of 58-59% in the feed coal. The fly ashes exhibited higher Brunauer-Emmett-Teller (BET) surface area, richer meso- and micropores, more disordered carbon crystalline structure, and better CO{sub 2} gasification reactivity than coal char. Ashes in fly ashes occurred to agglomerate into larger spherical grains, while those in coal char do not agglomerate. The minerals in fly ashes, especial alkali and alkaline-earth metals, had a catalytic effect on gasification reactivity of fly ash carbon. In the low-temperature range, the gasification process of fly ashes is mainly in chemical control, while in the high-temperature range, it is mainly in gas diffusion control, which was similar to coal char. In addition, the carbon in fly ashes was partially gasified and activated by water vapor and exhibited higher BET surface area and better gasification activity. Consequently, the fact that these carbons in fly ashes from entrained flow gasifiers are reclaimed and reused will be considered to be feasible. 15 refs., 7 figs., 5 tabs.

  12. Biomass Gasification using Solar Thermal Energy M. Munzinger and K. Lovegrove

    E-Print Network [OSTI]

    Biomass Gasification using Solar Thermal Energy M. Munzinger and K. Lovegrove Solar Thermal Group.lovegrove@anu.edu.au Hydrogen from Biomass as an energy carrier has generated increasing interest in recent years. There are several different technologies to convert solid or liquid Biomass into a gas mix consisting of mainly

  13. Proceedings of the seventh annual gasification and gas stream cleanup systems contractors review meeting: Volume 2

    SciTech Connect (OSTI)

    Ghate, M.R.; Markel, K.E. Jr.; Jarr, L.A.; Bossart, S.J.

    1987-08-01

    On June 16 through 19, 1987, METC sponsored the Seventh Annual Gasification and Gas Stream Cleanup Systems Contractors Review Meeting which was held at the Sheraton Lakeview Conference Center in Morgantown, West Virginia. The primary purpose of the meeting was threefold: to review the technical progress and current status of the gasification and gas stream cleanup projects sponsored by the Department of Energy; to foster technology exchange among participating researchers and other technical communities; to facilitate interactive dialogues which would identify research needs that would make coal-based gasification systems more attractive economically and environmentally. More than 310 representatives of Government, academia, industry, and foreign energy research organizations attended the 4-day meeting. Fifty-three papers and thirty poster dsplays were presented summarizing recent developments in the gasification and gas stream cleanup programs. Volume II covers papers presented at sessions 5 and 6 on system for the production of synthesis gas, and on system for the production of power. All papers have been processed for inclusion in the Energy Data Base.

  14. Environmentally Safe, Large Volume Utilization Applications for Gasification Byproducts

    SciTech Connect (OSTI)

    J.G. Groppo; R. Rathbone

    2008-06-30

    Samples of gasification by-products produced at Polk Station and Eastman Chemical were obtained and characterized. Bulk samples were prepared for utilization studies by screening at the appropriate size fractions where char and vitreous frit distinctly partitioned. Vitreous frit was concentrated in the +20 mesh fraction while char predominated in the -20+100 mesh fraction. The vitreous frit component derived from each gasifier slag source was evaluated for use as a pozzolan and as aggregate. Pozzolan testing required grinding the frit to very fine sizes which required a minimum of 60 kwhr/ton. Grinding studies showed that the energy requirement for grinding the Polk slag were slightly higher than for the Eastman slag. Fine-ground slag from both gasifiers showed pozzoalnic activity in mortar cube testing and met the ASTM C618 strength requirements after only 3 days. Pozzolanic activity was further examined using British Standard 196-5, and results suggest that the Polk slag was more reactive than the Eastman slag. Neither aggregate showed significant potential for undergoing alkali-silica reactions when used as concrete aggregate with ASTM test method 1260. Testing was conducted to evaluate the use of the frit product as a component of cement kiln feed. The clinker produced was comprised primarily of the desirable components Ca{sub 3}SiO{sub 5} and Ca{sub 2}SiO{sub 4} after raw ingredient proportions were adjusted to reduce the amount of free lime present in the clinker. A mobile processing plant was designed to produce 100 tons of carbon from the Eastman slag to conduct evaluations for use as recycle fuel. The processing plant was mounted on a trailer and hauled to the site for use. Two product stockpiles were generated; the frit stockpile contained 5% LOI while the carbon stockpile contained 62% LOI. The products were used to conduct recycle fuel tests. A processing plant was designed to separate the slag produced at Eastman into 3 usable products. The coarse frit has been shown to be suitable for use as clinker feed for producing Portland cement. The intermediate-size product is enriched in carbon (58-62% C) and may be used as recycle fuel either in the gasifier or in a PC boiler. The fines product contains 30-40% C and may also be used as a recycle gasifier fuel, as is presently done at TECO's Polk Station, however, due to gasifier operating requirements for the production of syngas, this is not feasible at Eastman.

  15. Tampa Electric Company Polk Power Station Unit Number 1. Annual report, January--December, 1993

    SciTech Connect (OSTI)

    Not Available

    1994-08-01

    This report satisfies the requirements of Cooperative Agreement DE-FC21-91MC27363, novated as of March 5, 1992, to provide an annual update report on the year`s activities associated with Tampa Electric Company`s 250 MW IGCC demonstration project for the year 1993. Tampa Electric Company`s Polk Power Station Unit 1 (PPS-1) Integrated Gasification Combined Cycle (IGCC) demonstration project will use a Texaco pressurized, oxygen-blown, entrained-flow coal gasifier to convert approximately 2,000 tons per day of coal (dry basis) coupled with a combined cycle power block to produce a net 250 MW electrical power output. Approximately 50% of the raw, hot syngas is cooled to 900 F and passed through a moving bed of zinc-based sorbent which removes sulfur containing compounds from the syngas. The remaining portion of the raw, hot syngas is cooled to 400 F for conventional acid gas removal. Sulfur-bearing compounds from both cleanup systems are sent to a conventional sulfuric acid plant to produce a marketable, high-purity sulfuric acid by-product. The cleaned medium-BTU syngas from these processes is routed to the combined cycle power generation system where it is mixed with air and burned in the combustion section of the combustion turbine. Heat is extracted from the expanded exhaust gases in a heat recovery steam generator (HRSG) to produce steam at three pressure levels for use throughout the integrated process. A highly modular, microprocessor-based distributed control system (DCS) is being developed to provide continuous and sequential control for most of the equipment on PPS-1.

  16. Behavior of chars from Bursa Mustafa Kemal Pasa Alpagut and Balkesir Dursunbey Cakiirca Lignite (Turkey) during non-catalytic and catalytic gasification

    SciTech Connect (OSTI)

    Bozkurt, Y.; Misirlioglu, Z.; Sinag, A.; Tekes, A.T.; Canel, M. [Ankara University, Ankara (Turkey). Dept. of Chemistry

    2008-07-01

    The reactivities of chars obtained by pyrolysis of Bursa Mustafa Kemal Pasa Alpagut lignite and Balkesir Dursunbey Cakiirca lignite (Turkey) at different temperatures were determined by CO{sub 2} gasification and by combustion with O{sub 2}. Catalytic effect of Na{sub 2}CO{sub 3} on the CO{sub 2} and O{sub 2} gasification reactivity of chars was investigated. Gasification tests were performed in the fixed bed reactors operating at ambient pressure. Reactivity of chars during the CO{sub 2} gasification reactions was determined by calculating the reaction rate constants and reactivity of chars during the O{sub 2} gasification was determined by using ignition temperatures of the samples. Activation energies and Arrhenius constants of the chars on the CO{sub 2} gasification reactions were also calculated by the help of Arrhenius curves. The activation energy for CO{sub 2} gasification was generally decreased with pyrolysis temperature, due to the different surface characteristics and different nature of carbon atoms gasified as the gasification reactions proceed. Generally, the increase in pyrolysis temperature leads to an increase in gasification reactivity with CO{sub 2}. The reactivity of chars in catalytic gasification was higher than the corresponding non-catalytic reactivity of the same chars. Ignition temperature increased with increasing pyrolysis temperature.

  17. Social and economic aspects of the introduction of gasification technology in rural areas of developing countries (Tanzania)

    SciTech Connect (OSTI)

    Groeneveld, M.J.; Westerterp, K.R.

    1980-01-01

    According to the evaluation criteria presented, the gasification of corn cobs is acceptable from the economical and agricultural point of view in the rural areas around Arusha (Tanzania). The gasification system is of relatively simple construction and local maintenance is possible. If the system is connected to the already existing corn mills in the villages, it is appropriate to the existing socio-cultural system. The economic calculations made clear that the use of gasification is attractive for both the owners of the corn mill and the government. The advantages for the government are the savings on imported oil and the extra income created for the users of the corn mill (inhabitants of the rural villages). The government loses income from taxes and from the production and transport of diesel oil. Evaluation methods presented can and should be used for gasification projects in other areas.

  18. Multiphysics modeling of carbon gasification processes in a well-stirred reactor with detailed gas-phase chemistry

    E-Print Network [OSTI]

    Qiao, Li

    . � 2011 The Combustion Institute. Published by Elsevier Inc. All rights reserved. 1. Introduction dynamics (CFD) of coal gasification reactors [8­12]. CFD mod- eling of entrained flow reactors is extremely

  19. TVA coal-gasification commercial demonstration plant project. Volume 5. Plant based on Koppers-Totzek gasifier. Final report

    SciTech Connect (OSTI)

    Not Available

    1980-11-01

    This volume presents a technical description of a coal gasification plant, based on Koppers-Totzek gasifiers, producing a medium Btu fuel gas product. Foster Wheeler carried out a conceptual design and cost estimate of a nominal 20,000 TPSD plant based on TVA design criteria and information supplied by Krupp-Koppers concerning the Koppers-Totzek coal gasification process. Technical description of the design is given in this volume.

  20. An investigation of changes in groundwater quality caused by in-situ gasification of East Texas lignite 

    E-Print Network [OSTI]

    Leach, Kimberly Sue

    1988-01-01

    AN INVESTIGATION OF CHANGES IN GROUNDWATER QUALITY CAUSED BY IN-SITU GASIFICATION OF EAST TEXAS LIGNITE A Thesis by KIMBERLY SUE LEACH Submitted to the Graduate College of Texas AGM University in Partial fulfillment of the requirements... for the degree of MASTER OF SCIENCE May 1988 Major Subject: Petroleum Engineering AN INVESTIGATION OF CHANGES IN GROUNDWATER QUALITY CAUSED BY IN-SITU GASIFICATION OF EAST TEXAS LIGNITE A Thesis by KIMBERLY SUE LEACH Approved as to style and content by...

  1. Product Characterization for Entrained Flow Coal/Biomass Co-Gasification

    SciTech Connect (OSTI)

    Shawn Maghzi; Ramanathan Subramanian; George Rizeq; Surinder Singh; John McDermott; Boris Eiteneer; David Ladd; Arturo Vazquez; Denise Anderson; Noel Bates

    2011-09-30

    The U.S. Department of Energyâ??s National Energy Technology Laboratory (DOE NETL) is exploring affordable technologies and processes to convert domestic coal and biomass resources to high-quality liquid hydrocarbon fuels. This interest is primarily motivated by the need to increase energy security and reduce greenhouse gas emissions in the United States. Gasification technologies represent clean, flexible and efficient conversion pathways to utilize coal and biomass resources. Substantial experience and knowledge had been developed worldwide on gasification of either coal or biomass. However, reliable data on effects of blending various biomass fuels with coal during gasification process and resulting syngas composition are lacking. In this project, GE Global Research performed a complete characterization of the gas, liquid and solid products that result from the co-gasification of coal/biomass mixtures. This work was performed using a bench-scale gasifier (BSG) and a pilot-scale entrained flow gasifier (EFG). This project focused on comprehensive characterization of the products from gasifying coal/biomass mixtures in a high-temperature, high-pressure entrained flow gasifier. Results from this project provide guidance on appropriate gas clean-up systems and optimization of operating parameters needed to develop and commercialize gasification technologies. GEâ??s bench-scale test facility provided the bulk of high-fidelity quantitative data under temperature, heating rate, and residence time conditions closely matching those of commercial oxygen-blown entrained flow gasifiers. Energy and Environmental Research Center (EERC) pilot-scale test facility provided focused high temperature and pressure tests at entrained flow gasifier conditions. Accurate matching of syngas time-temperature history during cooling ensured that complex species interactions including homogeneous and heterogeneous processes such as particle nucleation, coagulation, surface condensation, and gas-phase reactions were properly reproduced and lead to representative syngas composition at the syngas cooler outlet. The experimental work leveraged other ongoing GE R&D efforts such as biomass gasification and dry feeding systems projects. Experimental data obtained under this project were used to provide guidance on the appropriate clean-up system(s) and operating parameters to coal and biomass combinations beyond those evaluated under this project.

  2. Product Characterization for Entrained Flow Coal/Biomass Co-Gasification

    SciTech Connect (OSTI)

    Maghzi, Shawn; Subramanian, Ramanathan; Rizeq, George; Singh, Surinder; McDermott, John; Eiteneer, Boris; Ladd, David; Vazquez, Arturo; Anderson, Denise; Bates, Noel

    2011-09-30

    The U.S. Department of Energy‘s National Energy Technology Laboratory (DOE NETL) is exploring affordable technologies and processes to convert domestic coal and biomass resources to high-quality liquid hydrocarbon fuels. This interest is primarily motivated by the need to increase energy security and reduce greenhouse gas emissions in the United States. Gasification technologies represent clean, flexible and efficient conversion pathways to utilize coal and biomass resources. Substantial experience and knowledge had been developed worldwide on gasification of either coal or biomass. However, reliable data on effects of blending various biomass fuels with coal during gasification process and resulting syngas composition are lacking. In this project, GE Global Research performed a complete characterization of the gas, liquid and solid products that result from the co-gasification of coal/biomass mixtures. This work was performed using a bench-scale gasifier (BSG) and a pilot-scale entrained flow gasifier (EFG). This project focused on comprehensive characterization of the products from gasifying coal/biomass mixtures in a high-temperature, high-pressure entrained flow gasifier. Results from this project provide guidance on appropriate gas clean-up systems and optimization of operating parameters needed to develop and commercialize gasification technologies. GE‘s bench-scale test facility provided the bulk of high-fidelity quantitative data under temperature, heating rate, and residence time conditions closely matching those of commercial oxygen-blown entrained flow gasifiers. Energy and Environmental Research Center (EERC) pilot-scale test facility provided focused high temperature and pressure tests at entrained flow gasifier conditions. Accurate matching of syngas time-temperature history during cooling ensured that complex species interactions including homogeneous and heterogeneous processes such as particle nucleation, coagulation, surface condensation, and gas-phase reactions were properly reproduced and lead to representative syngas composition at the syngas cooler outlet. The experimental work leveraged other ongoing GE R&D efforts such as biomass gasification and dry feeding systems projects. Experimental data obtained under this project were used to provide guidance on the appropriate clean-up system(s) and operating parameters to coal and biomass combinations beyond those evaluated under this project.

  3. Cooperative Research in C1 Chemistry

    SciTech Connect (OSTI)

    Gerald P. Huffman

    2000-10-27

    C1 chemistry refers to the conversion of simple carbon-containing materials that contain one carbon atom per molecule into valuable products. The feedstocks for C1 chemistry include natural gas, carbon dioxide, carbon monoxide, methanol and synthesis gas (a mixture of carbon monoxide and hydrogen). Synthesis gas, or syngas, is produced primarily by the reaction of natural gas, which is principally methane, with steam. It can also be produced by gasification of coal, petroleum coke, or biomass. The availability of syngas from coal gasification is expected to increase significantly in the future because of increasing development of integrated gasification combined cycle (IGCC) power generation. Because of the abundance of remote natural gas, the advent of IGCC, and environmental advantages, C1 chemistry is expected to become a major area of interest for the transportation fuel and chemical industries in the relatively near future. The CFFLS will therefore perform a valuable national service by providing science and engineering graduates that are trained in this important area. Syngas is the source of most hydrogen. Approximately 10 trillion standard cubic feet (SCF) of hydrogen are manufactured annually in the world. Most of this hydrogen is currently used for the production of ammonia and in a variety of refining and chemical operations. However, utilization of hydrogen in fuel cells is expected to grow significantly in the next century. Syngas is also the feedstock for all methanol and Fischer-Tropsch plants. Currently, world consumption of methanol is over 25 million tons per year. There are many methanol plants in the U.S. and throughout the world. Methanol and oxygenated transportation fuel products play a significant role in the CFFLS C1 program. Currently, the only commercial Fischer-Tropsch plants are overseas, principally in South Africa (SASOL). However, new plants are being built or planned for a number of locations. One possible location for future F-T plant development in the U.S. is in the Alaskan oil fields.

  4. Bench-scale studies on gasification of biomass in the presence of catalysts

    SciTech Connect (OSTI)

    Mudge, L.K.; Baker, E.G.; Brown, M.D.; Wilcox, W.A.

    1987-11-01

    This report summarizes the results of bench-scale studies on the development of catalysts for conversion of biomass to specific gas products. The primary objective of these studies was to define operating conditions that allow long lifetimes for secondary catalysts used in biomass gasification. Nickel-based catalysts that were found to be active for conversion of wood to synthesis gases in previous studies were evaluated. These catalysts remained active indefinitely in laboratory studies but lost activity rapidly when evaluated in a process research unit. Bench-scale equipment was designed and installed to resolve the differences between laboratory and PRU results. Primary catalysts (alkali carbonates) were also evaluated for their effectiveness in improving conversion yields from biomass gasification. 21 refs., 27 figs., 19 tabs.

  5. Steam gasification of tyre waste, poplar, and refuse-derived fuel: A comparative analysis

    SciTech Connect (OSTI)

    Galvagno, S. Casciaro, G.; Casu, S.; Martino, M.; Mingazzini, C.; Russo, A.; Portofino, S.

    2009-02-15

    In the field of waste management, thermal disposal is a treatment option able to recover resources from 'end of life' products. Pyrolysis and gasification are emerging thermal treatments that work under less drastic conditions in comparison with classic direct combustion, providing for reduced gaseous emissions of heavy metals. Moreover, they allow better recovery efficiency since the process by-products can be used as fuels (gas, oils), for both conventional (classic engines and heaters) and high efficiency apparatus (gas turbines and fuel cells), or alternatively as chemical sources or as raw materials for other processes. This paper presents a comparative study of a steam gasification process applied to three different waste types (refuse-derived fuel, poplar wood and scrap tyres), with the aim of comparing the corresponding yields and product compositions and exploring the most valuable uses of the by-products.

  6. Catalyst specificities in high pressure hydroprocessing of pyrolysis and gasification tars

    SciTech Connect (OSTI)

    Soltes, E.J.; Lin, S.C.K.; Sheu, Y.H.E.

    1987-04-01

    Over a period of several years, the Department of Forest Science at Texas A and M University has been conducting studies in the hydroprocessing (catalytic high pressure hydrotreating or hydrodeoxygenation accompanied by hydrocracking) of pyrolytic tars produced in biomass pyrolysis and gasification. Upgrading through hydroprocessing results in good yields of volatile hydrocarbon and phenolic products. This paper compares the performance of twenty different catalysts selected for hydroprocessing of a pine pyrolysis oil, describes the use of noble metal catalysts with tars produced from nine different biomass feedstocks (oil from pine pyrolysis and the tars from pine wood chip, pine plywood trim, pecan shell, peanut shell, sugarcane bagasse, corncob, rice hull, and cottonseed hull gasification), and compares the use of several catalysts in a trickle bed reactor for kinetic studies of the hyroprocessing reaction.

  7. Methods for sulfate removal in liquid-phase catalytic hydrothermal gasification of biomass

    DOE Patents [OSTI]

    Elliott, Douglas C; Oyler, James

    2013-12-17

    Processing of wet biomass feedstock by liquid-phase catalytic hydrothermal gasification must address catalyst fouling and poisoning. One solution can involve heating the wet biomass with a heating unit to a pre-treatment temperature sufficient for organic constituents in the feedstock to decompose, for precipitates of inorganic wastes to form, for preheating the wet feedstock in preparation for subsequent removal of soluble sulfate contaminants, or combinations thereof. Processing further includes reacting the soluble sulfate contaminants with cations present in the feedstock material to yield a sulfate-containing precipitate and separating the inorganic precipitates and/or the sulfate-containing precipitates out of the wet feedstock. Having removed much of the inorganic wastes and the sulfate contaminants that can cause poisoning and fouling, the wet biomass feedstock can be exposed to the heterogenous catalyst for gasification.

  8. Methods for sulfate removal in liquid-phase catalytic hydrothermal gasification of biomass

    DOE Patents [OSTI]

    Elliott, Douglas C; Oyler, James R

    2014-11-04

    Processing of wet biomass feedstock by liquid-phase catalytic hydrothermal gasification must address catalyst fouling and poisoning. One solution can involve heating the wet biomass with a heating unit to a pre-treatment temperature sufficient for organic constituents in the feedstock to decompose, for precipitates of inorganic wastes to form, for preheating the wet feedstock in preparation for subsequent removal of soluble sulfate contaminants, or combinations thereof. Processing further includes reacting the soluble sulfate contaminants with cations present in the feedstock material to yield a sulfate-containing precipitate and separating the inorganic precipitates and/or the sulfate-containing precipitates out of the wet feedstock. Having removed much of the inorganic wastes and the sulfate contaminants that can cause poisoning and fouling, the wet biomass feedstock can be exposed to the heterogeneous catalyst for gasification.

  9. Coke Gasification - A Solution to Excess Coke Capacity and High Energy Costs 

    E-Print Network [OSTI]

    Patel, S. S.

    1982-01-01

    under the name GKT. Recently, the GKT gasifier was selected over the Texaco gasifier for the TVA Murphy Hill coal gasification project and -the Solvent Refined Coal-I coal liquefaction project A schematic :of the GKT gasifier is shown in Figure 1...;! at Texaco's Montebello Research Laboratory in California. ThEil pilot plant has been tested with various coals, petroleum coke and residues from coal liquefaction processes. Currently there are two 20 ton per day pilot plants operating at Montebello...

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

    DOE Patents [OSTI]

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

    1985-01-01

    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.

  11. Cryogenic fractionator gas as stripping gas of fines slurry in a coking and gasification process

    DOE Patents [OSTI]

    DeGeorge, Charles W. (Chester, NJ)

    1981-01-01

    In an integrated coking and gasification process wherein a stream of fluidized solids is passed from a fluidized bed coking zone to a second fluidized bed and wherein entrained solid fines are recovered by a scrubbing process and wherein the resulting solids-liquid slurry is stripped with a stripping gas to remove acidic gases, at least a portion of the stripping gas comprises a gas comprising hydrogen, nitrogen and methane separated from the coker products.

  12. Addendum to industrial market assessment of the products of mild gasification

    SciTech Connect (OSTI)

    Not Available

    1992-05-01

    The objective of this report is to review and update the 1988 report by J. E. Sinor Consultants Inc., ``Industrial Market Assessment of the Products of Mild Gasification, and to more fully present market opportunities for two char-based products from the mild gasification process (MGP): Formcoke for the iron and steel industry, and activated carbon for wastewater cleanup and flue gas scrubbing. Please refer to the original report for additional details. In the past, coal conversion projects have and liquids produced, and the value of the residual char was limited to its fuel value. Some projects had limited success until gas and oil competition overwhelmed them. The strategy adopted for this assessment is to seek first a premium value for the char in a market that has advantages over gas and oil, and then to find the highest values possible for gases, liquids, and tars, either on-site or sold into existing markets. During the intervening years since the 1988 report, there have been many changes in the national economy, industrial production, international competition, and environmental regulations. The Clean Air Act Amendments of 1990 (CAAA) will have a large impact on industry. There is considerable uncertainty about how the Act will be implemented, but it specifically addresses coke-oven batteries. This may encourage industry to consider formcoke produced via mild gasification as a low-pollution substitute for conventional coke. The chemistry and technology of coke making steel were reviewed in the 1988 market assessment and will not be repeated here. The CAAA require additional pollution control measures for most industrial facilities, but this creates new opportunities for the mild gasification process.

  13. Addendum to industrial market assessment of the products of mild gasification

    SciTech Connect (OSTI)

    Not Available

    1992-05-01

    The objective of this report is to review and update the 1988 report by J. E. Sinor Consultants Inc., Industrial Market Assessment of the Products of Mild Gasification, and to more fully present market opportunities for two char-based products from the mild gasification process (MGP): Formcoke for the iron and steel industry, and activated carbon for wastewater cleanup and flue gas scrubbing. Please refer to the original report for additional details. In the past, coal conversion projects have and liquids produced, and the value of the residual char was limited to its fuel value. Some projects had limited success until gas and oil competition overwhelmed them. The strategy adopted for this assessment is to seek first a premium value for the char in a market that has advantages over gas and oil, and then to find the highest values possible for gases, liquids, and tars, either on-site or sold into existing markets. During the intervening years since the 1988 report, there have been many changes in the national economy, industrial production, international competition, and environmental regulations. The Clean Air Act Amendments of 1990 (CAAA) will have a large impact on industry. There is considerable uncertainty about how the Act will be implemented, but it specifically addresses coke-oven batteries. This may encourage industry to consider formcoke produced via mild gasification as a low-pollution substitute for conventional coke. The chemistry and technology of coke making steel were reviewed in the 1988 market assessment and will not be repeated here. The CAAA require additional pollution control measures for most industrial facilities, but this creates new opportunities for the mild gasification process.

  14. Process for gasification using a synthetic CO.sub.2 acceptor

    DOE Patents [OSTI]

    Lancet, Michael S. (Pittsburgh, PA); Curran, George P. (Pittsburgh, PA)

    1980-01-01

    A gasification process is disclosed using a synthetic CO.sub.2 acceptor consisting essentially of at least one compound selected from the group consisting of calcium oxide and calcium carbonate supported in a refractory carrier matrix, the carrier having the general formula Ca.sub.5 (SiO.sub.4).sub.2 CO.sub.3. A method for producing the synthetic CO.sub.2 acceptor is also disclosed.

  15. Effect of CO2 gasification reaction on oxycombustion of pulverized coal char.

    SciTech Connect (OSTI)

    Molina, Alejandro; Hecht, Ethan S.; Shaddix, Christopher R.; Haynes, Brian S.

    2010-07-01

    For oxy-combustion with flue gas recirculation, as is commonly employed, it is recognized that elevated CO{sub 2} levels affect radiant transport, the heat capacity of the gas, and other gas transport properties. A topic of widespread speculation has concerned the effect of the CO{sub 2} gasification reaction with coal char on the char burning rate. To give clarity to the likely impact of this reaction on the oxy-fuel combustion of pulverized coal char, the Surface Kinetics in Porous Particles (SKIPPY) code was employed for a range of potential CO{sub 2} reaction rates for a high-volatile bituminous coal char particle (130 {micro}m diameter) reacting in several O{sub 2} concentration environments. The effects of boundary layer chemistry are also examined in this analysis. Under oxygen-enriched conditions, boundary layer reactions (converting CO to CO{sub 2}, with concomitant heat release) are shown to increase the char particle temperature and burning rate, while decreasing the O{sub 2} concentration at the particle surface. The CO{sub 2} gasification reaction acts to reduce the char particle temperature (because of the reaction endothermicity) and thereby reduces the rate of char oxidation. Interestingly, the presence of the CO{sub 2} gasification reaction increases the char conversion rate for combustion at low O{sub 2} concentrations, but decreases char conversion for combustion at high O{sub 2} concentrations. These calculations give new insight into the complexity of the effects from the CO{sub 2} gasification reaction and should help improve the understanding of experimentally measured oxy-fuel char combustion and burnout trends in the literature.

  16. Effect of pulsations on black liquor gasification. Progress report, July--September 1995

    SciTech Connect (OSTI)

    Kushari, A.; Jeong, H.; Jagoda, J.I.; Zinn, B.T.

    1995-12-31

    The objective of this study is to investigate the use of pulse combustion to provide the energy required for the endothermic gasification of black liquor in a fluidized bed. In this process it is critical that the temperature remain in the small window above the gasification temperature but below the smelting temperature of the inorganic salts in the black liquor. Pulse combustors have been shown to have high heat transfer rates between the hot combustion products and the combustor tailpipe. Similarly, fluidized beds have high heat transfer rates within the bed itself, promoting temperature uniformity throughout. Typical analysis of the gasified black liquor shows there is a large percentage of combustible gases in the products of the gasification process (approximately 70%). The potential exists, therefore, for using this fuel mixture to fire the pulse combustor. This makes the entire process more efficient and may be necessary to make it economically feasible. The overall goals of this study are to determine (1) which is the limiting heat transfer rate in the process of transferring the heat from the hot combustion products to the pipe, through the pipe, from the tailpipe to the bed and then throughout the bed; i.e., whether increased heat transfer within the pulse combustor will significantly increase the overall heat transfer rate; (2) whether the temperature distribution in the bed can be maintained within the narrow temperature range required by the process without generating hot spots in the bed even if the heat transfer from the pulse combustor is significantly increased; and (3) whether the fuel gas produced during the gasification process can be used to efficiently fire the pulse combustor.

  17. Study of char gasification in a differential fixed-bed reactor

    SciTech Connect (OSTI)

    Sotirchos, S.Y.; Crowley, J.A.

    1985-01-01

    The reaction of a low-ash coconut char with CO/sub 2/ was studied in a flow-type reaction/adsorption apparatus equipped with a thermal conductivity detector. The gaseous reactant (CO/sub 2/) is used as carrier gas. The concentration of CO in the product stream and hence the reaction rate, is monitored continuously by the TC detector. The experimental data obtained in this study are compared with the predictions of models for char gasification.

  18. Low-temperature catalytic gasification of wet industrial wastes. FY 1991--1992 interim report

    SciTech Connect (OSTI)

    Elliott, D.C.; Neuenschwander, G.G.; Hart, T.R.; Phelps, M.R.; Sealock, L.J. Jr.

    1993-07-01

    A catalytic gasification system operating in a pressurized water environment has been developed and refined at Pacific Northwest Laboratory (PNL) for over 12 years. Initial experiments were aimed at developing kinetics information for steam gasification of biomass in the presence of catalysts. The combined use of alkali and metal catalysts was reported for gasification of biomass and its components at low temperatures (350{degrees}C to 450{degrees}C). From the fundamental research evolved the concept of a pressurized, catalytic gasification system for converting wet biomass feedstocks to fuel gas. Extensive batch reactor testing and limited continuous reactor system (CRS) testing were undertaken in the development of this system under sponsorship of the US Department of Energy. A wide range of biomass feedstocks were tested, and the importance of the nickel metal catalyst was identified. Specific use of this process for treating food processing wastes was also studied. The concept application was further expanded to encompass cleanup of hazardous wastewater streams, and results were reported for batch reactor tests and continuous reactor tests. Ongoing work at PNL focuses on refining the catalyst and scaling the system to long-term industrial needs. The process is licensed as the Thermochemical Environmental Energy System (TEES{reg_sign}) to Onsite*Ofsite, Inc., of Duarte, California. This report is a follow-on to the 1989--90 interim report [Elliott et al. 1991], which reviewed the results of the studies conducted with a fixed-bed, continuous-feed, tubular reactor. The discussion here provides an overview of experiments on the wide range of potential feedstock materials conducted in a batch reactor; development of new catalyst materials; and tests performed in continuous-flow reactors at three scales. The appendices contain the history and background of the process development, as well as more detailed descriptions and results of the recent studies.

  19. Technoeconomic Comparison of Biofuels: Ethanol, Methanol, and Gasoline from Gasification of Woody Residues (Presentation)

    SciTech Connect (OSTI)

    Tarud, J.; Phillips, S.

    2011-08-01

    This presentation provides a technoeconomic comparison of three biofuels - ethanol, methanol, and gasoline - produced by gasification of woody biomass residues. The presentation includes a brief discussion of the three fuels evaluated; discussion of equivalent feedstock and front end processes; discussion of back end processes for each fuel; process comparisons of efficiencies, yields, and water usage; and economic assumptions and results, including a plant gate price (PGP) for each fuel.

  20. Fluid bed gasification – Plasma converter process generating energy from solid waste: Experimental assessment of sulphur species

    SciTech Connect (OSTI)

    Morrin, Shane, E-mail: shane.morrin@ucl.ac.uk [Department of Chemical Engineering, University College London, London WC1E 7JE (United Kingdom); Advanced Plasma Power, Swindon, Wiltshire SN3 4DE (United Kingdom); Lettieri, Paola, E-mail: p.lettieri@ucl.ac.uk [Department of Chemical Engineering, University College London, London WC1E 7JE (United Kingdom); Chapman, Chris, E-mail: chris.chapman@app-uk.com [Advanced Plasma Power, Swindon, Wiltshire SN3 4DE (United Kingdom); Taylor, Richard, E-mail: richard.taylor@app-uk.com [Advanced Plasma Power, Swindon, Wiltshire SN3 4DE (United Kingdom)

    2014-01-15

    Highlights: • We investigate gaseous sulphur species whilst gasifying sulphur-enriched wood pellets. • Experiments performed using a two stage fluid bed gasifier – plasma converter process. • Notable SO{sub 2} and relatively low COS levels were identified. • Oxygen-rich regions of the bed are believed to facilitate SO{sub 2}, with a delayed release. • Gas phase reducing regions above the bed would facilitate more prompt COS generation. - Abstract: Often perceived as a Cinderella material, there is growing appreciation for solid waste as a renewable content thermal process feed. Nonetheless, research on solid waste gasification and sulphur mechanisms in particular is lacking. This paper presents results from two related experiments on a novel two stage gasification process, at demonstration scale, using a sulphur-enriched wood pellet feed. Notable SO{sub 2} and relatively low COS levels (before gas cleaning) were interesting features of the trials, and not normally expected under reducing gasification conditions. Analysis suggests that localised oxygen rich regions within the fluid bed played a role in SO{sub 2}’s generation. The response of COS to sulphur in the feed was quite prompt, whereas SO{sub 2} was more delayed. It is proposed that the bed material sequestered sulphur from the feed, later aiding SO{sub 2} generation. The more reducing gas phase regions above the bed would have facilitated COS – hence its faster response. These results provide a useful insight, with further analysis on a suite of performed experiments underway, along with thermodynamic modelling.

  1. Evaluation of syngas production unit cost of bio-gasification facility using regression analysis techniques

    SciTech Connect (OSTI)

    Deng, Yangyang; Parajuli, Prem B.

    2011-08-10

    Evaluation of economic feasibility of a bio-gasification facility needs understanding of its unit cost under different production capacities. The objective of this study was to evaluate the unit cost of syngas production at capacities from 60 through 1800Nm 3/h using an economic model with three regression analysis techniques (simple regression, reciprocal regression, and log-log regression). The preliminary result of this study showed that reciprocal regression analysis technique had the best fit curve between per unit cost and production capacity, with sum of error squares (SES) lower than 0.001 and coefficient of determination of (R 2) 0.996. The regression analysis techniques determined the minimum unit cost of syngas production for micro-scale bio-gasification facilities of $0.052/Nm 3, under the capacity of 2,880 Nm 3/h. The results of this study suggest that to reduce cost, facilities should run at a high production capacity. In addition, the contribution of this technique could be the new categorical criterion to evaluate micro-scale bio-gasification facility from the perspective of economic analysis.

  2. ECONOMIC EVALUATION OF CO2 SEQUESTRATION TECHNOLOGIES TASK 4, BIOMASS GASIFICATION-BASED PROCESSING

    SciTech Connect (OSTI)

    Martha L. Rollins; Les Reardon; David Nichols; Patrick Lee; Millicent Moore; Mike Crim; Robert Luttrell; Evan Hughes

    2002-04-01

    Biomass derived energy currently accounts for about 3 quads of total primary energy use in the United States. Of this amount, about 0.8 quads are used for power generation. Several biomass energy production technologies exist today which contribute to this energy mix. Biomass combustion technologies have been the dominant source of biomass energy production, both historically and during the past two decades of expansion of modern biomass energy in the U. S. and Europe. As a research and development activity, biomass gasification has usually been the major emphasis as a method of more efficiently utilizing the energy potential of biomass, particularly wood. Numerous biomass gasification technologies exist today in various stages of development. Some are simple systems, while others employ a high degree of integration for maximum energy utilization. The purpose of this study is to conduct a technical and economic comparison of up to three biomass gasification technologies, including the carbon dioxide emissions reduction potential of each. To accomplish this, a literature search was first conducted to determine which technologies were most promising based on a specific set of criteria. During this reporting period, the technical and economic performances of the selected processes were evaluated using computer models and available literature. The results of these evaluations are summarized in this report.

  3. ECONOMIC EVALUATION OF CO2 SEQUESTRATION TECHNOLOGIES TASK 4, BIOMASS GASIFICATION-BASED PROCESSING

    SciTech Connect (OSTI)

    Martha L. Rollins; Les Reardon; David Nichols; Patrick Lee; Millicent Moore; Mike Crim; Robert Luttrell; Evan Hughes

    2002-06-01

    Biomass derived energy currently accounts for about 3 quads of total primary energy use in the United States. Of this amount, about 0.8 quads are used for power generation. Several biomass energy production technologies exist today which contribute to this energy mix. Biomass combustion technologies have been the dominant source of biomass energy production, both historically and during the past two decades of expansion of modern biomass energy in the U. S. and Europe. As a research and development activity, biomass gasification has usually been the major emphasis as a method of more efficiently utilizing the energy potential of biomass, particularly wood. Numerous biomass gasification technologies exist today in various stages of development. Some are simple systems, while others employ a high degree of integration for maximum energy utilization. The purpose of this study is to conduct a technical and economic comparison of up to three biomass gasification technologies, including the carbon dioxide emissions reduction potential of each. To accomplish this, a literature search was first conducted to determine which technologies were most promising based on a specific set of criteria. The technical and economic performances of the selected processes were evaluated using computer models and available literature. Using these results, the carbon sequestration potential of the three technologies was then evaluated. The results of these evaluations are given in this final report.

  4. EARLY ENTRANCE CO-PRODUCTION PLANT - DECENTRALIZED GASIFICATION COGENERATION TRANSPORTATION FUELS AND STEAM FROM AVAILABLE FEEDSTOCKS

    SciTech Connect (OSTI)

    Unknown

    2002-06-01

    Waste Processors Management, Inc. (WMPI), along with its subcontractors entered into a Cooperative Agreement with the USDOE, National Energy Technology Laboratory (NETL) to assess the techno-economic viability of building an Early Entrance Co-Production Plant (EECP) in the US to produce ultra clean Fischer-Tropsch (FT) transportation fuels with either power or steam as the major co-product. The EECP design includes recovery and gasification of low-cost coal waste (culm) from physical coal cleaning operations and will assess blends of the culm with coal or petroleum coke. The project has three phases. Phase 1 is the concept definition and engineering feasibility study to identify areas of technical, environmental and financial risk. Phase II is an experimental testing program designed to validate the coal waste mixture gasification performance. Phase III updates the original EECP design based on results from Phase II, to prepare a preliminary engineering design package and financial plan for obtaining private funding to build a 5,000 barrel per day (BPD) coal gasification/liquefaction plant next to an existing co-generation plant in Gilberton, Schuylkill County, Pennsylvania. The current report is WMPI's fourth quarterly technical progress report. It covers the period performance from January 1, 2002 through March 31, 2002.

  5. EIS-0431: EPA Notice of Availability of Draft Environmental Impact...

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

    Statement Hydrogen Energy California's Integrated Gasification Combined Cycle and Carbon Capture and Sequestration Project, Kern County, CA EPA announces the availability of the...

  6. EIS-0409: Notice of Intent to Prepare an Environmental Impact...

    Broader source: Energy.gov (indexed) [DOE]

    prepare an environmental impact statement for the proposed Kemper County Integrated Gasification Combined Cycle Project in Kemper County, Mississippi to assess the potential...

  7. index | netl.doe.gov

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

    Testing of materials under ideal and realistic process conditions such as those found in coal-fired power plant and integrated gasification combined cycle fuel gas. Performance...

  8. EIS-0431: Amended Notice of Intent to Prepare an Environmental...

    Energy Savers [EERE]

    Involvement Hydrogen Energy California's Integrated Gasification Combined Cycle and Carbon Capture and Sequestration Project, Kern County, CA DOE is publishing this Amended...

  9. EIS-0431: Extension of Public Comment Period | Department of...

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

    Comment Period Hydrogen Energy California's Integrated Gasification Combined Cycle and Carbon Capture and Sequestration Project, CA The U.S. Department of Energy (DOE) published...

  10. EIS-0431: DOE Notice of Availability of Draft Environmental Impact...

    Office of Environmental Management (EM)

    EIS-0431: DOE Notice of Availability of Draft Environmental Impact Statement Hydrogen Energy California's Integrated Gasification Combined Cycle and Carbon Capture and...

  11. EIS-0431: Amended Notice of Intent to Prepare an Environmental...

    Office of Environmental Management (EM)

    Impact Statement and Notice of Potential Floodplain and Wetland Involvement Hydrogen Energy California's Integrated Gasification Combined Cycle and Carbon Capture and...

  12. EIS-0431: EPA Notice of Availability of Draft Environmental Impact...

    Energy Savers [EERE]

    EIS-0431: EPA Notice of Availability of Draft Environmental Impact Statement Hydrogen Energy California's Integrated Gasification Combined Cycle and Carbon Capture and...

  13. EIS-0431: Extension of public comment period; Notice of public...

    Energy Savers [EERE]

    EIS-0431: Extension of public comment period; Notice of public hearing; Correction Hydrogen Energy California's Integrated Gasification Combined Cycle and Carbon Capture and...

  14. baepgig-tampaig | netl.doe.gov

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

    1996) Comprehensive Report to Congress Comprehensive Report to Congress on the Clean Coal Technology Program: Air-Blown Integrated Gasification Combined-Cycle Demonstration...

  15. SYNCHEM feasibility report: Phase 1

    SciTech Connect (OSTI)

    Not Available

    1995-01-01

    Several Czech and US companies have entered into a development agreement for the purposes of determining the technical and economic feasibility and overall financeability of an integrated gasification combined cycle (IGCC) regional energy facility to be located adjacent to the Chemopetrol refinery in Litvinov, Czech Republic. The Project would use a feedstock comprised of coal supplied by Doly a upravny Komorany s.p. (DUK) coal mining company and mined from the Most/Litvinov area together with high sulfur residual oils from the Chemopetrol refinery. When gasified together with oxygen from an Air Products air separation plant, and based on an average yearly consumption of 2,100K metric tons per year of coal (as delivered) and 630K tonnes per year of oil, approximately 11 million normal cubic meters per day of syngas will be produced. At its current projected design capacity, when combusted in two General Electric advanced technology Frame 9FA gas turbines, the Project will produce approximately 690MW of electric power; 250 metric tons/hour of steam for process; and 135 thermal equivalent MW of district heat. The Feasibility Phase efforts described in this report indicate the real possibility for a successful and profitable IGCC Project for the Czech Republic. It is therefore incumbent upon all the Project Participants to review and evaluate the information contained herein such that a go/no-go decision can be reached by early next year.

  16. Changes in char structure during the gasification of a Victorian brown coal in steam and oxygen at 800{degree}C

    SciTech Connect (OSTI)

    Xin Guo; Hui Ling Tay; Shu Zhang; Chun-Zhu Li [Monash University, Vic. (Australia). Department of Chemical Engineering

    2008-11-15

    Char structure is an important factor influencing its reactivity during gasification. This study aims to investigate the changes in char structure during the gasification of brown coal. A Victorian brown coal was gasified in a fluidized-bed/fixed-bed reactor at 800{degree}C in atmospheres containing 15% H{sub 2}O, 2000 ppm O{sub 2}, or 15% H{sub 2}O and 2000 ppm O{sub 2}, respectively. Although the char gasification in 2000 ppm O{sub 2} was mainly rate-limited by the external diffusion of O{sub 2}, the char-H{sub 2}O reaction was mainly rate-limited by the chemical reactions. The structural features of char at different levels of char gasification conversion were examined with FT-Raman spectroscopy. Our results show that the chars from the gasification in the mixture of 2000 ppm O{sub 2} and 15% H{sub 2}O had almost the same features as the chars from the gasification in 15% H{sub 2}O alone when the same levels of char conversion were achieved. Both the thermal decomposition of char and the char gasification reactions could result in changes in char structure during gasification. 29 refs., 5 figs., 1 tab.

  17. Development of an advanced, continuous mild gasification process for the production of co-products (Task 1), Volume 1. Final report

    SciTech Connect (OSTI)

    Knight, R.A.; Gissy, J.L.; Onischak, M.; Babu, S.P.; Carty, R.H.; Duthie, R.G.; Wootten, J.M.

    1991-09-01

    Under US DOE sponsorship, a project team consisting of the Institute of Gas Technology, Peabody Holding Company, and Bechtel Group, Inc. has been developing an advanced, mild gasification process to process all types of coal and to produce solid and condensable liquid co-products that can open new markets for coal. The three and a half year program (September 1987 to June 1991) consisted of investigations in four main areas. These areas are: (1) Literature Survey of Mild Gasification Processes, Co-Product Upgrading and Utilization, and Market Assessment; (2) Mild Gasification Technology Development: Process Research Unit Tests Using Slipstream Sampling; (3) Bench-Scale Char Upgrading Study; (4) Mild Gasification Technology Development: System Integration Studies. In this report, the literature and market assessment of mild gasification processes are discussed.

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

    SciTech Connect (OSTI)

    Lawrence Van Bibber; Charles Thomas; Robert Chaney

    2007-07-15

    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.

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

    SciTech Connect (OSTI)

    Not Available

    1992-02-01

    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.

  20. Catalytic gasification of graphite or carbon. Quarterly report, January 1, 1986-March 31, 1986

    SciTech Connect (OSTI)

    Heinemann, H.

    1986-03-01

    Steam gasification of five chars has been carried out in the presence of a mixture of potassium and nickel oxides as catalyst. The steady state rate of hydrogen production after 60 minutes at 620/sup 0/C is highest for a N. Dakota Husky lignite and is twice as high as the next char, Western Kentucky. The order is N. Dakota > W. Kentucky > Illinois number 6, low temp. > number 6, high temp. > Montana. All chars gasified at a rate at least one order of magnitude greater than graphite.