Sample records for anthracite culm bituminous

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

    SciTech Connect (OSTI)

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

    2007-01-15T23:59:59.000Z

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

  2. Fine Anthracite Coal Washing Using Spirals

    SciTech Connect (OSTI)

    R.P. Killmeyer; P.H. Zandhuis; M.V. Ciocco; W. Weldon; T. West; D. Petrunak

    2001-05-31T23:59:59.000Z

    The spiral performed well in cleaning the coarse 8 x 16 mesh size fraction, as demonstrated by the Ep ranging from 0.091 to 0.177. This is in line with typical spiral performance. In addition, the presence of the coarser size fraction did not significantly affect spiral performance on the typical 16 x 100 mesh fraction, in which the Ep ranged from 0.144 to 0.250. Changes in solids concentration and flow rate did not show a clear correlation with spiral performance. However, for difficult-to-clean coals with high near-gravity material, such as this anthracite, a single-stage spiral cleaning such a wide size fraction may not be able to achieve the clean coal ash and yield specifications required. In the first place, while the performance of the spiral on the coarse 8 x 16 mesh fraction is good with regard to Ep, the cutpoints (SG50s) are high (1.87 to 1.92), which may result in a clean coal with a higher-than-desired ash content. And second, the combination of the spiral's higher overall cutpoint (1.80) with the high near-gravity anthracite results in significant misplaced material that increases the clean coal ash error. In a case such as this, one solution may be to reclean the clean coal and middlings from the first-stage spiral in a second stage spiral.

  3. Bituminous pavement recycling Aravind K. and Animesh Das

    E-Print Network [OSTI]

    Das, Animesh

    Bituminous pavement recycling Aravind K. and Animesh Das Department of Civil Engineering IIT Kanpur Introduction The bituminous pavement rehabilitation alternatives are mainly overlaying, recycling and reconstruction. In the recycling process the material from deteriorated pavement, known as reclaimed asphalt

  4. Assessment of underground coal gasification in bituminous coals: catalog of bituminous coals and site selection. Appendix A. National coal resource data system: Ecoal, Wcoal, and Bmalyt. Final report, Phase I. [Bituminous coal; by state; coal seam depth and thickness; identification

    SciTech Connect (OSTI)

    None

    1982-01-31T23:59:59.000Z

    Appendix A is a catalog of the bituminous coal in 29 states of the contiguous United States which contain identified bituminous coal resources.

  5. Incinerator residue in bituminous base construction

    E-Print Network [OSTI]

    Haynes, Joseph Anthony

    1975-01-01T23:59:59.000Z

    for use of the material in a bituminous base. Preliminary investigation on the optimum mix design included Hveem stability, Marshall stability and Durability tests, A test section consisting of the experimental hot-mixed pavement, littercrete, and a... for flexural fatigue tests, Hveem and Marshall stabilities, thermal expansion, direct tension, splitting tensile and Schmidt tests. Four in. (10. 2 cm. ) diameter cores were taken after compaction (before traffic) and after six months in service. Samples...

  6. Updated Costs (June 2011 Basis) for Selected Bituminous Baseline...

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

    Date:2011-Oct-17 Project: Bituminous Baseline Study Case: Case 1 GEE Radiant IGCC wo CO2 Plant Size: 622.1 MW,net Estimate Type: Conceptual Cost Base (Jun) 2011 (x1000) Acct...

  7. Evaluation of an alternative bituminous material as a soil stabilizer 

    E-Print Network [OSTI]

    Kim, Yong-Rak

    1999-01-01T23:59:59.000Z

    characteristics as an alternative bituminous soil stabilizer in terms of replacing the cutback asphalts because the PRB material has been proved an environmentally safe material. Based on various laboratory tests, including an unconfined compressive strength test...

  8. 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)

    2009-04-15T23:59:59.000Z

    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.

  9. Process for removing pyritic sulfur from bituminous coals

    DOE Patents [OSTI]

    Pawlak, Wanda (Edmonton, CA); Janiak, Jerzy S. (Edmonton, CA); Turak, Ali A. (Edmonton, CA); Ignasiak, Boleslaw L. (Edmonton, CA)

    1990-01-01T23:59:59.000Z

    A process is provided for removing pyritic sulfur and lowering ash content of bituminous coals by grinding the feed coal, subjecting it to micro-agglomeration with a bridging liquid containing heavy oil, separating the microagglomerates and separating them to a water wash to remove suspended pyritic sulfur. In one embodiment the coal is subjected to a second micro-agglomeration step.

  10. Coal desulfurization in a rotary kiln combustor. Final report, March 15, 1990--July 31, 1991

    SciTech Connect (OSTI)

    Cobb, J.T. Jr.

    1992-09-11T23:59:59.000Z

    The purpose of this project was to demonstrate the combustion of coal and coal wastes in a rotary kiln reactor with limestone addition for sulfur control. The rationale for the project was the perception that rotary systems could bring several advantages to combustion of these fuels, and may thus offer an alternative to fluid-bed boilers. Towards this end, an existing wood pyrolysis kiln (the Humphrey Charcoal kiln) was to be suitably refurbished and retrofitted with a specially designed version of a patented air distributor provided by Universal Energy, Inc. (UEI). As the project progressed beyond the initial stages, a number of issues were raised regarding the feasibility and the possible advantages of burning coals in a rotary kiln combustor and, in particular, the suitability of the Humphrey Charcoal kiln as a combustor. Instead, an opportunity arose to conduct combustion tests in the PEDCO Rotary Cascading-Bed Boiler (RCBB) commercial demonstration unit at the North American Rayon CO. (NARCO) in Elizabethton, TN. The tests focused on anthracite culm and had two objectives: (a) determine the feasibility of burning anthracite culms in a rotary kiln boiler and (b) obtain input for any further work involving the Humphrey Charcoal kiln combustor. A number of tests were conducted at the PEDCO unit. The last one was conducted on anthracite culm procured directly from the feed bin of a commercial circulating fluid-bed boiler. The results were disappointing; it was difficult to maintain sustained combustion even when large quantities of supplemental fuel were used. Combustion efficiency was poor, around 60 percent. The results suggest that the rotary kiln boiler, as designed, is ill-suited with respect to low-grade, hard to burn solid fuels, such as anthracite culm. Indeed, data from combustion of bituminous coal in the PEDCO unit suggest that with respect to coal in general, the rotary kiln boiler appears inferior to the circulating fluid bed boiler.

  11. Coal desulfurization in a rotary kiln combustor

    SciTech Connect (OSTI)

    Cobb, J.T. Jr.

    1992-09-11T23:59:59.000Z

    The purpose of this project was to demonstrate the combustion of coal and coal wastes in a rotary kiln reactor with limestone addition for sulfur control. The rationale for the project was the perception that rotary systems could bring several advantages to combustion of these fuels, and may thus offer an alternative to fluid-bed boilers. Towards this end, an existing wood pyrolysis kiln (the Humphrey Charcoal kiln) was to be suitably refurbished and retrofitted with a specially designed version of a patented air distributor provided by Universal Energy, Inc. (UEI). As the project progressed beyond the initial stages, a number of issues were raised regarding the feasibility and the possible advantages of burning coals in a rotary kiln combustor and, in particular, the suitability of the Humphrey Charcoal kiln as a combustor. Instead, an opportunity arose to conduct combustion tests in the PEDCO Rotary Cascading-Bed Boiler (RCBB) commercial demonstration unit at the North American Rayon CO. (NARCO) in Elizabethton, TN. The tests focused on anthracite culm and had two objectives: (a) determine the feasibility of burning anthracite culms in a rotary kiln boiler and (b) obtain input for any further work involving the Humphrey Charcoal kiln combustor. A number of tests were conducted at the PEDCO unit. The last one was conducted on anthracite culm procured directly from the feed bin of a commercial circulating fluid-bed boiler. The results were disappointing; it was difficult to maintain sustained combustion even when large quantities of supplemental fuel were used. Combustion efficiency was poor, around 60 percent. The results suggest that the rotary kiln boiler, as designed, is ill-suited with respect to low-grade, hard to burn solid fuels, such as anthracite culm. Indeed, data from combustion of bituminous coal in the PEDCO unit suggest that with respect to coal in general, the rotary kiln boiler appears inferior to the circulating fluid bed boiler.

  12. Investigation of the combustion characteristics of Zonguldak bituminous coal using DTA and DTG

    SciTech Connect (OSTI)

    Haykiri-Acma, H.; Yaman, S.; Kucukbayrak, S.; Okutan, H. [Istanbul Technical University, Istanbul (Turkey). Dept. of Chemical Engineering

    2006-06-21T23:59:59.000Z

    Combustion characteristics of coking, semicoking, and noncoking Turkish bituminous coal samples from Zonguldak basin were investigated applying differential thermal analysis (DTA) and differential thermogravimetry (DTG) techniques. Results were compared with that of the coke from Zonguldak bituminous coal, a Turkish lignite sample from Soma, and a Siberian bituminous coal sample. The thermal data from both techniques showed some differences depending on the proximate analyses of the samples. Noncombustible components of the volatile matter led to important changes in thermal behavior. The data front both methods were, evaluated jointly, and some thermal properties were interpreted considering these methods in a complementary combination.

  13. INTERACTION OF A SUB-BITUMINOUS COAL WITH A STRONG ACID AND A STRONG BASE

    E-Print Network [OSTI]

    Seth, M.

    2010-01-01T23:59:59.000Z

    indicate that coal-derived asphaltenes exhibit an acid-baseanyone functional group is asphaltenes is amphoteric. Theseto oil, and 31.6% to asphaltenes) of a bituminous coal when

  14. Influence of the degree of metamorphism and reduction of the anthracites of the Donbas on the properties of the products of their thermal treatment

    SciTech Connect (OSTI)

    Eremin, I.V.; Ivanov, V.P.; Maloletnev, A.S.; Danilova, R.A.

    1981-01-01T23:59:59.000Z

    In the reported experiments, the influence of high-temperature treatment on the structure and properties of anthracites of the Donbas of different degrees of metamorphism and reduction has been studied. It has been shown that on thermal treatment up to 1250/degree/C feebly metamorphosed anthracites achieve structural orderedness to a considerable degree and their use in the electrode industry is possible. The predominating influence of the degree of metamorphism of the initial anthracites on the physicochemical properties of the products of their thermal treatment, as compared with that of the degree of reduction, has been established. 5 refs.

  15. Physical and mechanical properties of bituminous mixtures containing oil shales

    SciTech Connect (OSTI)

    Katamine, N.M.

    2000-04-01T23:59:59.000Z

    Rutting of bituminous surfaces on the Jordanian highways is a recurring problem. Highway authorities are exploring the use of extracted shale oil and oil shale fillers, which are abundant in Jordan. The main objectives of this research are to investigate the rheological properties of shale oil binders (conventional binder with various percentages of shale oil), in comparison with a conventional binder, and to investigate the ability of mixes to resist deformation. The latter is done by considering three wearing course mixes containing three different samples of oil shale fillers--which contained three different oil percentages--together with a standard mixture containing limestone filler. The Marshall design method and the immersion wheel tracking machine were adopted. It was concluded that the shale oil binders displayed inconsistent physical properties and therefore should be treated before being used. The oil shale fillers have provided mixes with higher ability to resist deformation than the standard mix, as measured by the Marshall quotients and the wheel tracking machine. The higher the percentages of oil in the oil shale fillers, the lower the ability of the mixes to resist deformation.

  16. China Energy Primer

    E-Print Network [OSTI]

    Ni, Chun Chun

    2010-01-01T23:59:59.000Z

    anthracite, and lignite and brown coal make up the remainingCoal Anthracite Lignite and Brown Coal Source: China Energyof Coal in 2006 Lignite and Brown Coal Anthracite Bituminous

  17. Surface Properties of Photo-Oxidized Bituminous Coals: Final report

    SciTech Connect (OSTI)

    NONE

    1998-09-01T23:59:59.000Z

    Natural weathering has a detrimental effect on the hydrophobic nature of coal, which in turn can influence clean-coal recovery during flotation. Few techniques are available that can establish the quality of coal surfaces and that have a short analysis time to provide input for process control. Luminescence emissions which can be quantified with an optical microscope and photometer system, are measurably influenced by degree of weathering as well as by mild storage deterioration. In addition, it has been shown that when vitrinite is irradiated with a relatively high intensity flux of violet- or ultraviolet- light in the presence of air, photo-oxidation of the surface occurs. The combination of measuring the change in luminescence emission intensity with degree of surface oxidation provided the impetus for the current investigation. The principal aim of this research was to determine whether clear correlations could be established among surface oxygen functionality, hydrophobicity induced by photo-oxidation, and measurements of luminescence intensity and alteration. If successful, the project would result in quantitative luminescence techniques based on optical microscopy that would provide a measure of the changes in surface properties as a function of oxidation and relate them to coal cleanability. Two analytical techniques were designed to achieve these goals. Polished surfaces of vitrain bands or a narrow size fraction of powdered vitrain concentrates were photo-oxidized using violet or ultraviolet light fluxes and then changes in surface properties and chemistry were measured using a variety of near-surface analytical techniques. Results from this investigation demonstrate that quantitative luminescence intensity measurements can be performed on fracture surfaces of bituminous rank coals (vitrains) and that the data obtained do reveal significant variations depending upon the level of surface oxidation. Photo-oxidation induced by violet or ultraviolet light fluxes does result in a progressive and significant increase in the amount of near-surface oxygen concentration at about the same level regardless of bituminous coal rank. These incremental changes in oxygen concentration appear to lower the hydrophobicity as shown by contact angle measurements on polished surfaces. Although this influence diminished as coal rank increased, the level of oxygen uptake was about the same, suggesting that the type of oxygen functionality formed during oxidation may be of great importance in modifying surface hydrophobicity. Changes in functional-group chemistry, measured by a variety of near-surface techniques, showed a general increase in the concentration of carbonyl-containing groups while those of CH{sub 2} groups decreased. All of these observations follow the trends observed in previous investigations of naturally weathered coals. The photo-oxidation technique also resulted in the development of phenolic, ester and anhydride moieties instead of the expected emplacement of carboxylic acid groups which are normally associated with naturally weathered coals. The importance of this observation is that esters and anhydrides would result in a more hydrophobic surface in comparison to the more hydrophilic surface resulting from acid functionality. This observation is consistent with the results of film flotation of UV-irradiated powdered vitrain in which floatability was generally observed to increase with increasing photo- oxidation.

  18. adaptation and use of bituminous materials: Topics by E-print...

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

    adaptation and use of bituminous materials First Page Previous Page 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 Next Page Last Page Topic Index 1...

  19. Design principles for design of bituminous pavement with stabilized/ cemented layer

    E-Print Network [OSTI]

    Das, Animesh

    Design principles for design of bituminous pavement with stabilized/ cemented layer Animesh Das1 Introduction A pavement designer wishes to design a pavement structure which is reliable and cost effective. Various materials have been used for pavement construction so as to economize the design. Depleting

  20. Principles of bituminous pavement design and the recent trends Animesh Das1

    E-Print Network [OSTI]

    Das, Animesh

    Principles of bituminous pavement design and the recent trends Animesh Das1 Introduction Understanding pavement behaviour is a complex task. This complexity is due to the complex response of the individual pavement materials which is very difficult to predict. In a typical pavement a number

  1. Assessment of underground coal gasification in bituminous coals. Volume I. Executive summary. Final report

    SciTech Connect (OSTI)

    None

    1981-01-01T23:59:59.000Z

    This report describes the bituminous coal resources of the United States, identifies those resources which are potentially amenable to Underground Coal Gasification (UCG), identifies products and markets in the vicinity of selected target areas, identifies UCG concepts, describes the state of the art of UCG in bituminous coal, and presents three R and D programs for development of the technology to the point of commercial viability. Of the 670 billion tons of bituminous coal remaining in-place as identified by the National Coal Data System, 32.2 billion tons or 4.8% of the total are potentially amenable to UCG technology. The identified amenable resource was located in ten states: Alabama, Colorado, Illinois, Kentucky, New Mexico, Ohio, Oklahoma, Utah, Virginia, and West Virginia. The principal criteria which eliminated 87.3% of the resource was the minimum thickness (42 inches). Three R and D programs were developed using three different concepts at two different sites. Open Borehole, Hydraulic Fracture, and Electrolinking concepts were developed. The total program costs for each concept were not significantly different. The study concludes that much of the historical information based on UCG in bituminous coals is not usable due to the poor siting of the early field tests and a lack of adequate diagnostic equipment. This information gap requires that much of the early work be redone in view of the much improved understanding of the role of geology and hydrology in the process and the recent development of analytical tools and methods.

  2. JV Task 126 - Mercury Control Technologies for Electric Utilities Burning Bituminous Coal

    SciTech Connect (OSTI)

    Jason Laumb; John Kay; Michael Jones; Brandon Pavlish; Nicholas Lentz; Donald McCollor; Kevin Galbreath

    2009-03-29T23:59:59.000Z

    The EERC developed an applied research consortium project to test cost-effective mercury (Hg) control technologies for utilities burning bituminous coals. The project goal was to test innovative Hg control technologies that have the potential to reduce Hg emissions from bituminous coal-fired power plants by {ge}90% at costs of one-half to three-quarters of current estimates for activated carbon injection (ACI). Hg control technology evaluations were performed using the EERC's combustion test facility (CTF). The CTF was fired on pulverized bituminous coals at 550,000 Btu/hr (580 MJ/hr). The CTF was configured with the following air pollution control devices (APCDs): selective catalytic reduction (SCR) unit, electrostatic precipitator (ESP), and wet flue gas desulfurization system (WFDS). The Hg control technologies investigated as part of this project included ACI (three Norit Americas, Inc., and eleven Envergex sorbents), elemental mercury (Hg{sup 0}) oxidation catalysts (i.e., the noble metals in Hitachi Zosen, Cormetech, and Hitachi SCR catalysts), sorbent enhancement additives (SEAs) (a proprietary EERC additive, trona, and limestone), and blending with a Powder River Basin (PRB) subbituminous coal. These Hg control technologies were evaluated separately, and many were also tested in combination.

  3. Fixed-bed gasification research using US coals. Volume 2. Gasification of Jetson bituminous coal

    SciTech Connect (OSTI)

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

    1985-03-31T23:59:59.000Z

    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 cooperative 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 describes the gasification testing of Jetson bituminous coal. This Western Kentucky coal was gasified during an initial 8-day and subsequent 5-day period. Material flows and compositions are reported along with material and energy balances. Operational experience is also described. 4 refs., 24 figs., 17 tabs.

  4. Fixed-bed gasification research using US coals. Volume 9. Gasification of Elkhorn bituminous coal

    SciTech Connect (OSTI)

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

    1985-05-01T23:59:59.000Z

    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 cooperative 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 ninth volume in a series of reports describing the atmospheric pressure, fixed-bed gasification of US coals. This specific report describes the gasification of Elkhorn bituminous coal. The period of gasificastion test was September 13 to October 12, 1983. 9 refs., 24 figs., 35 tabs.

  5. Fixed-bed gasification research using US coals. Volume 7. Gasification of Piney Tipple bituminous coal

    SciTech Connect (OSTI)

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

    1985-05-01T23:59:59.000Z

    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 cooperative 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 seventh volume in a series of reports describing the atmospheric pressure, fixed-bed gasification of US coals. This specific report describes the gasification of Piney Tipple bituminous coal. The period of the gasification test was July 18-24, 1983. 6 refs., 20 figs., 17 tabs.

  6. Applicability of beneficiated sub-bituminous coal in a phase II (AAA), deregulated electrical power market

    SciTech Connect (OSTI)

    Loreman, M.R.; McCord, T.G.

    1998-07-01T23:59:59.000Z

    Utilities have adapted to an operating environment increasingly constrained by emissions requirements, e.g., Phase 1 of the US 1992 Clean Air Act Amendments (CAAA), and by competitive economic conditions triggered in the present early stages of utility deregulation. Low capacity utilization, while not desirable, has been a factor in the ability of utilities to adapt. The method of choice for many Midwestern utilities has been to switch to sub-bituminous coals from the Powder River Basin (PRB) with their low sulfur and low delivered cost. However, the derates that have been experienced by switching to PRB coal in order to adapt to present regulations will become a negative factor as capacity utilization increases. Beneficiation of sub-bituminous coals would provide one option for utilities to eliminate derates and thereby increases capacity utilization, while maintaining low SO{sub 2} emissions. An optimum product can be delivered where just enough upgraded material could be blended with run-of-mine PRB coal at the beneficiation plant/mine facility to allow desired power plant performance at the lowest cost. Two plants, large enough to provide trainload quantities of unblended upgraded product, are in operation. A third plant is under construction. Progress continues in demonstrating the ability to transport and use these materials in utility boilers. This paper reviews the results of full-scale burns of the products from one of these plants, including shipments of both blended and unblended material. Technically, burns have been completed in boiler types including both pulverized-fired and cyclone-fired units. Stable flames are produced with NO{sub x} emissions lower than or comparable to the baseline blend. Opacity results are consistent with those of the source coal used for upgrading. Also considered are the economics of increased capacity utilization using these beneficiated PRB fuels in blends with PRB coal.

  7. Operation of the NRCh constriction of boilers in 300 MW energy units during combustion of anthracite dust

    SciTech Connect (OSTI)

    Kaminskii, V.P.; Mironov, S.N.

    1982-03-01T23:59:59.000Z

    Operation of the furnace constriction of boilers in 300 MW units during combustion of anthracite dust with liquid slag removal now requires special attention on the part of both operating personnel at thermal power plants and designers. The reason behind this is charring of the studs and carborundum mass on the roof portion of the constriction with subsequent exposure of the tubes; external high-temperature corrosion of the tubes on the roof portion and on the upper incline of the constriction with subsequent tapering of the tube walls to 1.5 mm and their breaking; the presence of corrosion-fatigue destruction of the tube walls in the upper incline of the constriction with formation of scale, transverse deep grooves and fissures on the front side of the tubes. Overall, at the present time the constriction is a point of failure that requires intensified control and greater repair costs to replace damaged sections of the heating surfaces. In conjunction with this, complex analysis of operation of the constriction has been carried out.

  8. China's Coal: Demand, Constraints, and Externalities

    E-Print Network [OSTI]

    Aden, Nathaniel

    2010-01-01T23:59:59.000Z

    anthracite, lignite and brown coal. While bituminous coal isproduction of lignite and brown coal, which also increasedtonnes. Whereas lignite and brown coal accounted for 4% of

  9. Pore size distribution and accessible pore size distribution in bituminous coals

    SciTech Connect (OSTI)

    Sakurovs, Richard [ORNL; He, Lilin [ORNL; Melnichenko, Yuri B [ORNL; Radlinski, Andrzej Pawell [ORNL; Blach, Tomasz P [ORNL

    2012-01-01T23:59:59.000Z

    The porosity and pore size distribution of coals determine many of their properties, from gas release to their behavior on carbonization, and yet most methods of determining pore size distribution can only examine a restricted size range. Even then, only accessible pores can be investigated with these methods. Small-angle neutron scattering (SANS) and ultra small-angle neutron scattering (USANS) are increasingly used to characterize the size distribution of all of the pores non-destructively. Here we have used USANS/SANS to examine 24 well-characterized bituminous and subbituminous coals: three from the eastern US, two from Poland, one from New Zealand and the rest from the Sydney and Bowen Basins in Eastern Australia, and determined the relationships of the scattering intensity corresponding to different pore sizes with other coal properties. The range of pore radii examinable with these techniques is 2.5 nm to 7 {micro}m. We confirm that there is a wide range of pore sizes in coal. The pore size distribution was found to be strongly affected by both rank and type (expressed as either hydrogen or vitrinite content) in the size range 250 nm to 7 {micro}m and 5 to 10 nm, but weakly in intermediate regions. The results suggest that different mechanisms control coal porosity on different scales. Contrast-matching USANS and SANS were also used to determine the size distribution of the fraction of the pores in these coals that are inaccessible to deuterated methane, CD{sub 4}, at ambient temperature. In some coals most of the small ({approx} 10 nm) pores were found to be inaccessible to CD{sub 4} on the time scale of the measurement ({approx} 30 min - 16 h). This inaccessibility suggests that in these coals a considerable fraction of inherent methane may be trapped for extended periods of time, thus reducing the effectiveness of methane release from (or sorption by) these coals. Although the number of small pores was less in higher rank coals, the fraction of total pores that was inaccessible was not rank dependent. In the Australian coals, at the 10 nm to 50 nm size scales the pores in inertinites appeared to be completely accessible to CD{sub 4}, whereas the pores in the vitrinite were about 75% inaccessible. Unlike the results for total porosity that showed no regional effects on relationships between porosity and coal properties, clear regional differences in the relationships between fraction of closed porosity and coal properties were found. The 10 to 50 nm-sized pores of inertinites of the US and Polish coals examined appeared less accessible to methane than those of the inertinites of Australian coals. This difference in pore accessibility in inertinites may explain why empirical relationships between fluidity and coking properties developed using Carboniferous coals do not apply to Australian coals.

  10. Speciation of chromium in feed coals and ash byproducts from Canadian power plants burning subbituminous and bituminous coals

    SciTech Connect (OSTI)

    Fariborz Goodarzi; Frank E. Huggins [Geological Survey of Canada-Calgary Division, Calgary, AB (Canada)

    2005-12-01T23:59:59.000Z

    The chromium species in the feed coals and ash byproducts from seven Canadian coal-fired power plants were examined using Cr X-ray absorption near-edge spectroscopy. Chromium in the Canadian feed coals is always found as Cr{sup 3+} but generally has a dual occurrence, as Cr{sup 3+} is distributed to varying degrees between the clay mineral illite and a poorly crystallized chromium oxyhydroxide phase associated with the organic fraction. In two subbituminous feed coals from Alberta, chromium is present largely as Cr{sup 3+}/illite, whereas in two other such coals, it is present predominantly as CrOOH. Chromium in a low-sulfur bituminous feed coal from Alberta is found mostly as Cr{sup 3+}/illite, whereas for feed coals from Nova Scotia with high sulfur contents, chromium is distributed between both Cr{sup 3+}/illite and CrOOH. Very little chromium was found in the limestone used in a fluidized-bed combustor. The chromium species in most bottom ash samples from all seven combustion units is predominantly, if not entirely, Cr{sup 3+} associated with aluminosilicate phases. Chromium speciation for subbituminous electrostatic precipitator fly ash is mostly Cr{sup 3+}, but in some cases, it is slightly lessand varies by sampling location at the plant. Chromium in fly ash from the combustion of bituminous feed coals is predominantlyCr{sup 3+}. A unique species of chromium found in one feed coal and an unrelated fly ash is metallic chromium, similar to that in stainless steel. The occurrence of this form of chromium in these materials indicates contamination from machinery, such as the coal milling machine or possibly wearing down of stainless steel parts by the coal or ash. The observation of this unexpected contamination demonstrates the power and usefulness of X-ray absorption fine-structure spectroscopy for speciation determination. 35 refs., 6 figs., 4 tabs.

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

    SciTech Connect (OSTI)

    None

    1982-01-31T23:59:59.000Z

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

  12. Catalytic Two-Stage Liquefaction (CTSL{trademark}) process bench studies and PDU scale-up with sub-bituminous coal. Final report

    SciTech Connect (OSTI)

    Comolli, A.G.; Johanson, E.S.; Karolkiewicz, W.F.; Lee, L.K.T.; Stalzer, R.H.; Smith, T.O.

    1993-03-01T23:59:59.000Z

    Reported are the details and results of Laboratory and Bench-Scale experiments using sub-bituminous coal conducted at Hydrocarbon Research, Inc., under DOE Contract No. DE-AC22-88PC88818 during the period October 1, 1988 to December 31, 1992. The work described is primarily concerned with testing of the baseline Catalytic Two-Stage Liquefaction (CTSL{trademark}) process with comparisons with other two stage process configurations, catalyst evaluations and unit operations such as solid separation, pretreatments, on-line hydrotreating, and an examination of new concepts. In the overall program, three coals were evaluated, bituminous Illinois No. 6, Burning Star and sub-bituminous Wyoming Black Thunder and New Mexico McKinley Mine seams. The results from a total of 16 bench-scale runs are reported and analyzed in detail. The runs (experiments) concern process variables, variable reactor volumes, catalysts (both supported, dispersed and rejuvenated), coal cleaned by agglomeration, hot slurry treatments, reactor sequence, on-line hydrotreating, dispersed catalyst with pretreatment reactors and CO{sub 2}/coal effects. The tests involving the Wyoming and New Mexico Coals are reported herein, and the tests involving the Illinois coal are described in Topical Report No. 2. On a laboratory scale, microautoclave tests evaluating coal, start-up oils, catalysts, thermal treatment, CO{sub 2} addition and sulfur compound effects were conducted and reported in Topical Report No. 3. Other microautoclave tests are described in the Bench Run sections to which they refer such as: rejuvenated catalyst, coker liquids and cleaned coals. The microautoclave tests conducted for modelling the CTSL{trademark} process are described in the CTSL{trademark} Modelling section of Topical Report No. 3 under this contract.

  13. United States - U.S. Energy Information Administration (EIA)

    Annual Energy Outlook 2013 [U.S. Energy Information Administration (EIA)]

    of primary coal (includes anthracite, bituminous, lignite, and for Estonia, oil shale). 829.7000 , 823.7750 , 838.1120 , 782.0910 , 895.9208 , 883.6381 , 890.3147 ,...

  14. Investigation of mercury transformation by HBr addition in a slipstream facility with real flue gas atmospheres of bituminous coal and Powder River Basin Coal

    SciTech Connect (OSTI)

    Yan Cao; Quanhai Wang; Chien-wei Chen; Bobby Chen; Martin Cohron; Yi-chuan Tseng; Cheng-chung Chiu; Paul Chu; Wei-Ping Pan [Western Kentucky University, Bowling Green, KY (United States). Institute for Combustion Science and Environmental Technology

    2007-09-15T23:59:59.000Z

    An investigation of speciated mercury transformation with the addition of hydrogen bromide (HBr) at elevated temperatures was conducted in a slipstream reactor with real flue gas atmospheres. Test results indicated that adding HBr into the flue gas at several parts per million strongly impacted the mercury oxidation and adsorption, which were dependent upon temperature ranges. Higher temperatures (in the range of 300-350 C) promoted mercury oxidation by HBr addition but did not promote mercury adsorption. Lower temperatures (in a range of 150-200 C) enhanced mercury adsorption on the fly ash by adding HBr. Test results also verified effects of flue gas atmospheres on the mercury oxidation by the addition of HBr, which included concentrations of chlorine and sulfur in the flue gas. Chlorine species seemed to be involved in the competition with bromine species in the mercury oxidation process. With the addition of HBr at 3 ppm at a temperature of about 330 C, the additional mercury oxidation could be reached by about 55% in a flue gas atmosphere by burning PRB coal in the flue gas and by about 20% in a flue gas by burning bituminous coal. These are both greater than the maximum gaseous HgBr2 percentage in the flue gas (35% for PRB coal and 5% for bituminous coal) by thermodynamic equilibrium analysis predictions under the same conditions. This disagreement may indicate a greater complexity of mercury oxidation mechanisms by the addition of HBr. It is possible that bromine species promote activated chlorine species generation in the flue gas, where the kinetics of elemental mercury oxidation were enhanced. However, SO{sub 2} in the flue gas may involve the consumption of the available activated chlorine species. Thus, the higher mercury oxidation rate by adding bromine under the flue gas by burning PRB coal may be associated with its lower SO{sub 2} concentration in the flue gas. 39 refs., 8 figs., 4 tabs.

  15. Mercury emissions during cofiring of sub-bituminous coal and biomass (chicken waste, wood, coffee residue, and tobacco stalk) in a laboratory-scale fluidized bed combustor

    SciTech Connect (OSTI)

    Yan Cao; Hongcang Zhou; Junjie Fan; Houyin Zhao; Tuo Zhou; Pauline Hack; Chia-Chun Chan; Jian-Chang Liou; Wei-ping Pan [Western Kentucky University (WKU), Bowling Green, KY (USA). Institute for Combustion Science and Environmental Technology (ICSET)

    2008-12-15T23:59:59.000Z

    Four types of biomass (chicken waste, wood pellets, coffee residue, and tobacco stalks) were cofired at 30 wt % with a U.S. sub-bituminous coal (Powder River Basin Coal) in a laboratory-scale fluidized bed combustor. A cyclone, followed by a quartz filter, was used for fly ash removal during tests. The temperatures of the cyclone and filter were controlled at 250 and 150{sup o}C, respectively. Mercury speciation and emissions during cofiring were investigated using a semicontinuous mercury monitor, which was certified using ASTM standard Ontario Hydra Method. Test results indicated mercury emissions were strongly correlative to the gaseous chlorine concentrations, but not necessarily correlative to the chlorine contents in cofiring fuels. Mercury emissions could be reduced by 35% during firing of sub-bituminous coal using only a quartz filter. Cofiring high-chlorine fuel, such as chicken waste (Cl = 22340 wppm), could largely reduce mercury emissions by over 80%. When low-chlorine biomass, such as wood pellets (Cl = 132 wppm) and coffee residue (Cl = 134 wppm), is cofired, mercury emissions could only be reduced by about 50%. Cofiring tobacco stalks with higher chlorine content (Cl = 4237 wppm) did not significantly reduce mercury emissions. Gaseous speciated mercury in flue gas after a quartz filter indicated the occurrence of about 50% of total gaseous mercury to be the elemental mercury for cofiring chicken waste, but occurrence of above 90% of the elemental mercury for all other cases. Both the higher content of alkali metal oxides or alkali earth metal oxides in tested biomass and the occurrence of temperatures lower than 650{sup o}C in the upper part of the fluidized bed combustor seemed to be responsible for the reduction of gaseous chlorine and, consequently, limited mercury emissions reduction during cofiring. 36 refs., 3 figs. 1 tab.

  16. Preconversion processing of bituminous coals: New directions to improved direct catalytic coal liquefaction. Final report, September 20, 1991--September 19, 1993

    SciTech Connect (OSTI)

    Not Available

    1993-09-01T23:59:59.000Z

    One of the main goals for competitive coal liquefaction is to decrease gas yields to reduce hydrogen consumption. Complexing this element as methane and ethane decreases process efficiently and is less cost effective. To decrease the gas yield and increase the liquid yield, an effective preconversion process has been explored on the basis of the physically associated molecular nature of coal. Activities have been focused on two issues: (1) maximizing the dissolution of associated coal and (2) defining the different reactivity associated with a wide molecular weight distribution. Two-step soaking at 350{degrees}C and 400{degrees}C in a recycle oil was found to be very effective for coal solubilization. No additional chemicals, catalysts, and hydrogen are required for this preconversion process. High-volatile bituminous coals tested before liquefaction showed 80--90% conversion with 50--55% oil yields. New preconversion steps suggested are as follows: (1) dissolution of coal with two-step high-temperature soaking, (2) separation into oil and heavy fractions of dissolved coal with vacuum distillation, and (3) selective liquefaction of the separated heavy fractions under relatively mild conditions. Laboratory scale tests of the proposed procedure mode using a small autoclave showed a 30% increase in the oil yield with a 15--20% decrease in the gas yield. This batch operation projects a substantial reduction in the ultimate cost of coal liquefaction.

  17. Evaluation of Control Strategies to Effectively Meet 70-90% Mercury Reduction on an Eastern Bituminous Coal Cyclone Boiler with SCR

    SciTech Connect (OSTI)

    Tom Campbell

    2008-12-31T23:59:59.000Z

    This is the final site report for testing conducted at Public Service of New Hampshire's (PSNH) Merrimack Unit 2 (MK2). This project was funded through the DOE/NETL Innovations for Existing Plants program. It was a Phase III project with the goal to develop mercury control technologies that can achieve 50-70% mercury capture at costs 25-50% less than baseline estimates of $50,000-$70,000/lb of mercury removed. While results from testing at Merrimack indicate that the DOE goal was partially achieved, further improvements in the process are recommended. Merrimack burned a test blend of eastern bituminous and Venezuelan coals, for a target coal sulfur content of 1.2%, in its 335-MW Unit 2. The blend ratio is approximately a 50/50 split between the two coals. Various sorbent injection tests were conducted on the flue gas stream either in front of the air preheater (APH) or in between the two in-series ESPs. Initial mercury control evaluations indicated that, without SO3 control, the sorbent concentration required to achieve 50% control would not be feasible, either economically or within constraints specific to the maximum reasonable particle loading to the ESP. Subsequently, with SO{sub 3} control via trona injection upstream of the APH, economically feasible mercury removal rates could be achieved with PAC injection, excepting balance-of-plant concerns. The results are summarized along with the impacts of the dual injection process on the air heater, ESP operation, and particulate emissions.

  18. Impacts of halogen additions on mercury oxidation, in a slipstream selective catalyst reduction (SCR), reactor when burning sub-bituminous coal

    SciTech Connect (OSTI)

    Yan Cao; Zhengyang Gao; Jiashun Zhu; Quanhai Wang; Yaji Huang; Chengchung Chiu; Bruce Parker; Paul Chu; Wei-ping Pan [Western Kentucky University (WKU), Bowling Green, KY (United States). Institute for Combustion Science and Environmental Technology (ICSET)

    2008-01-01T23:59:59.000Z

    This paper presents a comparison of impacts of halogen species on the elemental mercury (Hg(0)) oxidation in a real coal-derived flue gas atmosphere. It is reported there is a higher percentage of Hg(0) in the flue gas when burning sub-bituminous coal (herein Powder River Basin (PRB) coal) and lignite, even with the use of selective catalytic reduction (SCR). The higher Hg(0) concentration in the flue gas makes it difficult to use the wet-FGD process for the mercury emission control in coal-fired utility boilers. Investigation of enhanced Hg(0) oxidation by addition of hydrogen halogens (HF, HCl, HBr, and HI) was conducted in a slipstream reactor with and without SCR catalysts when burning PRB coal. Two commercial SCR catalysts were evaluated. SCR catalyst no. 1 showed higher efficiencies of both NO reduction and Hg(0) oxidation than those of SCR catalyst no. 2. NH{sub 3} addition seemed to inhibit the Hg(0) oxidation, which indicated competitive processes between NH{sub 3} reduction and Hg(0) oxidation on the surface of SCR catalysts. The hydrogen halogens, in the order of impact on Hg(0) oxidation, were HBr, HI, and HCl or HF. Addition of HBr at approximately 3 ppm could achieve 80% Hg(0) oxidation. Addition of HI at approximately 5 ppm could achieve 40% Hg(0) oxidation. In comparison to the empty reactor, 40% Hg(0) oxidation could be achieved when HCl addition was up to 300 ppm. The enhanced Hg(0) oxidation by addition of HBr and HI seemed not to be correlated to the catalytic effects by both evaluated SCR catalysts. The effectiveness of conversion of hydrogen halogens to halogen molecules or interhalogens seemed to be attributed to their impacts on Hg(0) oxidation. 30 refs., 4 figs.

  19. Characterization of liquids derived from laboratory coking of decant oil and co-coking of Pittsburgh seam bituminous coal with decant oil

    SciTech Connect (OSTI)

    Omer Gul; Caroline Clifford; Leslie R. Rudnick; Harold H. Schobert [Pennsylvania State University, University Park, PA (United States)

    2009-05-15T23:59:59.000Z

    In this study, decant oil and a blend of Pittsburgh seam bituminous coal with decant oil were subjected to coking and co-coking in a laboratory-scale delayed coker. Higher yields of coke and gas were obtained from co-coking than from coking. Coal addition into the feedstock resulted in lighter overhead liquid. GC/MS analyses of gasoline, jet fuel, and diesel show that co-coking of coal/decant oil gave higher quantity aromatic components than that of coking of decant oil alone. Simulated distillation gas chromatography analyses of overhead liquids and GC/MS analyses of vacuum fractions show that when coal was reacted with a decant oil, the coal constituents contributed to the distillable liquids. To address the reproducibility of the liquid products, overhead liquid samples collected at the first, third, and fifth hours of experiments of 6 h duration were evaluated using simulated distillation gas chromatography and {sup 1}H and {sup 13}C NMR. NMR analyses of the liquid products showed that, even though there were slight changes in the {sup 1}H and {sup 13}C spectra, the standard deviation was low for the time-dependent samples. Simulated distillation gas chromatography showed that the yields of refinery boiling range materials (i.e., gasoline, jet fuel, diesel, and fuel oil cuts) were reproducible between runs. Fractionation of the overhead liquids into refinery boiling range materials (gasoline, jet fuel, diesel, fuel oil fractions) showed that the boiling range materials and chemical compositions of fractions were found to be reproducible. 54 refs., 17 tabs.

  20. Anthracite-Crested butte folio, Colorado 

    E-Print Network [OSTI]

    Cross, Whitman, 1854-1949.; Eldridge, George Homans, 1854-1905.; Emmons, Samuel Franklin, 1841-1911.

    1894-01-01T23:59:59.000Z

    intake relationship to offspring age for black-tailed deer, elk, and white-tailed deer. 61 20 Scalar adjustment to milk energy concentration throughout lactation. 62 21 Scalar adjustment to milk production due to the milk requirement ratio. Milk... and likelihood of return at recreational areas (Swanson et al. 1989, Hastings 1986). Income from hunting operations is a major source of compensatory income for traditional farmers and ranchers (Haney 1983, Hill 1994). While deer are obviously an important...

  1. Anthracite Power & Light | Open Energy Information

    Open Energy Info (EERE)

    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 onYou are now leaving Energy.gov You are now leaving Energy.gov You are being directedAnnualProperty EditCalifornia: Energy Resources JumpAnaconda, Montana:Information

  2. Potential for Coal-to-Liquids Conversion in the U.S.-Resource Base

    E-Print Network [OSTI]

    Patzek, Tadeusz W.

    Potential for Coal-to-Liquids Conversion in the U.S.-Resource Base Gregory D. Croft1 and Tad W the multi-Hubbert curve analysis to coal production in the United States, we demonstrate that anthracite production of this highest-rank coal. The pro- duction of bituminous coal from existing mines is about 80

  3. THE 3R ANTHRACITE CLEAN COAL TECHNOLOGY Economical Conversion of Browncoal to Anthracite Type Clean

    E-Print Network [OSTI]

    Edward Someus

    pac i ties. The 3R An thra cite Clean Coal end prod uct and tech nol ogy may ad van ta geously be in

  4. The current state of CCS: Ongoing research at the University of Cambridge with application to the UK policy framework

    E-Print Network [OSTI]

    Daniels, K.A.; Huppert, H.E.; Neufeld, J.A.; Reiner, D.

    2012-12-14T23:59:59.000Z

    of crushed rock, reactive rock formations and un- derground reservoirs such as depleted oil and gas reservoirs or saline aquifers [3]. CO2 can 12Mainly bituminous coal, with some anthracite, is combusted for electricity in the UK. Bituminous coal is higher... Roadmap, Electricity Market Reform, carbon capture technologies, carbon sequestration, storage reservoir processes. JEL Classification O13 Q40 Q41 Q42 Q48 Q51 Q54 Q55 Q58 Contact K.A.Daniels@damtp.cam.ac.uk Publication December, 2012 Financial...

  5. EIS-0357- Gilberton Coal-to-Clean Fuels and Power Project in Giberton, PA

    Broader source: Energy.gov [DOE]

    This Environmental Impact Statement (EIS) assesses the potential environmental impacts that would result from a proposed Department of Energy (DOE) action to provide cost-shared funding for construction and operation of facilities near Gilberton, Pennsylvania, which have been proposed by WMPI PTY, LLC, for producing electricity, steam, and liquid fuels from anthracite coal waste (culm). The project was selected by DOE under the Clean Coal Power Initiative (CCPI) to demonstrate the integration of coal waste gasification and Fischer-Tropsch (F-T) synthesis of liquid hydrocarbon fuels at commercial scale.

  6. anthracite coal gasification: Topics by E-print Network

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

    Technology Demonstrations (5050) Clear Skies Reduced Carbon Intensity Clean Coal First Page Previous Page 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23...

  7. abandoned anthracite mines: Topics by E-print Network

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

    Coal Combustion By-Products Engineering Websites Summary: subject headings: Remedial action; Acid mine water; Mines; Coals; Recycling; Maryland; Fly ashRemediation of...

  8. anthracite mines mines: Topics by E-print Network

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

    Mines Using Coal Combustion By-Products Engineering Websites Summary: subject headings: Remedial action; Acid mine water; Mines; Coals; Recycling; Maryland; Fly ashRemediation of...

  9. Predictors of plasticity in bituminous coals. Final technical report

    SciTech Connect (OSTI)

    Lloyd, W. G.; Reasoner, J. W.; Hower, J. C.; Yates, L. P.; Clark, C. P.; Davis, E.; Fitzpatrick, A.; Irefin, A.; Jiminez, A.; Jones, T. M.

    1984-02-01T23:59:59.000Z

    A group of 40 hvb coals, mostly from western Kentucky fields, has been examined with regard to ASTM Gieseler plastometric properties. Twenty-nine of these coals have also been studied over a range of temperatures by isothermal Gieseler plastometry. Raw Gieseler data provide melting and coking slopes and readily calculable fluidity spans. Maximum fluidity by slope intersection is a more consistent measure than observed maximum fluidity. Isothermal slopes and maximum fluidities follow Arrhenius temperature dependencies, with activation energies related systematically to fluid properties. These freshly sampled coals are also characterized by chemical, physical and petrographic criteria, by quantitative solvent extractions, by pyrolysis gas chromatography, by Fourier Transform infrared analysis of coals and extraction residues, by the HPLC analysis of coal extracts, and by optical microscopy of coals and Gieseler semi-coke residues. Multiple linear regression analysis yields three-term expressions which estimate maximum fluidities (both ASTM and isothermal) with R values of .90 to .92. Slopes and critical temperatures are similarly predictable. Plastometer experiments with selected coals under superatmospheric pressures show both melting slopes and maximum fluidities to be sharply increased, the latter by one to three orders of magnitude. Some suggestions are offered to accommodate this new information into the general body of knowledge concerning the phenomenon of plasticity in mid-ranked coals. 81 references, 28 figures, 40 tables.

  10. Evaluation of an alternative bituminous material as a soil stabilizer

    E-Print Network [OSTI]

    Kim, Yong-Rak

    1999-01-01T23:59:59.000Z

    . Consequently, development of a new stabilization material, which is environmentally safe and non-flammable, is desired for replacing cutback asphalts. In this study a petroleum-resin-based (PRB) material was tested to investigate its physical and mechanical...

  11. australian bituminous coal: Topics by E-print Network

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

    composted manure LAPC, high ash raw manure HARM, and high ash partially composted manure HAPC) as well as blends of each biomass with Texas lignite coal (TXL). Activation...

  12. Updated Costs (June 2011 Basis) for Selected Bituminous Baseline Cases

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

    AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative1 First Use of Energy for All Purposes (Fuel and Nonfuel), 2002; Level:Energy: Grid Integration Redefining What'sis Taking Over OurThe Iron SpinPrinceton PlasmaAfternoon TalksDigitalRevision

  13. NETL - Bituminous Baseline Performance and Cost Interactive Tool | Open

    Open Energy Info (EERE)

    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 onYou are now leaving Energy.gov You are now leaving Energy.gov You are being directedAnnual SiteofEvaluatingGroup |JilinLu anMicrogreenMoonNASA/Ames Global Emissions DatasourceNEPCEnergy

  14. THE 3R ANTHRACITE CLEAN COAL TECHNOLOGY Economical Conversion of Browncoal to Anthracite Type Clean Coal by Low Temperature Carbonization Pre-Treatment Process

    E-Print Network [OSTI]

    Edward Someus

    The pre ven tive pre-treat ment of low grade solid fu els is safer, faster, better, and less costly vs. the “end-of-the-pipe ” post treat ment so lu tions. The “3R ” (Re cy cle-Re duce-Re use) in te grated en vi ron-ment con trol tech nol ogy pro vides pre ven tive pre-treat ment of low grade solid fu els, such as brown coal and con tam i nated solid fu els to achieve high grade cleansed fu els with an thra cite and coke com-pa ra ble qual ity. The goal of the 3R tech nol ogy is to pro vide cost ef fi cient and en vi ron men tally sus-tain able so lu tions by pre ven tive pre-treat ment means for ex tended op er a tions of the solid fuel com-bus tion power plants with ca pac ity up to 300 MWe power ca pac i ties. The 3R An thra cite Clean Coal end prod uct and tech nol ogy may ad van ta geously be in te grated to the oxyfuel – oxy-fir ing, Fos ter Wheeler an thra cite arc-fired util ity type boiler and Heat Pipe Re former tech nol o gies in com bi na tion with CO2 cap ture and stor age pro grams. The 3R tech nol ogy is pat ented orig i nal so lu tion. Ad van tages. Feedstock flex i bil ity: ap pli ca tion of pre-treated multi fu els from wider fuel se lec tion and avail abil ity. Im proved burn ing ef fi ciency. Tech nol ogy flex i bil ity: ef fi cient and ad van ta geous inter-link to proven boiler tech nol o gies, such as oxyfuel and arc-fired boil ers. Near zero pol lut ants for haz ard ous-air-pol lut ants: pre ven tive sep a ra tion of halo gens and heavy met als into small vol ume streams prior uti li za tion of cleansed fu els. ?97 % or ganic sul phur re moval achieved by the 3R ther-

  15. Coal desulfurization in a rotary kiln combustor. Quarterly report No. 1, April 16, 1990--July 15, 1990

    SciTech Connect (OSTI)

    Cobb, J.T. Jr.

    1990-08-15T23:59:59.000Z

    BCR National Laboratory (BCRNL) has initiated a project aimed at evaluating the technical and economic feasibility of using a rotary kiln, suitably modified, to burn Pennsylvania anthracite wastes, co-fired with high-sulfur bituminous coal. Limestone will be injected into the kiln for sulfur control, to determine whether high sulfur capture levels can be achieved with high sorbent utilization. The principal objectives of this work are: (1) to prove the feasibility of burning anthracite refuse, with co-firing of high-sulfur bituminous coal and with limestone injection for sulfur emissions control, in a rotary kiln fitted with a Universal Energy International (UEI) air injector system; (2) to determine the emissions levels of SO{sub x} and NO{sub x} and specifically to identify the Ca/S ratios that are required to meet New Source Performance Standards; (3) to evaluate the technical and economic merits of a commercial rotary kiln combustor in comparison to fluidized bed combustors; and, (4) to ascertain the need for further work, including additional combustion tests, prior to commercial application, and to recommend accordingly a detailed program towards this end.

  16. Coal desulfurization in a rotary kiln combustor

    SciTech Connect (OSTI)

    Cobb, J.T. Jr.

    1990-08-15T23:59:59.000Z

    BCR National Laboratory (BCRNL) has initiated a project aimed at evaluating the technical and economic feasibility of using a rotary kiln, suitably modified, to burn Pennsylvania anthracite wastes, co-fired with high-sulfur bituminous coal. Limestone will be injected into the kiln for sulfur control, to determine whether high sulfur capture levels can be achieved with high sorbent utilization. The principal objectives of this work are: (1) to prove the feasibility of burning anthracite refuse, with co-firing of high-sulfur bituminous coal and with limestone injection for sulfur emissions control, in a rotary kiln fitted with a Universal Energy International (UEI) air injector system; (2) to determine the emissions levels of SO{sub x} and NO{sub x} and specifically to identify the Ca/S ratios that are required to meet New Source Performance Standards; (3) to evaluate the technical and economic merits of a commercial rotary kiln combustor in comparison to fluidized bed combustors; and, (4) to ascertain the need for further work, including additional combustion tests, prior to commercial application, and to recommend accordingly a detailed program towards this end.

  17. Enhancement of pulverized coal combustion by plasma technology

    SciTech Connect (OSTI)

    Gorokhovski, M.A.; Jankoski, Z.; Lockwood, F.C.; Karpenko, E.I.; Messerle, V.E.; Ustimenko, A.B. [University of Rouen, Rouen (France)

    2007-07-01T23:59:59.000Z

    Plasma-assisted pulverized coal combustion is a promising technology for thermal power plants (TPP). This article reports one- and three- dimensional numerical simulations, as well as laboratory and industrial measurements of coal combustion using a plasma-fuel system (PFS). The chemical kinetic and fluid mechanics involved in this technology are analysed. The results show that a PFS, can be used to promote early ignition and enhanced stabilization of a pulverized coal flame. It is shown that this technology, in addition to enhancing the combustion efficiency of the flame, reduces harmful emissions from power coals of all ranks (brown, bituminous, anthracite and their mixtures). Data summarising the experience of 27 pulverized coal boilers in 16 thermal power plants in several countries (Russia, Kazakhstan, Korea, Ukraine, Slovakia, Mongolia and China), embracing steam productivities from 75 to 670 tons per hour (TPH), are presented. Finally, the practical computation of the characteristics of the PFS, as function of coal properties, is discussed.

  18. The role of coal in industrialization: A case study of Nigeria

    SciTech Connect (OSTI)

    Akarakiri, J.B. (Obafemi Awolowo Univ., Ile-Ife (Nigeria))

    1989-01-01T23:59:59.000Z

    Coal is a mineral matter found in layers or beds in sedimentary rocks. It is a very highly variable substance. In addition to the variations from lignite to bituminous and anthracite, there are vast differences in its heating value, amount of volatiles, sulfur, moisture and so on. The chemical and physical properties of coal make it an important industrial raw material. There is proven 639 million tonnes of coal reserves in Nigeria. This paper examines the potential and current role of coal in the industrialization of Nigeria. Industries are now dependent on fuel oil as a source of fuel because of its economic and technological advantages over coal. Coal is a source of industrial energy for the future after the known oil reserves might have been exhausted. In the short term, coal can be used as a material for chemicals, iron and steel production as well as a substitute for wood energy in the process of industrialization.

  19. Characterization and fate of vapor-phase organic constituents from atmospheric pressure fluidized bed combustors (AFBC): East Stroudsburg University AFBC

    SciTech Connect (OSTI)

    Yeh, Hsu-Chi; Newton, G.J.; Henderson, T.R.; Hobbs, C.H.

    1987-08-01T23:59:59.000Z

    Very little research has been devoted to the characterization of vapor-phase organic compounds in gaseous streams. Because of the concerns that gaseous organic compounds from FBCs may include potentially toxic and/or mutagenic materials. We will measure vapor-phase hydrocarbon concentrations in the process streams of operating FBCs. This report describes our field sampling results on the atmospheric pressure fluidized bed combustor (AFBC) at the East Stroudsburg University during its normal operation for supplying heat and hot water to the campus. This AFBC has a bed size of 36 ft/sup 2/ and was burning anthracite culm. The culm consumption rates during the week of our sampling period were 1600 to 3000 lb/hr. Emphasis was placed on characterization of process stream effluents, including particles and vapor-phase organic constituents. Results indicated that the mass concentration (or loading) of particulate matter within the effluent stream was similar to other FBCs that have been studied. The particulate mass concentration measured after the baghouse location was 0.0048 g/m/sup 3/ (0.0047 lb/10/sup 6/ Btu). This was equivalent to a total of 35 g/hr of particulate emissions. The fraction of particulate material presented as organics (extractable fraction) was, on the average, less than 2% of total mass of particulate emissions. The vapor-phase organic contents indicated that the quantities of individual polycyclic aromatic hydrocarbons (PAHs) were low, being less than 2.5 ..mu..g/m/sup 3/ for any individual sample. Most of the PAHs detected were low boiling compounds such as naphthalene or phenanthrene, with trace amounts of pyrene. 22 refs., 13 figs., 11 tabs.

  20. Evaluation of methods of mixing lime in bituminous paving mixtures in batch and drum plants

    E-Print Network [OSTI]

    Button, Joseph Wade

    1984-01-01T23:59:59.000Z

    prepared mixtures, field mixtures obtained at the plant and pavement cores. Laboratory tests included Hveem and Marshall stability, resilient modulus and indirect tension. Mixture conditioning to evaluate resistance to moisture damage included vacuum... Mixed and Compacted Specimens Tensile Strength Ratio for Laboratory Mixed and Compacted Specimens 14 Marshall Stability Before and After 7-days Soaking in Water for Lab Mixed and Compacted Specimens 36 FIGURE Page 15 16 Hveem Stability Before...

  1. INTERACTION OF A SUB-BITUMINOUS COAL WITH A STRONG ACID AND A STRONG BASE

    E-Print Network [OSTI]

    Seth, M.

    2010-01-01T23:59:59.000Z

    involves heating a slurry of coal and sodium hydroxideCoal is crushed, generally minus 20 mesh, and sent to a slurry

  2. Predictors of plasticity in bituminous coals. Technical progress report No. 7

    SciTech Connect (OSTI)

    Lloyd, W.G.; Reasoner, J.W.; Hower, J.C.; Yates, L.P.; Clark, C.P.; Davis, E.; Fitzpatrick, A.; Reagles, C.L.; Whitt, J.M.

    1983-06-13T23:59:59.000Z

    The 40-coal database for the prediction of the plastic properties of hvb coals has been completed. Statistical analysis has been commenced. Most of the 37 ostensibly independent experimental variables and the 22 derived variables are shown to have little or no predictive power. Approximately a dozen independent variables appear to be systematically related to plasticity. Maximum fluidity can be determined in several ways from Gieseler plastometer data. Under both ASTM and isothermal conditions, maximum fluidity can be predicted using just two independent variables with a standard linear regression model of the form ln(maximum fluidity) = ..beta../sub 0/ + ..beta../sub 1/*V/sub 1/ + ..beta../sub 2/*V/sub 2/ with correlation coefficients greater than .85. The use of three or four independent variables permits predictions with R greater than .90. Pyrolysis gas chromatography has emerged as a powerful and relatively inexpensive new tool for the characterization of coals. In conjunction with studies of extraction, extract characteristics, and residue swelling, pyrolysis/GC affords insights into the basic factors determining the plastic behavior of coals.

  3. Predictors of plasticity in bituminous coals. Technical progress report No. 2, March 1, 1982

    SciTech Connect (OSTI)

    Lloyd, W. G.; Reasoner, J. W.; Hower, J. C.; Yates, L. P.; Clark, C. P.; Jones, T. M.; Sturgeon, L. P.; Whitt, J. M.

    1982-03-01T23:59:59.000Z

    The approach of this study is to secure three dozen (or more) coals of varying rank, composition and plasticity, and to analyze these coals carefully by standard chemical and petrographic techniques. The bitumen fractions will be determined, both by THF (asphaltenes but not preasphaltenes) and DMF (everything). Pyrolysis gas chromatography on both whole coals and extracted residues will compare capacities to generate metaplast. Extracts from coals with plasticities differing by at least four orders of magnitude will be examined for identifiable differences; extraction residues will be subjected to differential FTIR analysis. All of the data will be combined and subjected to systematic statistical analysis with the objective of identifying predictors of coal plasticity. This report describes the work in the first six months of the study. During this period equipment and instrumentation has been obtained, 24 coal samples have been obtained, the nonclassical methods have been developed and checked out, and an appreciable amount of experimentl data has been obtained.

  4. Predictors of plasticity in bituminous coals. Technical progress report No. 5. [Gieseler plastometer

    SciTech Connect (OSTI)

    Lloyd, W.G.; Reasoner, J.W.; Hower, J.C.; Yates, L.P.; Bowling, C.C.; Davis, E.; Whitt, J.M.

    1982-12-01T23:59:59.000Z

    The forty fresh coal samples have been obtained, and the proximate, ultimate and petrographic characterization on all samples is now completed. ASTM Gieseler plastometry analyses have been completed on all 40 coals, in quadruplicate, and the melting and coking slopes and intersection maximum fluidities have been estimated. Significant progress has been made in completing the nonstandard analyses which will provide an important part of the project database. Fifteen coals have been subjected to the 20-run sets of isothermal Gieseler analyses; the balance of this group is expected to be completed by mid-1983. Pyrolysis gas chromatogrpahy has been completed for 36 of the 40 coals. Quantitative extractions have now been completed for 32 of the 40 coals, both with tegrahydrofuran and with dimethylformamide. FTIR spectra have been obtained in sets of three (whole coal, residue from THF extraction, residue from DMF extraction) for 31 of the 40 coals. This report also includes a descriptive study by optical microscopy of selected coals and semi-cokes derived from these coals. Future work will include correlation analysis of the completed datasets, and an intensive study of the characteristics of six or seven coals selected from the present set.

  5. Predictors of plasticity in bituminous coals. Technical progress report No. 3, June 1, 1982

    SciTech Connect (OSTI)

    Lloyd, W.G.; Reasoner, J.W.; Hower, J.C.; Yates, L.P.; Bowling, C.C.; Jones, T.M.; Sturgeon, L.P.; Whitt, J.M.

    1982-06-01T23:59:59.000Z

    An additional 13 coals have been obtained, bringing the total to 37. Classical chemical and petrographic characterizations have been completed for most of the coals now in hand. The database for analytical pyrolysis/gas chromatography and for quantitative extraction (THF and DMF) has been more than doubled. The procedures for Fourier Transform infrared analysis have been further modified, making use of a new micropulverizer and drying system, and a procedure for the production of uniform and reproducible KBr pellets has been developed and is now in use. The first analytical isothermal plastometry (AIP) data have been obtained, on two highly plastic coals, and additional data are now being generated. Additional work will be carried out with the pyrolysis/GC system and the THF and DMF extraction work. With the progress made in FTIR spectra acquisition, it is expected to complete acquisition and storage of raw coal spectra and to commence application of techniques to provide differential spectrometric information. HPLC analysis of extracts now appears ready for standardization of procedure. Finally, with the data available, statistical analytical work will be initiated.

  6. Predictors of plasticity in bituminous coals. Technical progress report No. 4, Part I of II

    SciTech Connect (OSTI)

    Lloyd, W.G.; Reasoner, J.W.; Hower, J.C.; Yates, L.P.; Bowling, C.C.; Davis, E.; Jones, T.M.; Whitt, J.M.

    1982-09-01T23:59:59.000Z

    We have substantially enlarged the analytical database developed from the first 37 coals obtained for this study. Pyrolysis/GC has now been completed for 30 coals, and THF and DMF quantitative extractions for 23 coals. FT-IR spectra have been obtained and disc-stored for all coals; differential analysis of these data is now commencing. The first statistical trial runs have been made. ASTM maximum fluidity can be predicted by a simple two-variable regression equation with R = 0.95. This initial success encourages us to undertake a more sophisticated examination of the interdependencies which are becoming evident as the database is built. Under the original work plan we are to enter an intensive Phase 2 study of six selected coals by January 1983.

  7. Predictors of plasticity in bituminous coals. Technical progress report No. 1

    SciTech Connect (OSTI)

    Lloyd, W.G.; Reasoner, J.W.; Jiminez, A.; Hower, J.C.; Yates, L.P.; Jones, T.M.

    1981-12-01T23:59:59.000Z

    The first dozen coals - high volatile B and C from western Kentucky - have been identified and samples obtained. Classical analyses are nearly completed on this first group. Method development work has been undertaken and is substantially completed for pyrolysis gas chromatography, quantitative extraction of bitumen fraction, and isothermal plastometry. The principal item of new equipment, a Fourier transform infrared spectrometer, has been purchased and has been delivered. It is planned to acquire and to commence classical (ASTM and petrographic) characterization of the second dozen coals to be used, and to commence the systematic acquisition of isothermal plastometric data, GC pyrograms, and quantitative extractions. Development work will be initiated on the statistical analytical approaches to be used, with the expectation of commencing the first statistical analysis in May 1982.

  8. Predictors of plasticity in bituminous coals. Technical progress report No. 8

    SciTech Connect (OSTI)

    Lloyd, W.G.; Reasoner, J.W.; Hower, J.C.; Yates, L.P.; Clark, C.P.; Davis, E.; Fitzpatrick, A.; Reagles, C.L.; Whitt, J.M.

    1983-09-01T23:59:59.000Z

    The greater part of the present study on predictors of coal fluidity has now been completed, with most of the developed database presented in the preceding Technical Progress Report. The one critical area in which we have fallen behind schedule is that of isothermal fluidity measurements at superatmospheric pressures. During the past quarter we have made several modifications to the experimental high-pressure Gieseler plastometer, and have been able to complete over 60 superatmospheric runs. This work will be completed and analyzed within the period of the 90-day no-cost extension which has been granted. The extra time has permitted completion of additional experiments in solvent extraction. During this period we have also completed characterization of THF extracts by HPLC, and characterization of coals, coal extraction residues and selected extracts by FTIR. 13 references, 25 tables.

  9. Predictors of plasticity in bituminous coals. Technical progress report No. 6

    SciTech Connect (OSTI)

    Lloyd, W.G.; Reasoner, J.W.; Hower, J.C.; Yates, L.P.; Bowling, C.C.; Davis, E.; Fitzpatrick, A.; Whitt, J.M.

    1983-03-01T23:59:59.000Z

    We have completed the pyrolysis/gas chromatographic analysis of all 40 coals in the present study, at two temperatures, 450/sup 0/ and 650/sup 0/C. We have also completed triplicate quantitative extraction analyses of all 40 coals, using tetrahydrofuran as the extractant solvent, and have completed a parallel set of extractions using N,N-dimethylformamide as the extractant solvent. In addition, we have completed analysis of over 100 additional isothermal Gieseler plastometer runs, and have made the first series of quantitative estimates of H(aromatic)/H(aliphatic) ratios from Fourier Transform Infrared Spectroscopy data. Exploratory work has begun on the petrographic characterization of the semi-coke residues from Gieseler plastometer runs, and also in characterizing THF extracts by thin layer chromatography and by column chromatography (quantitative group separations). Proximate, ultimate and petrographic characterization of the 40 coals has been completed previously. We are now prepared to start a study, using freshly re-sampled coals, of the effects of varying pressure upon the several parameters of fluidity.

  10. Thermo-Viscoelastic-Viscoplastic-Viscodamage-Healing Modeling of Bituminous Materials: Theory and Computation

    E-Print Network [OSTI]

    Darabi Konartakhteh, Masoud

    2012-10-19T23:59:59.000Z

    ……………… ……… 341 9.6. Extrapolation of the Rutting in 3D.……....………… 348 9.7. Comparison with Experimental Results.….………… 351 9.8. Conclusions………………………………………… 354 xviii CHAPTER Page X CONCLUSIONS AND RECOMMENDATIONS..…………… 356 10... prediction using viscoelastic- viscoplastic model and experimental data for the cyclic stress control test at 19oC when the stress amplitude is 750kPa. (a) Loading cycles 1-30; (b) Loading cycles 970-980……………….. 268 7.36 Comparison of the VE...

  11. THE EFFECTS OF SOLVENTS ON SUB-BITUMINOUS COAL BELOW ITS PYROLYSIS TEMPERATURE

    E-Print Network [OSTI]

    Grens III., Edward A.

    2013-01-01T23:59:59.000Z

    not hexane-solubles ("asphaltenes"), and pyridine- but notfractionated into oils, asphaltenes, and preasphaltenes, alltE;! nded to be largely asphaltenes and preasphaltenes, and

  12. HYDROGENOLYSIS OF A SUB-BITUMINOUS COAL WITH MOLTEN ZINC CHLORIDE SOLUTIONS

    E-Print Network [OSTI]

    Holten, R.R.

    2010-01-01T23:59:59.000Z

    molecular-weight ranges of asphaltenes and preasphaltenes.consecutive reactions: coal asphaltenes oil Since the firstfirst being con- verted to asphaltenes. Recently, Sternberg,

  13. Development and evaluation of an automated reflectance microscope system for the petrographic characterization of bituminous coals

    SciTech Connect (OSTI)

    Hoover, D. S.; Davis, A.

    1980-10-01T23:59:59.000Z

    The development of automated coal petrographic techniques will lessen the demands on skilled personnel to do routine work. This project is concerned with the development and successful testing of an instrument which will meet these needs. The fundamental differences in reflectance of the three primary maceral groups should enable their differentiation in an automated-reflectance frequency histogram (reflectogram). Consequently, reflected light photometry was chosen as the method for automating coal petrographic analysis. Three generations of an automated system (called Rapid Scan Versions I, II and III) were developed and evaluated for petrographic analysis. Their basic design was that of a reflected-light microscope photometer with an automatic stage, interfaced with a minicomputer. The hardware elements used in the Rapid Scan Version I limited the system's flexibility and presented problems with signal digitization and measurement precision. Rapid Scan Version II was designed to incorporate a new microscope photometer and computer system. A digital stepping stage was incorporated into the Rapid Scan Version III system. The precision of reflectance determination of this system was found to be +- 0.02 percent reflectance. The limiting factor in quantitative interpretation of Rapid Scan reflectograms is the resolution of reflectance populations of the individual maceral groups. Statistical testing indicated that reflectograms were highly reproducible, and a new computer program, PETAN, was written to interpret the curves for vitrinite reflectance parameters ad petrographic.

  14. Eastern gas shales bibliography selected annotations: gas, oil, uranium, etc. Citations in bituminous shales worldwide

    SciTech Connect (OSTI)

    Hall, V.S. (comp.)

    1980-06-01T23:59:59.000Z

    This bibliography contains 2702 citations, most of which are annotated. They are arranged by author in numerical order with a geographical index following the listing. The work is international in scope and covers the early geological literature, continuing through 1979 with a few 1980 citations in Addendum II. Addendum I contains a listing of the reports, well logs and symposiums of the Unconventional Gas Recovery Program (UGR) through August 1979. There is an author-subject index for these publications following the listing. The second part of Addendum I is a listing of the UGR maps which also has a subject-author index following the map listing. Addendum II includes several important new titles on the Devonian shale as well as a few older citations which were not found until after the bibliography had been numbered and essentially completed. A geographic index for these citations follows this listing.

  15. THE EFFECTS OF SOLVENTS ON SUB-BITUMINOUS COAL BELOW ITS PYROLYSIS TEMPERATURE

    E-Print Network [OSTI]

    Grens III., Edward A.

    2013-01-01T23:59:59.000Z

    48. Table 1. Roland seam coal analyses Proximate analysis: (some ext'racts of Roland seam coal - 4 hours extraction at5. Extraction of Roland seam coal with solvent mixtures for

  16. INTERACTION OF A SUB-BITUMINOUS COAL WITH A STRONG ACID AND A STRONG BASE

    E-Print Network [OSTI]

    Seth, M.

    2010-01-01T23:59:59.000Z

    alkali con- alkali-soluble Seam coal over the temperaturefor the Pittsburgh Seam coal. Another important conclusionVI, Composition of Roland seam coal--ultimate analysis~ wt%,

  17. HYDROGENOLYSIS OF A SUB-BITUMINOUS COAL WITH MOLTEN ZINC CHLORIDE SOLUTIONS

    E-Print Network [OSTI]

    Holten, R.R.

    2010-01-01T23:59:59.000Z

    variations in coal from rank to rank, mine to mine, seam tocoal was supplied by the Wyodak t. Resources Development Corporation from the Roland top seam

  18. Visual representation of carbon dioxide adsorption in a low-volatile bituminous coal molecular model

    SciTech Connect (OSTI)

    Marielle R. Narkiewicz; Jonathan P. Mathews [Pennsylvania State University, University Park, PA (United States). Department of Energy and Minerals Engineering

    2009-09-15T23:59:59.000Z

    Carbon dioxide can be sequestered in unmineable coal seams to aid in mitigating global climate change, while concurrently CH{sub 4} can be desorbed from the coal seam and used as a domestic energy source. In this work, a previously constructed molecular representation was used to simulate several processes that occur during sequestration, such as sorption capacities of CO{sub 2} and CH{sub 4}, CO{sub 2}-induced swelling, contraction because of CH{sub 4} and water loss, and the pore-blocking role of moisture. This is carried out by calculating the energy minima of the molecular model with different amounts of CO{sub 2}, CH{sub 4}, and H{sub 2}O. The model used is large (>2000 atoms) and contains a molecular-weight distribution, so that it has the flexibility to be used by other researchers and for other purposes in the future. In the low-level molecular modeling presented here, it was anticipated that CO{sub 2} would be adsorbed more readily than CH{sub 4}, that swelling would be anisotropic, greater perpendicular to the bedding plane because of the rank of this coal, and finally, that, with the addition of moisture, CO{sub 2} capacity in the coal would be reduced. As expected with this high-rank coal, there was swelling when CO{sub 2} perturbed the structure of approximately 5%. It was found that, on the basis of the interconnected pore structure and molecular sizes, CO{sub 2} was able to access 12.4% more of the pore volume (as defined by helium) than CH{sub 4}, in the rigid molecular representation. With water as stationary molecules, mostly hydrogen bound to the coal oxygen functionality, pore access decreased by 5.1% of the pore volume for CO{sub 2} accessibility and 4.7% of the pore volume for CH{sub 4} accessibility. 36 refs., 12 figs., 1 tab.

  19. INTERACTION OF A SUB-BITUMINOUS COAL WITH A STRONG ACID AND A STRONG BASE

    E-Print Network [OSTI]

    Seth, M.

    2010-01-01T23:59:59.000Z

    Investigation of Molten-Salt/Organic-Solvent CombinationsAs an alternative to molten salts, inorganic acids are aniii) Investigation of molten-salt/organic- Dee Extraction of

  20. HYDROGENOLYSIS OF A SUB-BITUMINOUS COAL WITH MOLTEN ZINC CHLORIDE SOLUTIONS

    E-Print Network [OSTI]

    Holten, R.R.

    2010-01-01T23:59:59.000Z

    Liquefaction Chemistry B. Molten Salt Catalysis RationaleUsed Equipment and Procedure Molten Salt a. b. c. Treat~entEquipment and Procedure Molten Salt Treatment a. Equipment

  1. Evaluation of reclaimed rubber in bituminous pavements. Final report, July 1993-April 1995

    SciTech Connect (OSTI)

    Trepanier, J.

    1995-06-01T23:59:59.000Z

    Section 1038 of the 1991 Intermodel Surface Transportation efficiency Act (ISTEA) mandated use of crumb rubber from scrap tires in asphalt pavement starting in FY 94. To gain some experience, the Illinois Department of Transportation (IDOT) constructed five demonstration projects in 1993 and one in 1994. All used the `dry process` to introduce crumb rubber into the mix. With the dry process, crumb rubber is added to the heated aggregate prior to addition of asphalt cement (AC). Three projects used very low addition rates. Each was divided into five equal segments. One segment, the control, used no crumb rubber. The other segments used 1/2, 1, 1 1/2 and 2 pounds of crumb rubber per ton of hot mix. The other three projects each used 20 pounds of crumb rubber per ton of hot mix. Both batch plants and drier-drum plants were used, and the crumb rubber was supplied in pre-measured batch-size packets, 50-pound paper bags and 2000-pound super sacks.

  2. HYDROGENOLYSIS OF A SUB-BITUMINOUS COAL WITH MOLTEN ZINC CHLORIDE SOLUTIONS

    E-Print Network [OSTI]

    Holten, R.R.

    2010-01-01T23:59:59.000Z

    for Liquefaction and Gasification of Western Coals", in5272 (1976). COal Processing - Gasification, Liguefaction,or gaseous fuels, coal gasification has advanced furthest

  3. HYDROGENOLYSIS OF A SUB-BITUMINOUS COAL WITH MOLTEN ZINC CHLORIDE SOLUTIONS

    E-Print Network [OSTI]

    Holten, R.R.

    2010-01-01T23:59:59.000Z

    of char and gases. The Fischer-Tropsch process is an exampleprocess economics, the Fischer-Tropsch process has not beenevaluations for a Fischer-Tropsch plant in the United

  4. HYDROGENOLYSIS OF A SUB-BITUMINOUS COAL WITH MOLTEN ZINC CHLORIDE SOLUTIONS

    E-Print Network [OSTI]

    Holten, R.R.

    2010-01-01T23:59:59.000Z

    or gaseous fuels, coal gasification has advanced furthestrapidly. While coal gasification may reach commercializa-5272 (1976). COal Processing - Gasification, Liguefaction,

  5. Evaluation of methods of mixing lime in bituminous paving mixtures in batch and drum plants 

    E-Print Network [OSTI]

    Button, Joseph Wade

    1984-01-01T23:59:59.000Z

    ) Joseph Wade Button, B. S. , Texas ASM University Co-Chairmen of Advisory Committee: Mr. Bob M. Gallaway and Dr. Dallas N. Little A field test was conducted to evaluate the use of hydrated lime as an antistrip additive in hot mix asphalt concrete.... Lime was added in the pugmill of the batch plant, on the cold feed belt, and through the fines feeder of the drum mix plant. The asphalt and aggregates used were characterized in the laboratory. Asphalt concrete mixture tests included laboratory...

  6. THE EFFECTS OF SOLVENTS ON SUB-BITUMINOUS COAL BELOW ITS PYROLYSIS TEMPERATURE

    E-Print Network [OSTI]

    Grens III., Edward A.

    2013-01-01T23:59:59.000Z

    resistance heaters, with heat input adjusted to con- trolfix temperature) and the heat input adjusted to give reflux

  7. Assessment of Energy Efficiency Improvement and CO2 Emission Reduction Potentials in the Iron and Steel Industry in China

    E-Print Network [OSTI]

    Hasanbeigi, Ali

    2013-01-01T23:59:59.000Z

    factor of bituminous coal, coking coal, and coke consumed inprice of Bituminous coal, coking coal, and coke consumed in

  8. Cost and Performance Baseline for Fossil Energy Plants Volume 1: Bituminous Coal and Natural Gas to Electricity Revision 3

    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: Alternative1 First Use of Energy for All Purposes (Fuel and Nonfuel), 2002; Level: National5Sales for4,645U.S. DOEThe Bonneville Power Administration would likeConstitution AndControllingCoolCorrective Action1, CostCost and

  9. Determination of the effect of different additives in coking blends using a combination of in situ high-temperature {sup 1}H NMR and rheometry

    SciTech Connect (OSTI)

    Miguel C. Diaz; Karen M. Steel; Trevor C. Drage; John W. Patrick; Colin E. Snape [Nottingham University, Nottingham (United Kingdom). Nottingham Fuel and Energy Centre, School of Chemical, Environmental and Mining Engineering

    2005-12-01T23:59:59.000Z

    High-temperature {sup 1}H NMR and rheometry measurements were carried out on 4:1 wt/wt blends of a medium volatile bituminous coal with two anthracites, two petroleum cokes, charcoal, wood, a low-temperature coke breeze, tyre crumb, and active carbon to determine the effects on fluidity development to identify the parameters responsible for these effects during pyrolysis and to study possible relationships among the parameters derived from these techniques. Positive, negative, and neutral effects were identified on the concentration of fluid material. Small positive effects (ca. 5-6%) were caused by blending the coal with petroleum cokes. Charcoal, wood, and active carbon all exerted negative effects on concentration (18-27% reduction) and mobility (12-25% reduction in T2) of the fluid phase, which have been associated with the inert character and high surface areas of these additives that adsorb the fluid phase of the coal. One of the anthracites and the low-temperature coke breeze caused deleterious effects to a lesser extent on the concentration (7-12%) and mobility (13-17%) of the fluid material, possibly due to the high concentration of metals in these additives (ca. 11% ash). Despite the high fluid character of tyre crumb at the temperature of maximum fluidity of the coal (73%), the mobility of the fluid phase of the blend was lower than expected. The comparison of {sup 1}H NMR and rheometry results indicated that to account for the variations in minimum complex viscosity for all the blends, both the maximum concentration of fluid phase and the maximum mobility of the fluid material had to be considered. For individual blends, two exponential relationships have been found between the complex viscosity and the concentration of solid phase in both the softening and resolidification stages but the parameters are different for each blend. 30 refs., 8 figs., 5 tabs.

  10. Isotope study on organic nitrogen of Westphalian anthracites from the Western Middle field of Pennsylvania (U.S.A.) and from the Bramsche

    E-Print Network [OSTI]

    that nitrogen is released by sedimentary organic matter during diagenesis and metamorphism. Improvements of our

  11. Sulfur and ash reduction potential and selected chemical and physical properties of United States coals. [Contains glossary

    SciTech Connect (OSTI)

    Cavallaro, J.A.; Deurbrouck, A.W.; Killmeyer, R.P.; Fuchs, W. (USDOE Pittsburgh Energy Technology Center, PA (USA). Coal Preparation Div.); Jacobsen, P.S. (Burns and Roe Services Corp., Pittsburgh, PA (USA))

    1991-02-01T23:59:59.000Z

    This report presents the washability and comprehensive characterization results of 184 raw coal channel samples, including anthracite, bituminous and lignite coals, collected from the Central Region of the United States. This is the second of a three volume report on the coals of the United States. All the data are presented in six appendices. Statistical techniques and definitions are presented in Appendix A, and a glossary of terms is presented in Appendix B. The complete washability data and an in-depth characterization of each sample are presented alphabetically by state in Appendix C. In Appendix D, a statistical evaluation is given for the composited washability data, selected chemical and physical properties and washability data interpolated at various levels of Btu recovery. This presentation is shown by state, section, and region where four or more samples were collected. Appendix E presents coalbed codes and names for the Central Region coals. Graphical summations are presented by state, section and region showing the effects of crushing on impurity reductions, and the distribution of raw and clean coal samples meeting various levels of SO{sub 2} emissions. 35 figs., 5 tabs.

  12. 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

    2008-03-15T23:59:59.000Z

    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.

  13. Low-rank-coal study national needs for resource development. Volume 1. Executive summary

    SciTech Connect (OSTI)

    Elliot, Dr., Martin A.; Hill, George R.; Jonakin, James; Crutchfield, Paul W.; Severson, Donald E.; White, David M.; Yeager, Kurt

    1980-11-01T23:59:59.000Z

    Low-rank coals - lignite and subbituminous - are those which have been subjected to the least amount of metamorphic change during the coal-forming process. As such, they retain greater fractions of moisture and volatile matter from the original peat material, and contain less fixed carbon, than the high-rank coals - bituminous and anthracite. The primary measure used to classify the lower ranks of coal is heating value. Other important characteristics which distinguish the low-rank coals from high-rank coals are discussed in this report. Low-rank coals represent a major, and largely untapped, energy resource for this country. Very extensive deposits of lignite and subbituminous coal exist in the western states, the Gulf coast, and Alaska. Major deposits of low-rank coal are also found in many other countries, most notably the USSR, Australia, Canada, and the central and eastern European nations. Worldwide coal statistics indicate that low-rank coals account for roughly one-third of the total resource and current production tonnages. This report recommends a comprehensive national research, development, and demonstration (RD and D) program to enhance the development of low-rank coals. The major conclusion of this study is that the unique properties of these coals affect the technologies for their extraction, preparation, direct use, and conversion and justify a separate focus on low-rank coals in the national RD and D efforts.

  14. Injury experience in coal mining, 1991

    SciTech Connect (OSTI)

    Not Available

    1991-12-31T23:59:59.000Z

    This Mine Safety and Health Administration (MSHA) informational report reviews in detail the occupational injury and illness experience of coal mining in the United States for 1991. Data reported by operators of mining establishments concerning work injuries are summarized by work location, accident classification, part of body injured, nature of injury, occupation, and anthracite or bituminous coal. Related information on employment, worktime, and operating activity also is presented. Data reported by independent contractors performing certain work at mining locations are depicted separately in this report. For ease of comparison between coal mining and the metal and nonmetal mineral mining industries, summary reference tabulations are included at the end of both the operator and the contractor sections of this report. Data used in compiling this report were reported by operators of coal mines and preparation plants on a mandatory basis as required under the Federal Mine Safety and Health Act of 1977, Public Law 91-173,as amended by Public Law 95-164. Since January 1, 1978, operators of mines or preparation plants or both which are subject to the Act have been required under 30 CFR, Part 50, to submit reports of injuries, occupational illnesses, and related data.

  15. 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.

    2006-01-01T23:59:59.000Z

    Weber et al. , 1996) Big Sky (PRB), sub-bituminous (Weber etet al. , 1996) Big Sky ( PRB), sub-bituminous (Weber etWeber et al. , 1996) Big Sky (PRB), sub-bituminous (Weber et

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

    E-Print Network [OSTI]

    Lu, Xiaoming

    2012-01-01T23:59:59.000Z

    with less carbon and energy density than coal, is highlyfossil energy plants, volume 1: Bituminous coal and naturalfossil energy power plants, Volume 1: Bituminous coal and

  17. Waste-tire and shingle scrap/bituminous paving test sections on the Willard Munger recreational trail gateway segment. Interim report, 1990-91

    SciTech Connect (OSTI)

    Turgeon, C.M.

    1991-02-01T23:59:59.000Z

    The need to reduce our states dependence on land fills resulted in a unique cooperative venture by three state agencies. A partnership was forged between the Minnesota Pollution Control Agency (MPCA), the Minnesota Department of Natural Resources (DNR) and the Minnesota Department of Transportation (Mn/DOT) to investigate the use of recycled tire rubber and processed asphalt shingle scrap. The result is a two mile section of the Willard Munger Recreational Trail in St. Paul constructed with asphalt paving mixtures which contain varying percentages of recycled tire rubber and shingle scrap. Conventional mixing and paving equipment was utilized for construction. The application appears to be a viable alternative to landfilling these materials. However, costs for the mixtures containing rubber increased from 35% to 50% over the cost of the conventional mixture. Since the use of shingle scrap was negotiated by the private companies involved, no comparable cost data is available.

  18. Study of mercury oxidation by a selective catalytic reduction catalyst in a pilot-scale slipstream reactor at a utility boiler burning bituminous coal

    SciTech Connect (OSTI)

    Yan Cao; Bobby Chen; Jiang Wu; Hong Cui; John Smith; Chi-Kuan Chen; Paul Chu; Wei-Ping Pan [Western Kentucky University, Bowling Green, KY (United States). Institute for Combustion Science and Environmental Technology (ICSET)

    2007-01-15T23:59:59.000Z

    One of the cost-effective mercury control technologies in coal-fired power plants is the enhanced oxidation of elemental mercury in selective catalytic reduction (SCR) followed by the capture of the oxidized mercury in the wet scrubber. This paper is the first in a series of two in which the validation of the SCR slipstream test and Hg speciation variation in runs with or without SCR catalysts inside the SCR slipstream reactor under special gas additions (HCl, Cl{sub 2}, SO{sub 2}, and SO{sub 3}) are presented. Tests indicate that the use of a catalyst in a SCR slipstream reactor can achieve greater than 90% NO reduction efficiency with a NH{sub 3}/NO ratio of about 1. There is no evidence to show that the reactor material affects mercury speciation. Both SCR catalysts used in this study exhibited a catalytic effect on the elemental mercury oxidation but had no apparent adsorption effect. SCR catalyst 2 seemed more sensitive to the operational temperature. The spike gas tests indicated that HCl can promote Hg{sup 0} oxidation but not Cl{sub 2}. The effect of Cl{sub 2} on mercury oxidation may be inhibited by higher concentrations of SO{sub 2}, NO, or H{sub 2}O in real flue-gas atmospheres within the typical SCR temperature range (300-350{sup o}C). SO{sub 2} seemed to inhibit mercury oxidation; however, SO{sub 3} may have some effect on the promotion of mercury oxidation in runs with or without SCR catalysts. 25 refs., 9 figs., 2 tabs.

  19. Emissions of airborne toxics from coal-fired boilers: Mercury

    SciTech Connect (OSTI)

    Huang, H.S.; Livengood, C.D.; Zaromb, S.

    1991-09-01T23:59:59.000Z

    Concerns over emissions of hazardous air Pollutants (air toxics) have emerged as a major environmental issue, and the authority of the US Environmental Protection Agency to regulate such pollutants was greatly expanded through the Clean Air Act Amendments of 1990. Mercury has been singled out for particular attention because of concerns over possible effects of emissions on human health. This report evaluates available published information on the mercury content of coals mined in the United States, on mercury emitted in coal combustion, and on the efficacy of various environmental control technologies for controlling airborne emissions. Anthracite and bituminous coals have the highest mean-mercury concentrations, with subbituminous coals having the lowest. However, all coal types show very significant variations in mercury concentrations. Mercury emissions from coal combustion are not well-characterized, particularly with regard to determination of specific mercury compounds. Variations in emission rates of more than an order of magnitude have been reported for some boiler types. Data on the capture of mercury by environmental control technologies are available primarily for systems with electrostatic precipitators, where removals of approximately 20% to over 50% have been reported. Reported removals for wet flue-gas-desulfurization systems range between 35 and 95%, while spray-dryer/fabric-filter systems have given removals of 75 to 99% on municipal incinerators. In all cases, better data are needed before any definitive judgments can be made. This report briefly reviews several areas of research that may lead to improvements in mercury control for existing flue-gas-clean-up technologies and summarizes the status of techniques for measuring mercury emissions from combustion sources.

  20. Future Impacts of Coal Distribution Constraints on Coal Cost

    E-Print Network [OSTI]

    McCollum, David L

    2007-01-01T23:59:59.000Z

    a particular type of coal, each of which is inherentlyThere are four classes of coal: bituminous, sub-bituminous,minerals Metallic ores Coal Crude petroleum Gasoline Fuel

  1. Prime coats materials and methods

    E-Print Network [OSTI]

    Mantilla, Christian Augusto

    1994-01-01T23:59:59.000Z

    A prime coat is the application of a suitable bituminous binder applied to a nonbituminous granular base as a preliminary treatment before the application of a bituminous surfacing. The purpose of this research is to establish practical applications...

  2. THE FURNACE COMBUSTION AND RADIATION CHARACTERISTICS OF METHANOL AND A METHANOL/COAL SLURRY

    E-Print Network [OSTI]

    Grosshandler, W.L.

    2010-01-01T23:59:59.000Z

    Emissions from Fuel Oil Combustion," Combustion, 21, August,K #4 Fuel Oil Bituminous Coal (Group 4) The lower combustion

  3. National Level Co-Control Study of the Targets for Energy Intensity and Sulfur Dioxide in China

    E-Print Network [OSTI]

    Zhou, Nan

    2013-01-01T23:59:59.000Z

    Coal {bituminous} Coke Heavy Oil Natural Gas Electricity EAFoil and natural gas ( heavy fuel oil electricity generation

  4. Development of a pilot-scale kinetic extruder feeder system and test program. Phase I report

    SciTech Connect (OSTI)

    None

    1982-03-01T23:59:59.000Z

    This report describes the work done under Phase I, the moisture tolerance testing of the Kinetic Extruder. The following coals were used in the test program: Western Bituminous (Utah), Eastern Bituminous (Pennsylvania), North Dakota Lignite, Sub-Bituminous (Montana), and Eastern Bituminous coal mixed with 20-percent Limestone. The coals were initially tested at the as-received moisture level and subsequently tested after surface moisture was added by water spray. Test results and recommendations for future research and development work are presented.

  5. Supporting Information for Historical gaseous and primary aerosol emissions in

    E-Print Network [OSTI]

    Meskhidze, Nicholas

    2104002XXX Bituminous/ Subbituminous Coal Distillate oil 2104004XXX Distillate Oil SO2, PM Natural gas Bituminous/ Subbituminous Coal 101003XX Lignite 2101002XXX Electric Utility Bituminous/ Subbituminous Coal Residual oil 101004XX External Combustion Boilers Residual Oil NOx, SO2, PM 2101005XXX Electric Utility

  6. ITP Mining: Energy and Environmental Profile of the U.S. Mining...

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

    1 Combustion Engineering, Combustion-Fossil Power, Chapter 2-7, 1991. Coal 2-1 Energy and Environmental Profile of the U.S. Mining Industry Anthracite - Hard and very...

  7. NETL Report format template

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

    Bituminous Baseline Performance and Cost Interactive Tool Documentation November 18, 2010 Disclaimer This report was prepared as an account of work sponsored by an agency of the...

  8. THE CHEMISTRY OF COAL MODEL COMPOUNDS -CLEAVAGE OF ALIPHATIC BRIDGES BETWEEN AROMATIC NUCLEI CATALYSED BY LEWIS ACIDS

    E-Print Network [OSTI]

    Taylor, Newell D.

    2011-01-01T23:59:59.000Z

    and Background I. II. III. IV. II. Coal Liquefaction . •Coal Structure • • . Lewis Acid Catalysts. Scope andOrganic Structure of Bituminous Coal", Proceedings, Stanford

  9. ZINC CHLORIDE-CATALYZED REACTIONS OF OXYGEN- AND SULFUR-CONTAINING COMPOUNDS WITH MODEL STRUCTURES IN COAL

    E-Print Network [OSTI]

    Mobley, David Paul

    2013-01-01T23:59:59.000Z

    H. H. , ed. , "Chemistry of Coal Utilization", Suppl. Vol. ,H. H. , ed. , "Chemistry of Coal Utilization", Suppl. Vol. ,Internat. Conf. Bituminous Coal, 3d Con£. , 2, 35 (1932);

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

    E-Print Network [OSTI]

    Croft, Gregory Donald

    2009-01-01T23:59:59.000Z

    historical trends in coal seam thickness and depth andanthracite and bituminous coal seams exceeding 28 inches indepths in ever thinner coal seams. The goal of Part I of

  11. Assessment of China's Energy-Saving and Emission-Reduction Accomplishments and Opportunities During the 11th Five Year Plan

    E-Print Network [OSTI]

    Levine, Mark D.

    2010-01-01T23:59:59.000Z

    Swedish National Energy Administration ton coal equivalenttCO 2 ) Energy Electricity * bituminous coal Costs areare needed, such as energy price reform (coal, electricity,

  12. Energy Efficiency Improvement and Cost Saving Opportunities for the U.S. Iron and Steel Industry An ENERGY STAR(R) Guide for Energy and Plant Managers

    E-Print Network [OSTI]

    Worrell, Ernst

    2011-01-01T23:59:59.000Z

    In addition, the coking coal market began to deteriorateits permeability. Bituminous, or coking coal, is blended andmerchant coke plants, coking coal is heated in a low-oxygen,

  13. Inventory of China's Energy-Related CO2 Emissions in 2008

    E-Print Network [OSTI]

    Fridley, David

    2011-01-01T23:59:59.000Z

    gas petroleum waxes coking coal t C/TJ other bituminous coalprocesses of coal washing, coking, petroleum refineries, gaslosses include coal washing, coking, petroleum refining, gas

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

    E-Print Network [OSTI]

    Lu, Xiaoming

    2012-01-01T23:59:59.000Z

    1: Bituminous coal and natural gas to electricity. DOE/NETL-M, Williams E. Synthetic natural gas (SNG): Technology,2009. 105. Overview of Natural Gas in California. California

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

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

    Baseline for Fossil Energy Plants, Volume 1: Bituminous Coal and Natural Gas to Electricity, Revision 2 CO2 Capture Ready Coal Power Plants Assessment of Hydrogen Production...

  16. The establishment, growth, and forage production of five grass species during their first growing season on an upland postoak site in Brazos County, Texas

    E-Print Network [OSTI]

    Adcock, Willie Leroy

    1954-01-01T23:59:59.000Z

    showing good growth and its erect culms on July 16, 1953 King Ranch bluestem on July 16, 1953, showing its sprawling culms and slow initial growth 31 32 32 14. Silver beardgrass on July 16, 1953. Growth compares favorably with that of RF472... and isolation strips. When plantings were made and when readings were taken of the plots, the inside plots A I' ) Replications V Poi Poi Pci Bou 4sa RF472 Asa RF472 Asa Asa 4is N Bou Poi Cheek Asa RF472 Asa Ais Cheok Pci 1. 9 ' Cheek Bou Asa RF...

  17. Response of Pan American Balsamscale, Soil, and Livestock to Prescribed Burning.

    E-Print Network [OSTI]

    Mutz, J.L.; Greene, T.G.; Scifres, C.J.; Koerth, B.H.

    1985-01-01T23:59:59.000Z

    and November 4, 1982 and on May 7 and October 21 , 1983 were measured by clipping vegetation to ground line in 10 randomly placed 0.25 m2 quad rats per subplot. Herbage was separated into grasses and forbs be fore ovendrying and weighing. Mulch... tiller was defined as a living stem or whorl of leaves of any size originating from the base of the plant. Reproductive culms on tagged plants were counted on June 15 and November 3, 1982. Only culms bear ing infloresences were counted...

  18. The influence of burning on nitrogen dynamics of a Pan American balsamscale community

    E-Print Network [OSTI]

    Greene, Thomas Alexander

    1983-01-01T23:59:59.000Z

    at various dates near Cuero, Texas. 35 Table 12. Soi. l water content as g of dry weight at three depths in 1982 on plots burned at, various dates near Cuero, Texas' Table 13. Cumulative rainfall (mm) from March 12 to November 4, 1982, near Cuero, Texas.... Change in tiller number was calculated. for each plant as a percentage of numbers the previous month. Reproductive culms on individual tagged. plants were counted on June 15 and November 5, 1982. Only culms bearing inflorescences were counted...

  19. Coal is a combustible sedimentary rock and a valuable economic resource. During the Pennsylvanian Period

    E-Print Network [OSTI]

    Polly, David

    Coal is a combustible sedimentary rock and a valuable economic resource. During the Pennsylvanian of years produced the bituminous coals currently found in southwestern Indiana. Bituminous coals in Indiana currently ranks as the seventh-largest coal-producing state in the nation and has an estimated 17.57 billion

  20. Determination of Mercury in Coal by Isotope Dilution Cold-Vapor Generation Inductively

    E-Print Network [OSTI]

    Articles Determination of Mercury in Coal by Isotope Dilution Cold-Vapor Generation Inductively. Approximately 93% of U.S. coal consumption is used to generate electricity, and the U.S. EPA has estimated2 developed for high-accuracy determinations of mer- cury in bituminous and sub-bituminous coals. A closed

  1. SUPPORTING INFORMATION Properties of Activated Carbon Powders and Their Influence on Oxygen

    E-Print Network [OSTI]

    SUPPORTING INFORMATION Properties of Activated Carbon Powders and Their Influence on Oxygen pages, 4 figures) #12;2 Figure S1: Example of RDE LSV data for bituminous coal based sample (B1: Example of K­L analysis for bituminous coal based sample (B1) where the slope of the line is used

  2. Study of physical and chemical properties of vitrinites. Inferences on depositional and coalification controls

    E-Print Network [OSTI]

    Paris-Sud XI, Université de

    , textural and coking properties was carried out on vitrains from the Puertollano, Blanzy­Montçeau, Asturias (subbituminous/high volatile C bituminous coals). The characteristics of the Puertollano vitrains described here can also be attributed to the telocollinite (>80% vol.) for the high volatile C bituminous coal

  3. Fly Ash Amendments Catalyze Soil Carbon Sequestration

    SciTech Connect (OSTI)

    Amonette, James E.; Kim, Jungbae; Russell, Colleen K.; Palumbo, A. V.; Daniels, William L.

    2003-09-15T23:59:59.000Z

    We tested the effects of four alkaline fly ashes {Class C (sub-bituminous), Class F (bituminous), Class F [bituminous with flue-gas desulfurization (FGD) products], and Class F (lignitic)} on a reaction that simulates the enzyme-mediated formation of humic materials in soils. The presence of FGD products completely halted the reaction, and the bituminous ash showed no benefit over an ash-free control. The sub-bituminous and lignitic fly ashes, however, increased the amount of polymer formed by several-fold. The strong synergetic effect of these ashes when enzyme is present apparently arises from the combined effects of metal oxide co-oxidation (Fe and Mn oxides), alkaline pH, and physical stabilization of the enzyme (porous silica cenospheres).

  4. Abstract--`Rocker' tanglehead (Heteropogon contortus [L.] Beauv. ex Roem. and J.A. Schultes) is a perennial, warm-season

    E-Print Network [OSTI]

    as well as terminating the main culm; Rachis joints readily disarticulating at maturity; Glumes four accessions were transplanted into a spaced plant, mass selection block for evaluation and final selection block have shown that Rocker averages a size of 120 cm by 120 cm versus an average size of all

  5. Prediction of metallurgical coke strength from the petrographic composition of coal blends

    SciTech Connect (OSTI)

    Sutcu, H.; Toroglu, I.; Piskin, S. [Zonguldak Karaelmas University, Zonguldak (Turkey)

    2009-07-01T23:59:59.000Z

    Turkey, especially Zonguldak on the West Coast of Black Sea region, has large reserves of bituminous coal that can be used either directly or in blends with other coals for metallurgical coke production. It is possible to predict the coking properties of these coals by petrographic analysis. In this study, semi- and non-coking coals were blended with coking bituminous coals in varying proportions and an estimation was made as to their stability factors through petrographic techniques. It was established that semi- and non-coking bituminous coals could be used in the production of metallurgical coke.

  6. Vitrinite reflectance anisotropy as a tectonic fabric element

    SciTech Connect (OSTI)

    Hower, J.C. (Univ. of Kentucky, Lexington); Davis, A.

    1981-04-01T23:59:59.000Z

    The anisotropy of the coal maceral vitrinite was analyzed in relation to the tectonic setting of a coal from the Southern Anthracite Field in Pennsylvania. For the coal studied, the maximum-intermediate reflectance plane essentially paralleled the axial plane of the synclinorium (N66/sup 0/E strike, 64/sup 0/SE dip).

  7. Coal liquefaction process using pretreatment with a binary solvent mixture

    DOE Patents [OSTI]

    Miller, Robert N. (Allentown, PA)

    1986-01-01T23:59:59.000Z

    An improved process for thermal solvent refining or hydroliquefaction of non-anthracitic coal at elevated temperatures under hydrogen pressure in a hydrogen donor solvent comprises pretreating the coal with a binary mixture of an aromatic hydrocarbon and an aliphatic alcohol at a temperature below 300.degree. C. before the hydroliquefaction step. This treatment generally increases both conversion of coal and yields of oil.

  8. Carbon Vol. 28, Nos. 213. pp. 261-279, 1990 Printed in Great Britain.

    E-Print Network [OSTI]

    : carbon formation from catalyzed CO decomposition over iron and from liquid phase coking of hydrocarbons. preparation of carbons via catalytic cracking of CO and coking processes, 2. carbon active sites of concern. In par- ticular. we envisioned gasifying plentiful anthracite coal, with its attendant mineral matter

  9. Lamh Foisdineach An Uachtar Eleventh Night

    E-Print Network [OSTI]

    Oxford, University of

    , Men with metal arms, men with no face on. #12;Lamh Foisdineach An Uachtar Poem for Charlotte Slow of a heavy, ready ewe, and the anthracite mounds of heavy-lidded cows snorting in their hide. We're lulled, quarreling gulls trawl in the downpour, my feet crunch the brittle shingle on the ground. I have tried

  10. Catalysts for coal liquefaction processes

    DOE Patents [OSTI]

    Garg, D.

    1986-10-14T23:59:59.000Z

    Improved catalysts for catalytic solvent refining or hydroliquefaction of non-anthracitic coal at elevated temperatures under hydrogen pressure in a hydrogen donor solvent comprise a combination of zinc or copper, or a compound thereof, and a Group VI or non-ferrous Group VIII metal, or a compound thereof.

  11. Catalytic coal liquefaction process

    DOE Patents [OSTI]

    Garg, D.; Sunder, S.

    1986-12-02T23:59:59.000Z

    An improved process for catalytic solvent refining or hydroliquefaction of non-anthracitic coal at elevated temperatures under hydrogen pressure in a solvent comprises using as catalyst a mixture of a 1,2- or 1,4-quinone and an alkaline compound, selected from ammonium, alkali metal, and alkaline earth metal oxides, hydroxides or salts of weak acids. 1 fig.

  12. China Energy Databook - Rev. 4

    E-Print Network [OSTI]

    Sinton Editor, J.E.

    2010-01-01T23:59:59.000Z

    bituminous coal, and brown coal, but not slaty coal. Figureston) f 19.92 to 33. II Brown coals, lignites (metric ton) fcoal, and 13%, lignite (brown coal). Coal bed methane may

  13. China Energy Databook -- User Guide and Documentation, Version 7.0

    E-Print Network [OSTI]

    Fridley, Ed., David

    2008-01-01T23:59:59.000Z

    Subtotal Lignite and Brown Coal Total Source: NBS, ChinaSubtotal Lignite and Brown Coal Total Source: NBS, ChinaGt) Coal Classification brown coal bituminous coal gas coal

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

    E-Print Network [OSTI]

    Lu, Xiaoming

    2012-01-01T23:59:59.000Z

    5. Power generation via IGCC from bituminous coal. It shouldElectricity Generation (KWh/gallon FT Liquid) Coal-to-PowerElectricity Generation (KWh/gallon FT Liquid) Coal-to-Power

  15. COAL LIQUEFACTION STUDIES USING PHOSPHORIC ACID AT MODERATE TEMPERATURES AND PRESSURES

    E-Print Network [OSTI]

    McLean, J.B.

    2010-01-01T23:59:59.000Z

    Analys of Wyodak Roland Seam Coal Froximate Analysis C,T. &THF-extractabilities of a seam coal increased from 12% MAFused Wyodak Roland seam sub-bituminous coal. Consistent with

  16. A Comparison of Iron and Steel Production Energy Use and Energy Intensity in China and the U.S.

    E-Print Network [OSTI]

    Hasanbeigi, Ali

    2012-01-01T23:59:59.000Z

    other bituminous coal and coking coal. Small differences incoal (used as fuel) Coking coal Coke oven coke Natural gasrange for typical NCVs of coking coal of 26.6 to 29.8Mj/kg.

  17. A Comparison of Iron and Steel Production Energy Use and Energy Intensity in China and the U.S.

    E-Print Network [OSTI]

    Hasanbeigi, Ali

    2012-01-01T23:59:59.000Z

    other bituminous coal and clean coal. The NCV used in theadded to the rest of the clean coal used in the industry andand added to the reported clean coal used as a fuel in the

  18. asian villages asia: Topics by E-print Network

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

    GCLS AND BITUMINOUS GEOMEMBRANES H. Bannour1 regarding the behavior of geosynthetic clay liners (GCLs) as part of a composite liner, focused Paris-Sud XI, Universit de 68...

  19. asian regional cooperation: Topics by E-print Network

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

    GCLS AND BITUMINOUS GEOMEMBRANES H. Bannour1 regarding the behavior of geosynthetic clay liners (GCLs) as part of a composite liner, focused Paris-Sud XI, Universit de 170...

  20. asian regional conference: Topics by E-print Network

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

    GCLS AND BITUMINOUS GEOMEMBRANES H. Bannour1 regarding the behavior of geosynthetic clay liners (GCLs) as part of a composite liner, focused Paris-Sud XI, Universit de 15...

  1. asia oceania region: Topics by E-print Network

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

    GCLS AND BITUMINOUS GEOMEMBRANES H. Bannour1 regarding the behavior of geosynthetic clay liners (GCLs) as part of a composite liner, focused Paris-Sud XI, Universit de 105...

  2. The variability of fly ash and its effects on selected properties of fresh Portland cement/fly ash mortars

    E-Print Network [OSTI]

    McKerall, William Carlton

    1980-01-01T23:59:59.000Z

    the needed quality control of concrete . Another source of concern results from the recent development of lignite and sub-bituminous coal as fuel sources. The ash produced from these coals is of a different chemical composition than traditional bituminous... 50 percent to greater than 200 percent of a control test. An exhaustive literature review has revealed neglig1ble information concerning the PAI of sub- b1tuminous and lignite ashes. Research is greatly needed to determine the ash properties...

  3. CO{sub 2} Sequestration Potential of Charqueadas Coal Field in Brazil

    SciTech Connect (OSTI)

    Romanov, V [NETL

    2012-10-23T23:59:59.000Z

    The I2B coal seam in the Charqueadas coal field has been evaluated as a target for enhanced coal bed methane production and CO{sub 2} sequestration. The samples were low rank coals (high volatile bituminous and sub-bituminous) obtained from the I2B seam as ?3? cores. Such properties as sorption capacity, internal structure of the samples, porosity and permeability were of primary interest in this characterization study.

  4. CONDITIONING TECHNOLOGY FOR RADIOACTIVE WASTE RESULTED FROM THE TREATMENT OF LIQUID WASTE FROM THE ROMANIAN NUCLEAR POWER PLANT

    SciTech Connect (OSTI)

    ARSENE, CARMEN; ANDREI, VERONICA; NEGOIU, DUMITRU

    2003-02-27T23:59:59.000Z

    For the conditioning of spent resins contaminated with radionuclides, such as: 137Cs, 134Cs, 60Co, 58Co, 57Co, 54Mn, etc., techniques of direct immobilization in cement, bitumen and organic polymers have been tested. The selected process was the bituminization using industrial bitumen, I 60-70, made in Romania, which had very good characteristics. The paper presents stages of the research project, technical conditions for the process and advantages of the bituminization of spent resins.

  5. A kinetic model for the liquefaction of Texas lignite 

    E-Print Network [OSTI]

    Haley, Sandra Kay

    1980-01-01T23:59:59.000Z

    the Wilcox formation was uti- lized. Previous dissolution studies were conducted with bituminous ard subbituminous coals mined in other states. Secondly, the methods This thesis follows the style of the AIChE Journal. of analysis employed on the reaction... conditions, coal characteristics, catalyst effects), others delved into the kinetics and attempted to model their systems. Wiser (1968) utilized a Utah high-volatile bituminous coal and conducted thermal dissolution studies at temperatures ranging from...

  6. Seed production characteristics and photoperiodic responses in buffelgrass: [Pennisetum ciliare L. (Link.)

    E-Print Network [OSTI]

    Evers, Gerald Wayne

    1968-01-01T23:59:59.000Z

    - hour photoperiod. 50 14. Nean temperatures outside and inside the photo- control frame 51 15. New second year growth of Common and Blue buffelgrass on April 23, 1967 vi LIST OF TABLES Table Inflorescence and culm number in buffelgrass lines... in 1966 and 1967. Parcae 26 Involucres per inflorescence in five lines of buffelgrass in first-yeax seed production study . 28 Means of observation of six inflozescence char- acteristics in buffelgrass in the 1966 and 1967 study. 32 Number of days...

  7. Process for increasing the bitumen content of oil sands froth

    SciTech Connect (OSTI)

    Tipman, R.N.; Rajan, V.S.V.; Wallace, D.

    1993-06-29T23:59:59.000Z

    A process is described for the removal of solids and water from a feed bituminous froth containing bitumen, solids and water in a gravity settling vessel have an existing bituminous froth layer floating on a quiescent body of water defining a bitumen-water interface therebetween comprising the steps of heating the feed bituminous froth to a temperature in the range of 85 to 100 C, feeding the heated froth into the body of water at a level below the bitumen-water interface whereby water and solids contained in the feed froth separate from the froth and the bitumen rises to accumulate in the existing bituminous froth layer, discharging solids-containing under flow from the vessel, monitoring the level of the bitumen-water interface and controlling the discharge of solids-containing under flow responsive to the monitoring of the bitumen-water interface at a rate such that the said interface is maintained at an effective level above the level at which the feed bituminous froth is fed into the body of water, and recovering a bitumen-enriched layer as an overflow.

  8. Coal liquefaction process using pretreatment with a binary solvent mixture

    DOE Patents [OSTI]

    Miller, R.N.

    1986-10-14T23:59:59.000Z

    An improved process for thermal solvent refining or hydroliquefaction of non-anthracitic coal at elevated temperatures under hydrogen pressure in a hydrogen donor solvent comprises pretreating the coal with a binary mixture of an aromatic hydrocarbon and an aliphatic alcohol at a temperature below 300 C before the hydroliquefaction step. This treatment generally increases both conversion of coal and yields of oil. 1 fig.

  9. Water filtration optimization by geometric programming

    E-Print Network [OSTI]

    Wray, Duane Jimmy

    1970-01-01T23:59:59.000Z

    important as a means of removing suspended and colloidal matter. Sand is the most commonly used filter media but is rapidly being replaced by a combination of anthracite, sand, and garnet for faster filtration rates. Due to the complexity... of the filtering process, the design of these filters has remained an art without ever progressing to a science. Filters are in general designed from experience and rules of thumb without any assurance that maximum efficiency is attained at minimum cost. A...

  10. Exploratory research on novel coal liquefaction concept. Progress report, April 1, 1996--June 30, 1996

    SciTech Connect (OSTI)

    Burke, F.P.; Brandes, S.D.; Winschel, R.A.

    1996-08-12T23:59:59.000Z

    Activities this quarter were conducted under Tasks 2, 3, and 5. Task 2 work concentrated on evaluating the effects of low-severity, first-stage reaction conditions on coal conversions of lignite, subbituminous, and bituminous coals. The impact of artificially weathering bituminous coal was investigated. Large quantities of first-stage product were made using the one-liter reactor for subsequent filtration and catalytic upgrading tests. Test conditions and coal conversions for all microautoclave and one-liter tests made this quarter are presented. Filtration tests examined lignite, subbituminous, and bituminous coal products. The effects on resid conversion of second-stage reaction conditions and catalyst recycle were studied. Task 3 work included the successful transfer of first-stage reactor products to a receiver and the design of an interstage filter. Task 5 work included an ongoing review of the technical and patent literature and expansion of the annotated bibliography. Mass and elemental balances were obtained for selected tests.

  11. Near-Zero Emissions Oxy-Combustion Flue Gas Purification - Power Plant Performance

    SciTech Connect (OSTI)

    Andrew Seltzer; Zhen Fan

    2011-03-01T23:59:59.000Z

    A technical feasibility assessment was performed for retrofitting oxy-fuel technology to an existing power plant burning low sulfur PRB fuel and high sulfur bituminous fuel. The focus of this study was on the boiler/power generation island of a subcritical steam cycle power plant. The power plant performance in air and oxy-firing modes was estimated and modifications required for oxy-firing capabilities were identified. A 460 MWe (gross) reference subcritical PC power plant was modeled. The reference air-fired plant has a boiler efficiency (PRB/Bituminous) of 86.7%/89.3% and a plant net efficiency of 35.8/36.7%. Net efficiency for oxy-fuel firing including ASU/CPU duty is 25.6%/26.6% (PRB/Bituminous). The oxy-fuel flue gas recirculation flow to the boiler is 68%/72% (PRB/bituminous) of the flue gas (average O{sub 2} in feed gas is 27.4%/26.4%v (PRB/bituminous)). Maximum increase in tube wall temperature is less than 10ºF for oxy-fuel firing. For oxy-fuel firing, ammonia injected to the SCR was shut-off and the FGD is applied to remove SOx from the recycled primary gas stream and a portion of the SOx from the secondary stream for the high sulfur bituminous coal. Based on CFD simulations it was determined that at the furnace outlet compared to air-firing, SO{sub 3}/SO{sub 2} mole ratio is about the same, NOx ppmv level is about the same for PRB-firing and 2.5 times for bituminous-firing due to shutting off the OFA, and CO mole fraction is approximately double. A conceptual level cost estimate was performed for the incremental equipment and installation cost of the oxyfuel retrofit in the boiler island and steam system. The cost of the retrofit is estimated to be approximately 81 M$ for PRB low sulfur fuel and 84 M$ for bituminous high sulfur fuel.

  12. Resource characterization series (final)

    SciTech Connect (OSTI)

    Hower, J.C.; Wild, G.D.

    1981-01-01T23:59:59.000Z

    Coals from the Princess Reserve District in northeastern Kentucky were obtained from the R-series cores and from Kentucky Geological Survey collections. The coals span the stratigraphic section from the Bruin coal near the base of the Breathitt Formation to a coal near the top of the Conemaugh Formation. The Princess District coals are high volatile C and B bituminous. High volatile A bituminous coals occur in southern Lawrence County. Reflectance highs and reactive maceral lows were noted in the Princess 3 and Princess 7 coals in along a north-south trend which may be parallel to the Waverly Arch.

  13. Reactions of oats to Helminthosporium victoriae as reflected by different inoculation procedures and a search for new sources of resistance in radiated oats

    E-Print Network [OSTI]

    Raab, Quinton Joe

    1957-01-01T23:59:59.000Z

    ~. Ih~ data showed that the text produced the same symptoms as the organ- ism Twc days after treatment with the tox1n the seedlings were em- andned fer resistancen Prom this mass screening 973 seedlings were fanngt h r ttantt H ttnt H k(5)abg t&I!4... were obtained fram 200 seeds of a susceptible variety of cats that were sub)ected to 25~000 r units of X-radiations, A number of strains were found te be resistant te stem rust under field conditions, Earhart (2) reported that a culm rett1ng...

  14. Erroneous coal maturity assessment caused by low temperature oxidation

    E-Print Network [OSTI]

    Paris-Sud XI, Université de

    Erroneous coal maturity assessment caused by low temperature oxidation Y. Copard J. R. Disnar, J. F on different outcrop coals from the French Massif Central revealed abnormally high Tmax values, which initially observed for medium to low volatile bituminous coals (Rr1.5%), was accompanied by a very clear exponential

  15. METHANE de-NOX for Utility PC Boilers

    SciTech Connect (OSTI)

    Bruce Bryan; Joseph Rabovitser; Serguei Nester; Stan Wohadlo

    2004-09-30T23:59:59.000Z

    Large-scale PRB testing during the current quarter was cut short due to the inability of the coal mill to meet the 85 MMBtu/h design firing rate. The project was therefore redirected toward design, installation and testing of the 85-million Btu/h preheater for bituminous coal. Based on extensive pilot-scale testing completed earlier in the project, 2-D modeling and preliminary design activities were started based on the use of staged, annular protective air films to control temperature and prevent deposition on the preheater walls. A total of 14 2-D modeling cases were completed for the modified preheater for bituminous coal. The preheater concept modeled was based on an expanding preheater chamber where the diameter of the chamber is increased in steps along its length and annular cooling/protective air is introduced at each step. A process flow diagram for the bituminous coal preheating system and a preliminary preheater design drawing were developed based on the modeling results. A project schedule to complete design, installation and testing of the 85 MMBtu/h bituminous coal preheating system before the end of December was also developed.

  16. Sorption of MS2 Bacteriophage to Layered Double Hydroxides: Effects of Reaction Time, pH, and Competing Anions

    E-Print Network [OSTI]

    Sparks, Donald L.

    that some materials such as coal-based media, clay minerals, metal oxides­hydroxides, and activated very high retention capacities for from an aqueous solution by bituminous coal (Oza and MS2. Sorption) from 5.2 102 plaque-forming units (pfu)/mL solution by Mg­Al reported that some coal-based media

  17. Investigation Of Synergistic NOx Reduction From Cofiring And Air Staged Combustion Of Coal And Low Ash Dairy Biomass In A 30 Kilowatt Low NOx Furnace

    E-Print Network [OSTI]

    Lawrence, Benjamin Daniel

    2013-08-01T23:59:59.000Z

    to address this concern. DB is evaluated as a cofired fuel with Wyoming Powder River Basin (PRB) sub-bituminous coal in a small-scale 29 kW_(t) low NO_(x) burner (LNB) facility. Fuel properties, of PRB and DB revealed the following: a higher heating value...

  18. 0 2 4 6 8 10 12 14 Effective Stress(MPa)

    E-Print Network [OSTI]

    Stanford University

    and Transport Properties of Low-Rank Coal, PRB, WY: Implications for Carbon Sequestration with CH4. Origin: PRB, WY, Fort Union Forma on, Roland and Smith Coal Zone Rank: sub-bituminous Microfracture and cleats So , easy to break Origin: PRB, Montana, Wyodak-Anderson coal zone Rank

  19. NOx, SOx & CO{sub 2} mitigation using blended coals

    SciTech Connect (OSTI)

    Labbe, D.

    2009-11-15T23:59:59.000Z

    Estimates of potential CO{sub 2} reduction achievable through the use of a mixture of bituminous and subbituminous (PRB) coals, whilst attaining NOx and SOx compliance are presented. The optimization considerations to provide satisfactory furnace, boiler and unit performance with blended coal supplies to make such operation feasible are discussed. 6 refs., 7 figs., 1 tab.

  20. Influence of coal on coke properties and blast-furnace operation

    SciTech Connect (OSTI)

    G.R. Gainieva; L.D. Nikitin [OAO Zapadno-Sibirskii Metallurgicheskii Kombinat (Russian Federation)

    2007-07-01T23:59:59.000Z

    With unstable coal supplies and properties and a fluctuating content of coking coal in the batch at OAO Zapadno-Sibirskii Metallurgicheskii Kombinat (ZSMK) and of bituminous coal at Kuznetskaya enrichment facility, it is important to optimize the rank composition of the batch for coke production.

  1. REMEDIAT1NG AT MANUFACTURED GAS

    E-Print Network [OSTI]

    Peters, Catherine A.

    , comhusti- hle gas manufactured Pfrom coke, coal, and oil 1 served as the major gas- eous fuel for urban for the three primary gas production meth- ods: coal carbonization, carbureted water gas production, and oil gas, and metals. Tar resid- uals were produced from the vola- tiIe component of bituminous coals in coal

  2. Cold in-place recycling with bitumen emulsion Animesh Das1

    E-Print Network [OSTI]

    Das, Animesh

    Cold in-place recycling with bitumen emulsion Animesh Das1 Introduction The cold in-place recycling (CIPR) is a process where the existing bituminous pavement is recycled without application of heat breaking (depends on temparture, humidity and wind), the breakdown rolling is initiated with large rubber-tired

  3. USE OF DISTRIBUTED FIBER OPTIC SENSORS TO DETECT DAMAGE IN A Xavier Chapeleau

    E-Print Network [OSTI]

    Paris-Sud XI, Université de

    USE OF DISTRIBUTED FIBER OPTIC SENSORS TO DETECT DAMAGE IN A PAVEMENT Xavier Chapeleau 1 , Juliette strains and crack initiation. These first tests demonstrate that distributed fiber optic sensor based, by monitoring strain profiles in the bituminous layers. KEYWORDS: Distributed fiber optic sensor, asphalt

  4. Recent technologies and processes for enhanced safety in bitumen or cement solidification of Li/ml radwaste

    SciTech Connect (OSTI)

    Tchemitcheff, F.

    1993-12-31T23:59:59.000Z

    SGN has more than 20 years of experience in the treatment of low and medium level radioactive wastes. SGN industrialized two major types of radwaste processes: bituminization and cement solidification. The R&D work on these two processes is discussed.

  5. (Basic properties of coals and other solids)

    SciTech Connect (OSTI)

    Not Available

    1991-11-25T23:59:59.000Z

    This report discusses basic properties of bituminous, subbituminous, and lignite coals. Properties of coal liquids are also investigated. Heats of immersion in strong acids are found for Pittsburgh {number sign}8, Illinois {number sign}6, and Wyodak coals. Production of coal liquids by distillation is discussed. Heats of titration of coal liquids and coal slurries are reported. (VC)

  6. [Basic properties of coals and other solids]. Eighth quarterly report, [September--November 1991

    SciTech Connect (OSTI)

    Not Available

    1991-11-25T23:59:59.000Z

    This report discusses basic properties of bituminous, subbituminous, and lignite coals. Properties of coal liquids are also investigated. Heats of immersion in strong acids are found for Pittsburgh {number_sign}8, Illinois {number_sign}6, and Wyodak coals. Production of coal liquids by distillation is discussed. Heats of titration of coal liquids and coal slurries are reported. (VC)

  7. Transuranic contaminated waste form characterization and data base

    SciTech Connect (OSTI)

    Kniazewycz, B.G.; McArthur, W.C.

    1980-07-01T23:59:59.000Z

    This volume contains appendices A to F. The properties of transuranium (TRU) radionuclides are described. Immobilization of TRU wastes by bituminization, urea-formaldehyde polymers, and cements is discussed. Research programs at DOE facilities engaged in TRU waste characterization and management studies are described.

  8. Rencontres Gosynthtiques -9-11 avril 2013, Dijon DBITS DANS UNE TANCHIT COMPOSITE GOMEMBRANE

    E-Print Network [OSTI]

    Paris-Sud XI, Université de

    years regarding the behaviour of geosynthetic clay liners (GCLs) as part of a composite liner composed, geosynthetic clay liner, bituminous geomembrane, flow rate 1. Introduction Les géomembranes bitumineuses (GM to an alternative design for a canal projected in France at the moment. Keywords: Geosynthetics, composite liners

  9. EARLY ENTRANCE CO-PRODUCTION PLANT - DECENTRALIZED GASIFICATION COGENERATION TRANSPORTATION FUELS AND STEAM FROM AVAILABLE FEEDSTOCKS

    SciTech Connect (OSTI)

    Unknown

    2003-01-01T23:59:59.000Z

    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.

  10. EARLY ENTRANCE CO-PRODUCTION PLANT-DECENTRALIZED GASIFICATION COGENERATION TRANSPORTATION FUELS AND STEAM FROM AVAILABLE FEEDSTOCKS

    SciTech Connect (OSTI)

    Unknown

    2002-07-01T23:59:59.000Z

    Waste Processors Management, Inc. (WMPI), along with its subcontractors entered into a Cooperative Agreement with the US Department of Energy (DOE) and the 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 2 is an experimental testing program designed to validate the coal waste mixture gasification performance. Phase 3 updates the original EECP design based on results from Phase 2, 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 April 1, 2002 through June 30, 2002.

  11. Close-coupled Catalytic Two-Stage Liquefaction (CTSL{trademark}) process bench studies. Final report, [October 1, 1988--July 31, 1993

    SciTech Connect (OSTI)

    Comolli, A.G.; Johanson, E.S.; Karolkiewicz, W.F.; Lee, L.K.; Popper, G.A.; Stalzer, R.H.; Smith, T.O.

    1993-06-01T23:59:59.000Z

    This is the final report of a four year and ten month contract starting on October 1, 1988 to July 31, 1993 with the US Department of Energy to study and improve Close-Coupled Catalytic Two-Stage Direct Liquefaction of coal by producing high yields of distillate with improved quality at lower capital and production costs in comparison to existing technologies. Laboratory, Bench and PDU scale studies on sub-bituminous and bituminous coals are summarized and referenced in this volume. Details are presented in the three topical reports of this contract; CTSL Process Bench Studies and PDU Scale-Up with Sub-Bituminous Coal-DE-88818-TOP-1, CTSL Process Bench Studies with Bituminous Coal-DE-88818-TOP-2, and CTSL Process Laboratory Scale Studies, Modelling and Technical Assessment-DE-88818-TOP-3. Results are summarized on experiments and studies covering several process configurations, cleaned coals, solid separation methods, additives and catalysts both dispersed and supported. Laboratory microautoclave scale experiments, economic analysis and modelling studies are also included along with the PDU-Scale-Up of the CTSL processing of sub-bituminous Black Thunder Mine Wyoming coal. During this DOE/HRI effort, high distillate yields were maintained at higher throughput rates while quality was markedly improved using on-line hydrotreating and cleaned coals. Solid separations options of filtration and delayed coking were evaluated on a Bench-Scale with filtration successfully scaled to a PDU demonstration. Directions for future direct coal liquefaction related work are outlined herein based on the results from this and previous programs.

  12. Quantum Field Effects in Stationary Electron Spin Resonance Spectroscopy

    E-Print Network [OSTI]

    Dmitri Yerchuck; Vyacheslav Stelmakh; Yauhen Yerchak; Alla Dovlatova

    2015-01-28T23:59:59.000Z

    It is proved on the example of electron spin resonance (ESR) studies of anthracites, that by strong electron-photon and electron-phonon interactions the formation of the coherent system of the resonance phonons takes place. The acoustic quantum Rabi oscillations were observed for the first time in ESR-spectroscopy. Its Rabi frequency value on the first damping stage was found to be equal 920.6 kHz, being to be independent on the microwave power level in the range 20 - 6 dB [0 dB corresponds to 100 mW]. By the subsequent increase of the microwave power the stepwise transition to the phenomenon of nonlinear quantum Rabi oscillations, characterised by splitting of the oscillation group of lines into two subgroups with doubling of the total lines' number takes place. Linewidth of an individual oscillation line becomes approximately the twofold narrower, being to be equal the only to $0.004 \\pm 0.001$ G. Along with the absorption process of EM-field energy the emission process was observed. It was found, that the emission process is the realization of the acoustic spin resonance, the source of acoustic wave power in which is the system of resonance phonons, accumulated in the samples by the registration with AFC. It has been found, that the lifetime of coherent state of a collective subsystem of resonance phonons in anthracites is very long and even by room temperature it is evaluated by the value exceeding 4.6 minutes. The model of new kinds of instantons was proposed. They are considered to be similar in the mathematical structure to Su-Schrieffer-Heeger solitons with "propagation" direction along time $t$-axis instead of space $z$-axis. The proof, that the superconductivity state in the anthracite samples studied is produced at the room temperature in ESR conditions in the accordance with the theory of the quantised acoustic field, has experimentally been obtained.

  13. Create a Consortium and Develop Premium Carbon Products from Coal

    SciTech Connect (OSTI)

    Frank Rusinko; John Andresen; Jennifer E. Hill; Harold H. Schobert; Bruce G. Miller

    2006-01-01T23:59:59.000Z

    The objective of these projects was to investigate alternative technologies for non-fuel uses of coal. Special emphasis was placed on developing premium carbon products from coal-derived feedstocks. A total of 14 projects, which are the 2003 Research Projects, are reported herein. These projects were categorized into three overall objectives. They are: (1) To explore new applications for the use of anthracite in order to improve its marketability; (2) To effectively minimize environmental damage caused by mercury emissions, CO{sub 2} emissions, and coal impounds; and (3) To continue to increase our understanding of coal properties and establish coal usage in non-fuel industries. Research was completed in laboratories throughout the United States. Most research was performed on a bench-scale level with the intent of scaling up if preliminary tests proved successful. These projects resulted in many potential applications for coal-derived feedstocks. These include: (1) Use of anthracite as a sorbent to capture CO{sub 2} emissions; (2) Use of anthracite-based carbon as a catalyst; (3) Use of processed anthracite in carbon electrodes and carbon black; (4) Use of raw coal refuse for producing activated carbon; (5) Reusable PACs to recycle captured mercury; (6) Use of combustion and gasification chars to capture mercury from coal-fired power plants; (7) Development of a synthetic coal tar enamel; (8) Use of alternative binder pitches in aluminum anodes; (9) Use of Solvent Extracted Carbon Ore (SECO) to fuel a carbon fuel cell; (10) Production of a low cost coal-derived turbostratic carbon powder for structural applications; (11) Production of high-value carbon fibers and foams via the co-processing of a low-cost coal extract pitch with well-dispersed carbon nanotubes; (12) Use of carbon from fly ash as metallurgical carbon; (13) Production of bulk carbon fiber for concrete reinforcement; and (14) Characterizing coal solvent extraction processes. Although some of the projects funded did not meet their original goals, the overall objectives of the CPCPC were completed as many new applications for coal-derived feedstocks have been researched. Future research in many of these areas is necessary before implementation into industry.

  14. Coal metamorphism in the upper portion of the Pennsylvanian Sturgis Formation in Western Kentucky

    SciTech Connect (OSTI)

    Hower, J.C.

    1983-12-01T23:59:59.000Z

    Coals from the Pennsylvanian upper Sturgis Formation (Mississippian and Virginian) were sampled from a borehole in Union County, western Kentucky. The coals exhibited two discrete levels of metamorphism. The lower rank coals of high-volatile C bituminous rank were assumed to represent the normal level of metamorphism. A second set of coals of high-volatile A bituminous rank was found to be associated with sphalerite, chlorite, and twinned calcite. The latter mineral assemblages indicate that hydrothermal metamorphism was responsible for the anomalous high rank. Consideration of the sphalerite fluid-inclusion temperatures from nearby ores and coals and the time - temperature aspects of the coal metamorphism suggests that the hydrothermal metamorphic event was in the 150 to 200 C range for a brief time (10/sup 5/-10/sup 5/and yr), as opposed to the longer term (25-50m yr) 60 to 75 C ambient metamorphism.

  15. Petrography of the Herrin (No. 11) coal in western Kentucky

    SciTech Connect (OSTI)

    Hower, J.C.; Wild, G.D.

    1981-06-01T23:59:59.000Z

    The Herrin (No.11) coal in western Kentucky is in the upper part of the Pennsylvanian (Des Moinesian) Carbondale Formation. Samples were obtained from 13 mines in Kentucky and one mine in Illinois in three equal benches from two to three channels for a total of 93 samples. The rank of the coal (as vitrinite reflectance) is high volatile C bituminous in the Moorman Syncline and high volatile A bituminous in the Webster Syncline. Reflectance does not vary between mines in the Moorman Syncline. The percentage of total vitrinite macerals for each mine is over 85% and the percentage of total vitrinite plus liptinite macerals is over 89% (average over 90%) (both on dry, mineral-free basis). 37 refs.

  16. Coal Production 1992

    SciTech Connect (OSTI)

    Not Available

    1993-10-29T23:59:59.000Z

    Coal Production 1992 provides comprehensive information about US coal production, the number of mines, prices, productivity, employment, productive capacity, and recoverable reserves to a wide audience including Congress, Federal and State agencies, the coal industry, and the general public. In 1992, there were 3,439 active coal mining operations made up of all mines, preparation plants, and refuse operations. The data in Table 1 cover the 2,746 mines that produced coal, regardless of the amount of production, except for bituminous refuse mines. Tables 2 through 33 include data from the 2,852 mining operations that produced, processed, or prepared 10 thousand or more short tons of coal during the period, except for bituminous refuse, and includes preparation plants with 5 thousand or more employee hours. These mining operations accounted for over 99 percent of total US coal production and represented 83 percent of all US coal mining operations in 1992.

  17. Pelletizing lignite

    DOE Patents [OSTI]

    Goksel, Mehmet A. (Houghton, MI)

    1983-11-01T23:59:59.000Z

    Lignite is formed into high strength pellets having a calorific value of at least 9,500 Btu/lb by blending a sufficient amount of an aqueous base bituminous emulsion with finely-divided raw lignite containing its inherent moisture to form a moistened green mixture containing at least 3 weight % of the bituminous material, based on the total dry weight of the solids, pelletizing the green mixture into discrete green pellets of a predetermined average diameter and drying the green pellets to a predetermined moisture content, preferrably no less than about 5 weight %. Lignite char and mixture of raw lignite and lignite char can be formed into high strength pellets in the same general manner.

  18. Scale-Up and Demonstration of Fly Ash Ozonation Technology

    SciTech Connect (OSTI)

    Rui Afonso; R. Hurt; I. Kulaots

    2006-03-01T23:59:59.000Z

    The disposal of fly ash from the combustion of coal has become increasingly important. When the fly ash does not meet the required specification for the product or market intended, it is necessary to beneficiate it to achieve the desired quality. This project, conducted at PPL's Montour SES, is the first near full-scale ({approx}10 ton/day), demonstration of ash ozonation technology. Bituminous and sub bituminous ashes, including two ash samples that contained activated carbon, were treated during the project. Results from the tests were very promising. The ashes were successfully treated with ozone, yielding concrete-suitable ash quality. Preliminary process cost estimates indicate that capital and operating costs to treat unburned carbon are competitive with other commercial ash beneficiation technologies at a fraction of the cost of lost sales and/or ash disposal costs. This is the final technical report under DOE Cooperative Agreement No.: DE-FC26-03NT41730.

  19. EA-1616: National Carbon Research Center Project at Southern Company Services' Power Systems Development Facility near Wilsonville, Alabama

    Broader source: Energy.gov [DOE]

    This EA evaluates and updates the potential environmental impacts of DOE’s proposed continued operations of the NCCC Project at the PSDF plant. The NCCC is designed to test and evaluate carbon dioxide (CO2) control technologies for power generation facilities, including CO2 capture solvents and sorbents, mass-transfer devices, lower cost water-gas shift reactors, and scaled-up membrane technologies. Additionally, the NCCC evaluates methods to integrate CO2 capture technologies with other coal-based power plant systems by testing both pre-combustion and post-combustion technologies. The NCCC provides the capability to test these systems under a wide range of fuels, including bituminous and sub-bituminous coals, lignites and biomass/coal mixtures. The goal of the NCCC project is to accelerate the development, optimization, and commercialization of viable CO2 control technologies.

  20. In-situ coal gasification: a new technology

    SciTech Connect (OSTI)

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

    1982-01-01T23:59:59.000Z

    While the technology for underground gasification of Western US subbituminous coals is advancing through efforts at the Hanna and Hoe Creek test sites, the development of an Eastern bituminous coal technology has only begun. The Pricetown 1 field test proved the feasibility of gasifying the thin-seam, swelling bituminous coal resources. Key issues remaining to be demonstrated include an effective linkage method, means of controlling gas production and composition, and scale-up. A major field-test program could entail three phases: (1) resolving the linkage and process control problems in the Appalachian basin, (2) assessing the technology in the untested Illinois basin, and (3) testing a multimodule commercial-scale prototype.

  1. Association of coal metamorphism and hydrothermal mineralization in Rough Creek fault zone and Fluorspar District, Western Kentucky

    SciTech Connect (OSTI)

    Hower, J.C.; Fiene, F.L.; Trinkle, E.J.

    1983-09-01T23:59:59.000Z

    The ambient coal rank (metamorphism) of the Carboniferous coals in the Western Kentucky coalfield ranges from high volatile A bituminous (vitrinite maximum reflectance up to 0.75% R/sub max/) in the Webster syncline (Webster and southern Union Counties) to high volatile C bituminous (0.45 to 0.60% R/sub max/) over most of the remainder of the area. Anomalous patterns of metamorphism, however, have been noted in coals recovered from cores and mines in fault blocks of the Rough Creek fault zone and Fluorspar District. Coals in Gil-30 borehole (Rough Creek faults, Bordley Quadrangle, Union County) vary with no regard for vertical position, from high volatile C(0.55% R/sub max/) to high volatile A (0.89%R/sub max) bituminous. Examination of the upper Sturgis Formation (Missourian/Virgilian) coals revealed that the higher rank (generally above 0.75% R/sub max/) coals had vein mineral assemblages of sphalerite, twinned calcite, and ferroan dolomite. Lower rank coals had only untwinned calcite. Several sites in Webster County contain various coals (Well (No. 8) to Coiltwon (No. 14)) with vitrinite reflectances up to 0.83% R/sub max/ and associated sphalerite mineralization. Mississippian and Lower Pennsylvanian (Caseyville Formation Gentry coal) coals in the mineralized Fluorspar District have ranks to nearly medium volatile bituminous (1.03% R/sub max/). The regional rank trend exhibited by the fualt zones is generally higher rank than the surrounding areas. Sphalerite mineralization in itself is not unique within Illinois basin coals, but if it was partly responsible for the metamorphism of these coals, then the fluid temperature must have been higher within the above mentioned fault complexes.

  2. Survey of air-cure experience on dust control system design for PRB coal

    SciTech Connect (OSTI)

    Harris, M.R.

    1998-07-01T23:59:59.000Z

    This paper describes major changes required in features for coal dust control systems when existing coal fired power plants switch to PRB (Powder River Basin) coal. It encompasses all transfer points within the coal handling system from receiving to the plant bunkers or silos. It provides a comparison of bituminous and PRB coal from a dust collection aspect, the major features required for reliability and safety and the reasons for implementation.

  3. Sustainable development with clean coal

    SciTech Connect (OSTI)

    NONE

    1997-08-01T23:59:59.000Z

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

  4. Optimum usage and economic feasibility of animal manure-based biomass in combustion systems

    E-Print Network [OSTI]

    Carlin, Nicholas T.

    2010-07-14T23:59:59.000Z

    value of cattle biomass vs. moisture and ash percentage (assuming a dry, ash free HHV of 19,770 kJ/kg)........................................32 Figure 2.5 Nitrogen, sulfur, and chlorine contents of DB, FB, Texas lignite, and Wyoming sub... 6.27 Ash emission vs. co-fire rate when replacing Wyoming sub-bituminous coal with low-ash dairy biomass ...............................................................269 Figure 6.28 Ash emission vs. co-fire rate when replacing Texas lignite...

  5. The H-Coal pilot plant and the Breckinridge Project

    SciTech Connect (OSTI)

    Wigglesworth, T.H.

    1982-05-01T23:59:59.000Z

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

  6. The effect of construction variables on the dynamic modulus of asphalt treated base courses 

    E-Print Network [OSTI]

    Moeller, William Ernest

    1970-01-01T23:59:59.000Z

    were taken the confining pressure was raised to 20 psi and the procedure repeated. The same sequence was repeated for a confining prossnre of 40 psi. 37 Unconfined Comcression Test The unconfined compression test has long been used in the testing... the recorder load versus time plot. No other instrumentation was utilized in this test. The Texas High?ay Department procedure for unconfined compression testing of bituminous mixtures specifies a specimen temperature of 140 F and a rate of loading...

  7. College Of Wooster 2012 Greenhouse Gas Emissions From Coal and Natural Gas Combustion Default Values From EPA Greenhouse Gas Rule

    E-Print Network [OSTI]

    Wilson, Mark A.

    56410 CO2 = 1 X 10 -3 X Fuel X HHV X EF Where CO2 = Annual CO2 mass emissions for the specific fuel type high heat value. EF =Fuel default CO2 Emission Factor from Table C-1Page 56410 CO2 Coal CO2 = 1 X 10 -3 Default CO2 Emission Factor For Bituminous Coal = 93.40 kg/mmbtu Default CH4 Emission Factor

  8. (c) 2008-2011. Minh Ha-Duong. Rodica Loisel. CIRED Reproduction allowed. share alike. attribution. Blue cells: Numerical assumptions defining the scenario

    E-Print Network [OSTI]

    ,00 Gt CO2 generated G = g B 4,50 Gt CO2 stored S = s B Carbon dioxide emissions and coal types 2,38 t CO2 generated by t of coal (bituminous grade) Coal Types CO2 emissions 2050 2,101 Gt of coal consumed « Expected fatalities for one wedge of CCS in 2050 » Defines the « wedge of CCS at baseload coal power plants

  9. Study of catalytic diffusion in coal. Final report for 1983/1984 SOMED Project. [Determination of pore (hole) size and pore shape distribution

    SciTech Connect (OSTI)

    Kispert, L.D.

    1984-09-01T23:59:59.000Z

    The purpose of our studies is to determine the pore (hole) size and pore shape distribution in standard bituminous coal samples from various Alabama coal seams such as that of the Mary Lee, Black Creek and Pratt during and after swelling of the coal with different solvents at various temperatures. These samples come from the Penn State Coal Sample Bank at Pennsylvania State University Coal Research Section and from Alabama's Mineral Industries. Methods have been developed in the laboratory whereby free radical probes of varying sizes can be diffused into the coal under various conditions. These probes can be detected and the environment surrounding the probes can be deduced by electron paramagnetic resonance (EPR) methods. To date, we have found that not only can the shape and size of the pores be determined, but that the size distribution varies from one bituminous coal seam to another, even for coal of the same rank, suggesting a different optimal catalyst should be used for each seam. The effect of oxygen on the coal samples during grinding has been studied; however, the free radical technique appears to be insensitive to the presence of oxygen effects. It is our goal to determine the structural differences between various bituminous coals. 9 references, 9 figures, 1 table.

  10. Study of catalytic diffusion in coal. Final report, 1983-1984

    SciTech Connect (OSTI)

    Kispert, L.D.

    1984-09-01T23:59:59.000Z

    The purpose of these studies is to determine the pore (hole) size and pore shape distribution in standard bituminous coal samples from various Alabama coal seams such as that of the Mary Lee, Black Creek and Pratt during and after swelling of the coal with different solvents at various temperatures. These samples come from the Penn State Coal Sample Bank at Pennsylvania State University Coal Research Section and from Alabama's Mineral Industries. Methods were developed in the laboratory whereby free-radical probes of varying sizes can be diffused into the coal under various conditions. These probes can be detected and the environment surrounding the probes can be deduced by electron paramagnetic resonance (EPR) methods. To date, it has been found that not only can the shape and size of the pores be determined, but that the size distribution varies from one bituminous coal seam to another, even for coal of the same rank, suggesting a different optimal catalyst should be used for each seam. The effect of oxygen on the coal samples during grinding has been studied; however, the free radical technique appears to be insensitive to the presence of oxygen effects. The goal is to determine the structural differences between various bituminous coals.

  11. Mineral matter transformations in a pressurized drop-tube furnace

    SciTech Connect (OSTI)

    Swanson, M.L.; Tibbetts, J.E.

    1992-12-31T23:59:59.000Z

    To meet the objectives of the program, a pressurized combustion vessel was built to allow the operating parameters of a direct-fired gas turbine combustor to be simulated. One goal in building this equipment was to design the gas turbine simulator as small as possible to reduce the quantity of test fuel needed, while not undersizing the combustor such that wall effects had a significant effect on the measured combustion performance. Based on computer modeling, a rich-lean, two-stage, nonslagging combustor was constructed to simulate a direct-fired gas turbine. This design was selected to maximize the information that could be obtained on the impact of low-rank coal`s unique properties on the gas turbine combustor, its turbomachinery, and the required hot-gas cleanup devices (such as high-temperature/high-pressure (HTHP) cyclones). Seventeen successful combustion tests using coal-water fuels were completed. These tests included seven tests with a commercially available Otisca Industries-produced, Taggart seam bituminous fuel and five tests each with physically and chemically cleaned Beulah-Zap lignite and a chemically cleaned Kemmerer subbituminous fuel. LRC-fueled heat engine testing conducted at the Energy and Environmental Research Center (EERC) has indicated that LRC fuels perform very well in short residence time heat engine combustion systems. Analyses of the emission and fly ash samples highlighted the superior burnout experienced by the LRC fuels as compared to the bituminous fuel even under a longer residence time profile for the bituminous fuel.

  12. Mineral matter transformations in a pressurized drop-tube furnace

    SciTech Connect (OSTI)

    Swanson, M.L.; Tibbetts, J.E.

    1992-01-01T23:59:59.000Z

    To meet the objectives of the program, a pressurized combustion vessel was built to allow the operating parameters of a direct-fired gas turbine combustor to be simulated. One goal in building this equipment was to design the gas turbine simulator as small as possible to reduce the quantity of test fuel needed, while not undersizing the combustor such that wall effects had a significant effect on the measured combustion performance. Based on computer modeling, a rich-lean, two-stage, nonslagging combustor was constructed to simulate a direct-fired gas turbine. This design was selected to maximize the information that could be obtained on the impact of low-rank coal's unique properties on the gas turbine combustor, its turbomachinery, and the required hot-gas cleanup devices (such as high-temperature/high-pressure (HTHP) cyclones). Seventeen successful combustion tests using coal-water fuels were completed. These tests included seven tests with a commercially available Otisca Industries-produced, Taggart seam bituminous fuel and five tests each with physically and chemically cleaned Beulah-Zap lignite and a chemically cleaned Kemmerer subbituminous fuel. LRC-fueled heat engine testing conducted at the Energy and Environmental Research Center (EERC) has indicated that LRC fuels perform very well in short residence time heat engine combustion systems. Analyses of the emission and fly ash samples highlighted the superior burnout experienced by the LRC fuels as compared to the bituminous fuel even under a longer residence time profile for the bituminous fuel.

  13. USE OF MOLECULAR MODELING TO DETERMINE THE INTERACTION AND COMPETITION OF GASES WITHIN COAL FOR CARBON DIOXIDE SEQUESTRATION

    SciTech Connect (OSTI)

    Jeffrey D. Evanseck; Jeffry D. Madura; Jonathan P. Mathews

    2005-05-27T23:59:59.000Z

    We have made progress in carrying out large scale molecular dynamics simulations using the CHARMM force field in order to refine our coal/guest interactions. There have been two issues facing us over the last year. First, we have had to create a completely new topology and parameter definition for coal. Since we are using a classical force field, we have adopted the strategy of treating coal composed of individual common fragments based upon a distribution of mass, composition, and bonding. Our procedure is similar to treating a protein as being composed of the discrete set of amino acids. Second, we have had to incorporate the quality CO{sub 2} parameters that we have developed over the last two years. There are the geometric and arithmetic procedures, which we have successfully implemented. We have utilized computational molecular modeling to generate a state-of-the-art large scale structural representation of a bituminous coal of low volatile bituminous rank. This structure(s) has been used to investigate the molecular forces between the bituminous coal structure (or idealized pores) and the molecular species CH{sub 4} and CO{sub 2}. We are close to carrying out molecular dynamics simulations, which will allow us to explore and test the newly created model of coal.

  14. Formation and retention of methane in coal. Final report

    SciTech Connect (OSTI)

    Hucka, V.J.; Bodily, D.M.; Huang, H.

    1992-05-15T23:59:59.000Z

    The formation and retention of methane in coalbeds was studied for ten Utah coal samples, one Colorado coal sample and eight coal samples from the Argonne Premium Coal Sample Bank.Methane gas content of the Utah and Colorado coals varied from zero to 9 cm{sup 3}/g. The Utah coals were all high volatile bituminous coals. The Colorado coal was a gassy medium volatile bituminous coal. The Argonne coals cover a range or rank from lignite to low volatile bituminous coal and were used to determine the effect of rank in laboratory studies. The methane content of six selected Utah coal seams and the Colorado coal seam was measured in situ using a special sample collection device and a bubble desorbometer. Coal samples were collected at each measurement site for laboratory analysis. The cleat and joint system was evaluated for the coal and surrounding rocks and geological conditions were noted. Permeability measurements were performed on selected samples and all samples were analyzed for proximate and ultimate analysis, petrographic analysis, {sup 13}C NMR dipolar-dephasing spectroscopy, and density analysis. The observed methane adsorption behavior was correlated with the chemical structure and physical properties of the coals.

  15. Formation and retention of methane in coal

    SciTech Connect (OSTI)

    Hucka, V.J.; Bodily, D.M.; Huang, H.

    1992-05-15T23:59:59.000Z

    The formation and retention of methane in coalbeds was studied for ten Utah coal samples, one Colorado coal sample and eight coal samples from the Argonne Premium Coal Sample Bank.Methane gas content of the Utah and Colorado coals varied from zero to 9 cm{sup 3}/g. The Utah coals were all high volatile bituminous coals. The Colorado coal was a gassy medium volatile bituminous coal. The Argonne coals cover a range or rank from lignite to low volatile bituminous coal and were used to determine the effect of rank in laboratory studies. The methane content of six selected Utah coal seams and the Colorado coal seam was measured in situ using a special sample collection device and a bubble desorbometer. Coal samples were collected at each measurement site for laboratory analysis. The cleat and joint system was evaluated for the coal and surrounding rocks and geological conditions were noted. Permeability measurements were performed on selected samples and all samples were analyzed for proximate and ultimate analysis, petrographic analysis, {sup 13}C NMR dipolar-dephasing spectroscopy, and density analysis. The observed methane adsorption behavior was correlated with the chemical structure and physical properties of the coals.

  16. Measurement of Sorption-Induced Strain

    SciTech Connect (OSTI)

    Eric P. Robertson; Richard L. Christiansen

    2005-05-01T23:59:59.000Z

    Strain caused by the adsorption of gases was measured in samples of subbituminous coal from the Powder River basin of Wyoming, U.S.A. and high-volatile bituminous coal from east-central Utah, U.S.A. using an apparatus developed jointly at the Idaho National Laboratory (Idaho Falls, Idaho, U.S.A.) and Colorado School of Mines (Golden, Colorado, U.S.A.). The apparatus can be used to measure strain on multiple small coal samples based on the optical detection of the longitudinal strain instead of the more common usage of strain gauges, which require larger samples and longer equilibration times. With this apparatus, we showed that the swelling and shrinkage processes were reversible and that accurate strain data could be obtained in a shortened amount of time. A suite of strain curves was generated for these coals using gases that included carbon dioxide, nitrogen, methane, helium, and various mixtures of these gases. A Langmuir-type equation was applied to satisfactorily model the strain data obtained for pure gases. The sorption-induced strain measured in the subbituminous coal was larger than the high-volatile bituminous coal for all gases tested over the range of pressures used in the experimentation, with the CO2-induced strain for the subbituminous coal over twice as great at the bituminous coal.

  17. Field Testing of a Wet FGD Additive for Enhanced Mercury Control - Task 3 Full-scale Test Results

    SciTech Connect (OSTI)

    Gary Blythe

    2007-05-01T23:59:59.000Z

    This Topical Report summarizes progress on Cooperative Agreement DE-FC26-04NT42309, 'Field Testing of a Wet FGD Additive'. The objective of the project is to demonstrate the use of a flue gas desulfurization (FGD) additive, Degussa Corporation's TMT-15, to prevent the reemission of elemental mercury (Hg{sup 0}) in flue gas exiting wet FGD systems on coal-fired boilers. Furthermore, the project intends to demonstrate whether the additive can be used to precipitate most of the mercury (Hg) removed in the wet FGD system as a fine TMT salt that can be separated from the FGD liquor and bulk solid byproducts for separate disposal. The project is conducting pilot- and full-scale tests of the TMT-15 additive in wet FGD absorbers. The tests are intended to determine required additive dosages to prevent Hg{sup 0} reemissions and to separate mercury from the normal FGD byproducts for three coal types: Texas lignite/Power River Basin (PRB) coal blend, high-sulfur Eastern bituminous coal, and low-sulfur Eastern bituminous coal. The project team consists of URS Group, Inc., EPRI, TXU Generation Company LP, Southern Company, and Degussa Corporation. TXU Generation has provided the Texas lignite/PRB cofired test site for pilot FGD tests, Monticello Steam Electric Station Unit 3. Southern Company is providing the low-sulfur Eastern bituminous coal host site for wet scrubbing tests, as well as the pilot- and full-scale jet bubbling reactor (JBR) FGD systems to be tested. IPL, an AES company, provided the high-sulfur Eastern bituminous coal full-scale FGD test site and cost sharing. Degussa Corporation is providing the TMT-15 additive and technical support to the test program as cost sharing. The project is being conducted in six tasks. Of the six project tasks, Task 1 involves project planning and Task 6 involves management and reporting. The other four tasks involve field testing on FGD systems, either at pilot or full scale. The four tasks include: Task 2 - Pilot Additive Testing in Texas Lignite Flue Gas; Task 3 - Full-scale FGD Additive Testing in High-sulfur Eastern Bituminous Flue Gas; Task 4 - Pilot Wet Scrubber Additive Tests at Plant Yates; and Task 5 - Full-scale Additive Tests at Plant Yates. The pilot-scale tests were completed in 2005 and have been previously reported. This topical report presents the results from the Task 3 full-scale additive tests, conducted at IPL's Petersburg Station Unit 2. The Task 5 full-scale additive tests will be conducted later in calendar year 2007.

  18. Field Testing of a Wet FGD Additive for Enhanced Mercury Control - Pilot-Scale Test Results

    SciTech Connect (OSTI)

    Gary M. Blythe

    2006-03-01T23:59:59.000Z

    This Topical Report summarizes progress on Cooperative Agreement DE-FC26-04NT42309, ''Field Testing of a Wet FGD Additive.'' The objective of the project is to demonstrate the use of a flue gas desulfurization (FGD) additive, Degussa Corporation's TMT-15, to prevent the reemissions of elemental mercury (Hg{sup 0}) in flue gas exiting wet FGD systems on coal-fired boilers. Furthermore, the project intends to demonstrate that the additive can be used to precipitate most of the mercury (Hg) removed in the wet FGD system as a fine TMT salt that can be separated from the FGD liquor and bulk solid byproducts for separate disposal. The project will conduct pilot and full-scale tests of the TMT-15 additive in wet FGD absorbers. The tests are intended to determine required additive dosage requirements to prevent Hg{sup 0} reemissions and to separate mercury from the normal FGD byproducts for three coal types: Texas lignite/Power River Basin (PRB) coal blend, high-sulfur Eastern bituminous coal, and low-sulfur Eastern bituminous coal. The project team consists of URS Group, Inc., EPRI, TXU Generation Company LP, Southern Company, and Degussa Corporation. TXU Generation has provided the Texas lignite/PRB co-fired test site for pilot FGD tests, Monticello Steam Electric Station Unit 3. Southern Company is providing the low-sulfur Eastern bituminous coal host site for wet scrubbing tests, as well as the pilot and full-scale jet bubbling reactor (JBR) FGD systems to be tested. A third utility, to be named later, will provide the high-sulfur Eastern bituminous coal full-scale FGD test site. Degussa Corporation is providing the TMT-15 additive and technical support to the test program. The project is being conducted in six tasks. Of the six project tasks, Task 1 involves project planning and Task 6 involves management and reporting. The other four tasks involve field testing on FGD systems, either at pilot or full scale. The four tasks include: Task 2 - Pilot Additive Testing in Texas Lignite Flue Gas; Task 3 - Full-scale FGD Additive Testing in High Sulfur Eastern Bituminous Flue Gas; Task 4 - Pilot Wet Scrubber Additive Tests at Yates; and Task 5 - Full-scale Additive Tests at Plant Yates. This topical report presents the results from the Task 2 and Task 4 pilot-scale additive tests. The Task 3 and Task 5 full-scale additive tests will be conducted later in calendar year 2006.

  19. Process for solvent refining of coal using a denitrogenated and dephenolated solvent

    DOE Patents [OSTI]

    Garg, Diwakar (Macungie, PA); Givens, Edwin N. (Bethlehem, PA); Schweighardt, Frank K. (Allentown, PA)

    1984-01-01T23:59:59.000Z

    A process is disclosed for the solvent refining of non-anthracitic coal at elevated temperatures and pressure in a hydrogen atmosphere using a hydrocarbon solvent which before being recycled in the solvent refining process is subjected to chemical treatment to extract substantially all nitrogenous and phenolic constituents from the solvent so as to improve the conversion of coal and the production of oil in the solvent refining process. The solvent refining process can be either thermal or catalytic. The extraction of nitrogenous compounds can be performed by acid contact such as hydrogen chloride or fluoride treatment, while phenolic extraction can be performed by caustic contact or contact with a mixture of silica and alumina.

  20. A study of the volatile matter of coal as a function of the heating rate

    SciTech Connect (OSTI)

    Yanes, E.; Wilhite, D.; Riley, J.M. Jr. [Western Kentucky Univ., Bowling Green, KY (United States)] [and others

    1996-12-31T23:59:59.000Z

    A study of the volatile matter yields as a function of the heating rate was conducted. A suite of 21 coal and coke samples varying in rank from anthracitic to lignitic and heating rates from 10{degrees}C/min to about 450{degrees}C/min were used in the study. Heating rates up to 60{degrees}C per minute, which are typically used in ASTM Test Method 5142 (instrumental Proximate Analysis), were achieved in a macro thermogravimetric analysis (TGA) system. Heating rates of 50-200{degrees}C/min were obtained in a micro TGA system. All measurements were made in a nitrogen atmosphere. The results of the study illustrate the dependence of the volatile matter yield on the heating rate. For most coals and cokes the optimum heating rate for determining volatile matter values that agree with those obtained by ASTM Method D 3175 appears to be in the 100-150{degrees}C range.

  1. Applications and experiences with super duplex stainless steel in wet FGD scrubber systems

    SciTech Connect (OSTI)

    Francis, R.; Byrne, G.; Warburton, G.; Hebdon, S. [Weir Materials Ltd., Manchester (United Kingdom)

    1998-12-31T23:59:59.000Z

    The paper presents the properties of the author`s company`s proprietary super duplex stainless steel. Work is presented showing the development of a more realistic laboratory solution representing typical limestone slurries found in real flue gas desulfurization (FGD) systems. The importance of additions of metal ions such as Fe{sup 3+} and Mn{sup 2+} as well as partially oxidized sulfur species is demonstrated. Results are presented comparing the crevice corrosion resistance of super duplex stainless steel in these slurries with other commonly used wrought and cast stainless steels, for both simulated anthracite and lignite type slurries. Data from loop tests on the erosion resistance of a range of alloys in simulated FGD slurries is presented. The results clearly show the superior resistance of super duplex stainless steel to both crevice corrosion and erosion in FGD slurries. Finally the experiences in UK FGD systems with both cast and wrought super duplex stainless steel are presented.

  2. The relationship between the thermoplastic behavior of blends and their component coals

    SciTech Connect (OSTI)

    Sakurovs, R.

    1999-07-01T23:59:59.000Z

    The thermoplastic behaviors of a number of coking coal blends were measured using proton magnetic resonance thermal analysis (PMRTA) to determine to what extent they were affected by interactions between the component coals. Most blends showed evidence that at temperatures near their temperatures of maximum fluidity the extent to which they fused was different to that expected if the coals did not interact. Only blends of coking coals of different rank fused to a greater extent than expected in the absence of interactions. Semi-anthracite, low rank coals and charcoal reduced the extent of fusion of coking coals to values below those expected if they were acting as inert diluents. These interactions are interpreted as being mediated by transfer of volatile material between the coals on heating.

  3. Development of biological coal gasification (MicGAS process). Final report, May 1, 1990--May 31, 1995

    SciTech Connect (OSTI)

    NONE

    1998-12-31T23:59:59.000Z

    ARCTECH has developed a novel process (MicGAS) for direct, anaerobic biomethanation of coals. Biomethanation potential of coals of different ranks (Anthracite, bitumious, sub-bitumious, and lignites of different types), by various microbial consortia, was investigated. Studies on biogasification of Texas Lignite (TxL) were conducted with a proprietary microbial consortium, Mic-1, isolated from hind guts of soil eating termites (Zootermopsis and Nasutitermes sp.) and further improved at ARCTECH. Various microbial populations of the Mic-1 consortium carry out the multi-step MicGAS Process. First, the primary coal degraders, or hydrolytic microbes, degrade the coal to high molecular weight (MW) compounds. Then acedogens ferment the high MW compounds to low MW volatile fatty acids. The volatile fatty acids are converted to acetate by acetogens, and the methanogens complete the biomethanation by converting acetate and CO{sub 2} to methane.

  4. Risk Assessment and Monitoring of Stored CO2 in Organic Rocks Under Non-Equilibrium Conditions

    SciTech Connect (OSTI)

    Malhotra, Vivak

    2014-06-30T23:59:59.000Z

    The USA is embarking upon tackling the serious environmental challenges posed to the world by greenhouse gases, especially carbon dioxide (CO2). The dimension of the problem is daunting. In fact, according to the Energy Information Agency, nearly 6 billion metric tons of CO2 were produced in the USA in 2007 with coal-burning power plants contributing about 2 billion metric tons. To mitigate the concerns associated with CO2 emission, geological sequestration holds promise. Among the potential geological storage sites, unmineable coal seams and shale formations in particular show promise because of the probability of methane recovery while sequestering the CO2. However. the success of large-scale sequestration of CO2 in coal and shale would hinge on a thorough understanding of CO2's interactions with host reservoirs. An important parameter for successful storage of CO2 reservoirs would be whether the pressurized CO2 would remain invariant in coal and shale formations under reasonable internal and/or external perturbations. Recent research has brought to the fore the potential of induced seismicity, which may result in caprock compromise. Therefore, to evaluate the potential risks involved in sequestering CO2 in Illinois bituminous coal seams and shale, we studied: (i) the mechanical behavior of Murphysboro (Illinois) and Houchin Creek (Illinois) coals, (ii) thermodynamic behavior of Illinois bituminous coal at - 100oC ? T ? 300oC, (iii) how high pressure CO2 (up to 20.7 MPa) modifies the viscosity of the host, (iv) the rate of emission of CO2 from Illinois bituminous coal and shale cores if the cores, which were pressurized with high pressure (? 20.7 MPa) CO2, were exposed to an atmospheric pressure, simulating the development of leakage pathways, (v) whether there are any fractions of CO2 stored in these hosts which are resistance to emission by simply exposing the cores to atmospheric pressure, and (vi) how compressive shockwaves applied to the coal and shale cores, which were pressurized with high pressure CO2, determine the fate of sequestered CO2 in these cores. Our results suggested that Illinois bituminous coal in its unperturbed state, i.e., when not pressurized with CO2, showed large variations in the mechanical properties. Modulus varied from 0.7 GPa to 3.4 GPa even though samples were extracted from a single large chunk of coal. We did not observe any glass transition for Illinois bituminous coal at - 100oC ? T ? 300oC, however, when the coal was pressurized with CO2 at ambient ? P ? 20.7 MPa, the viscosity of the coal decreased and inversely scaled with the CO2 pressure. The decrease in viscosity as a function of pressure could pose CO2 injection problems for coal as lower viscosity would allow the solid coal to flow to plug the fractures, fissures, and cleats. Our experiments also showed a very small fraction of CO2 was absorbed in coal; and when CO2 pressurized coals were exposed to atmospheric conditions, the loss of CO2 from coals was massive. Half of the sequestered gas from the coal cores was lost in less than 20 minutes. Our shockwave experiments on Illinois bituminous coal, New Albany shale (Illinois), Devonian shale (Ohio), and Utica shale (Ohio) presented clear evidence that the significant emission of the sequestered CO2 from these formations cannot be discounted during seismic activity, especially if caprock is compromised. It is argued that additional shockwave studies, both compressive and transverse, would be required for successfully mapping the risks associated with sequestering high pressure CO2 in coal and shale formations.

  5. Coal Reburning for Cyclone Boiler NO{sub x} Control Demonstration. Quarterly report No. 12, January--March 1993

    SciTech Connect (OSTI)

    Not Available

    1993-07-01T23:59:59.000Z

    The project involves retrofitting/testing the reburning technology at Wisconsin Power & Light`s 100 MWe Nelson Dewey Unit {number_sign}2 in Cassville, Wisconsin to determine the commercial applicability of this technology to reduce NO{sub x} emission levels. Based upon the data collected and evaluated f or reburn No{sub x} reduction performance with the Lamar Indiana bituminous coal f or boiler loads of 110 MW, 82 MW, and 60 MW, average NO{sub x} reductions of 52.4%, 50.1% and 35.8%, respectively were achieved. Average emissions of NO{sub x}with reburn in operation were 290 ppm (.39 lb/million Btu) , 265 ppm (.36 lb/million Btu) and 325 ppm (.44 lb/million Btu) respectively, all corrected to 3% 02 content. Boiler efficiency losses due to increased unburned carbon in the ash were 0.1% at 110 NW, .25% at 83 MW and 1.5% at 60 MW. Reburn performance results with western sub-bituminous coal at 110 MW, 82 MW and 60 MW boiler loads indicated NO{sub x} reductions of 55.4%, 52.1% and 52.6% respectively. Under optimal conditions, NO{sub x} reductions approaching 63% were achieved with the more reactive western sub-bituminous coal. Boiler efficiency losses due to increased unburned carbon in the ash were unchanged at full load, a loss of 0.2% at 83 MW and a loss of .3% at low load, much improved over results with the Lamar coal.

  6. Coal Reburning for Cyclone Boiler NO[sub x] Control Demonstration

    SciTech Connect (OSTI)

    Not Available

    1993-01-01T23:59:59.000Z

    The project involves retrofitting/testing the reburning technology at Wisconsin Power Light's 100 MWe Nelson Dewey Unit [number sign]2 in Cassville, Wisconsin to determine the commercial applicability of this technology to reduce NO[sub x] emission levels. Based upon the data collected and evaluated f or reburn No[sub x] reduction performance with the Lamar Indiana bituminous coal f or boiler loads of 110 MW, 82 MW, and 60 MW, average NO[sub x] reductions of 52.4%, 50.1% and 35.8%, respectively were achieved. Average emissions of NO[sub x]with reburn in operation were 290 ppm (.39 lb/million Btu) , 265 ppm (.36 lb/million Btu) and 325 ppm (.44 lb/million Btu) respectively, all corrected to 3% 02 content. Boiler efficiency losses due to increased unburned carbon in the ash were 0.1% at 110 NW, .25% at 83 MW and 1.5% at 60 MW. Reburn performance results with western sub-bituminous coal at 110 MW, 82 MW and 60 MW boiler loads indicated NO[sub x] reductions of 55.4%, 52.1% and 52.6% respectively. Under optimal conditions, NO[sub x] reductions approaching 63% were achieved with the more reactive western sub-bituminous coal. Boiler efficiency losses due to increased unburned carbon in the ash were unchanged at full load, a loss of 0.2% at 83 MW and a loss of .3% at low load, much improved over results with the Lamar coal.

  7. Coal combustion under conditions of blast furnace injection

    SciTech Connect (OSTI)

    Crelling, J.C. [Southern Illinois Univ., Carbondale, IL (United States). Dept. of Geology

    1995-12-01T23:59:59.000Z

    Because of its increasing cost and decreasing availability, metallurgical coke is now being replaced by coal injected at the tuyere area of the furnace where the blast air enters. The purpose of this study is to evaluate the combustion of coal during the blast furnace injection process and to delineate the optimum properties of the feed coal with particular reference to the coals from the Illinois Basin. Although this research is not yet completed the results to date support the following conclusions: (1) based on the results of computer modeling, lower rank bituminous coals, including coal from the Illinois Basin, compare well in their injection properties with a variety of other bituminous coals, although the replacement ratio improves with increasing rank; (2) based on the results of petrographic analysis of material collected from an active blast furnace, it is clear the coal derived char is entering into the raceway of the blast furnace; (3) the results of reactivity experiments on a variety of coal chars at a variety of reaction temperatures show that lower rank bituminous coals, including coal from the Illinois basin, yield chars with significantly higher reactivities in both air and CO{sub 2} than chars from higher rank Appalachian coals and blast furnace coke. These results indicate that the chars from the lower rank coals should have a superior burnout rate in the tuyere and should survive in the raceway environment for a shorter time. These coals, therefore, will have important advantages at high rates of injection that may overcome their slightly lower replacement rates.

  8. Maintaining Low Oxygen (O2) in Coal Fueled Utility Boilers Using CO Instrumentation

    E-Print Network [OSTI]

    Hopkins, D.; Downing, T.

    and the annual fuel savings possible from this 02 reduction. Unit til 1.8 a pulverized coal fired, 565 MW, CE boiler system placed in service July 27, 1982. Complete and safe combustion in this boiler is maintained by continuously monitoring 02 and CO...Il at Muleshoe, Texas. This is a 565 :Megawatt unit utilizing a Combustion Engineering boiler firing sub-bituminous Wyoming coal thrQugh six elevations of tilting tangential nozzles. The boiler is balanced draft with two air preheaters. Environmental...

  9. Petrographic characterization of economizer fly ash

    SciTech Connect (OSTI)

    Valentim, B.; Hower, J.C.; Soares, S.; Guedes, A.; Garcia, C.; Flores, D.; Oliveira, A. [University of Porto, Oporto (Portugal). Center of Geology

    2009-11-15T23:59:59.000Z

    Policies for reducing NOx emissions have led power plants to restrict O{sub 2}, resulting in high-carbon fly ash production. Therefore, some potentially useful fly ash, such as the economizer fly ash, is discarded without a thorough knowledge of its composition. In order to characterize this type of fly ash, samples were collected from the economizer Portuguese power plant burning two low-sulfur bituminous coals. Characterization was also performed on economizer fly ash subsamples after wet sieving, density and magnetic separation. Analysis included atomic absorption spectroscopy, loss-on-ignition, scanning electron microscopy/energy-dispersive X-ray spectroscopy, optical microscopy, and micro-Raman spectroscopy.

  10. The Wilsonville Advanced Coal Liquefaction Research and Development Facility, Wilsonville, Alabama

    SciTech Connect (OSTI)

    Not Available

    1990-05-01T23:59:59.000Z

    This reports presents the operating results for Run 252 at the Advanced Coal Liquefaction R D Facility in Wilsonville, Alabama. This run operated in the Close-Coupled Integrated Two-Stage Liquefaction mode (CC-ITSL) using Illinois No. 6 bituminous coal. The primary run objective was demonstration of unit and system operability in the CC-ITSL mode with catalytic-catalytic reactors and with ash recycle. Run 252 began on 26 November 1986 and continued through 3 February 1987. During this period 214.4 MF tons of Illinois No. 6 coal were fed in 1250 hours of operation. 3 refs., 29 figs., 18 tabs.

  11. Radioactive waste treatment technologies and environment

    SciTech Connect (OSTI)

    HORVATH, Jan; KRASNY, Dusan [JAVYS, PLc. - Nuclear and Decommisioning Company, PLc. (Slovakia)

    2007-07-01T23:59:59.000Z

    The radioactive waste treatment and conditioning are the most important steps in radioactive waste management. At the Slovak Electric, plc, a range of technologies are used for the processing of radioactive waste into a form suitable for disposal in near surface repository. These technologies operated by JAVYS, PLc. Nuclear and Decommissioning Company, PLc. Jaslovske Bohunice are described. Main accent is given to the Bohunice Radwaste Treatment and Conditioning Centre, Bituminization plant, Vitrification plant, and Near surface repository of radioactive waste in Mochovce and their operation. Conclusions to safe and effective management of radioactive waste in the Slovak Republic are presented. (authors)

  12. Emissions mitigation of blended coals through systems optimization

    SciTech Connect (OSTI)

    Don Labbe [IOM Invensys Operations Management (United States)

    2009-10-15T23:59:59.000Z

    For coal fired power stations, such as those located in the US, that have installed NOx and SOx emissions abatement equipment substantial carbon dioxide reduction could be achieved by shifting from pure PRB coal to blended coals with local bituminous coal. Don Labbe explains how. The article is based on a presentation at Power-Gen Asia 2009, which takes place 7-9 October in Bangkok, Thailand and an ISA POWID 2009 paper (19th Annual Joint ISA POWID/EPRI Controlls and Instrumentation Conference, Chicago, Illinois, May 2009). 4 refs., 3 figs.

  13. METHANE de-NOX for Utility PC Boilers

    SciTech Connect (OSTI)

    Bruce Bryan; Joseph Rabovitser; Serguei Nester; Stan Wohadlo

    2005-06-30T23:59:59.000Z

    Large-scale combustion tests with caking bituminous coal has stopped. This stoppage has come about due to limitations in current funding available to continue large scale research and development activities at Riley's Commercial Burner Test Facility (CBTF) of the PC Preheat technology. The CBTF was secured and decommissioned in the previous quarter; work this quarter has focused on disposition of PC Preheat experimental equipment at the CBTF as well as methods for disposal of about 100 tons of residual PRB test coal in storage. GTI was granted a no-cost time extension through September 2005; a final report is due in December 2005.

  14. Thinking beyond the fire

    SciTech Connect (OSTI)

    Pircon, R. [Benetech (United States)

    2006-07-15T23:59:59.000Z

    Assuring optimal performance, adaptability and overall coal yard competitiveness means more than just avoiding catastrophe. Increasing use of subbituminous coal requires better understanding of coal transfers, storage and Powder River Basin/bituminous coal blends. Introducing PRB coal increases susceptibility to spontaneous combustion so spillage and dust become larger issues. Coal yard risk overviews, such as Benetech's Risk Index, are emerging. Benetech's steps for evaluating fire and efficiency requires: identifying variables; establishing 'best-in-class' remedies; implementing performance standards; and monitoring progress with reevaluation techniques. The article explains these steps. 2 photos.

  15. Paints and Painting Materials and Miscellaneous Analyses.

    E-Print Network [OSTI]

    Harrington, H. H.; Tilson, P. S.

    1897-01-01T23:59:59.000Z

    . DISTILLATION OF BY-PEODUCTS FROM LIGNITE-TAR. Two light black, watery products from lignite-tar were sent for ex? amination, and gave the following results: Boiling point when received: No. 1, 94 degrees; No. 2, 81 degrees. Distilled at 75 to 150 degrees... of lignite for analysis are frequently received. Below are given types of these from different localities, as well as a sample of Coke from wood tar, and a sample of Bituminous coal from Corsicana. No. 1 is lignite from Crockett; No. 2 from Burleson county...

  16. Decaking of coal or oil shale during pyrolysis in the presence of iron oxides

    DOE Patents [OSTI]

    Khan, M. Rashid (Morgantown, WV)

    1989-01-01T23:59:59.000Z

    A method for producing a fuel from the pyrolysis of coal or oil shale in the presence of iron oxide in an inert gas atmosphere. The method includes the steps of pulverizing feed coal or oil shale, pulverizing iron oxide, mixing the pulverized feed and iron oxide, and heating the mixture in a gas atmosphere which is substantially inert to the mixture so as to form a product fuel, which may be gaseous, liquid and/or solid. The method of the invention reduces the swelling of coals, such as bituminous coal and the like, which are otherwise known to swell during pyrolysis.

  17. Assessment of solid-waste characteristics and control technology for oil-shale retorting. Final report for September 1983-February 1985

    SciTech Connect (OSTI)

    Agarwal, A.K.

    1986-05-01T23:59:59.000Z

    The report presents information on oil-shale deposits in the eastern and western parts of the United States, their geological subdivisions, locations, tonnage, and physical and chemical characteristics. Characteristics of solid and liquid wastes produced from various oil-shale-processing technologies and control methods are presented. Also included are results from an experimental study to construct liners and covers for disposal of spent shale. A compilation of available data on the auto-ignition potential of raw and spent shales indicates a similarity between raw-shale fines and bituminous coals.

  18. Decaking of coal or oil shale during pyrolysis in the presence of iron oxides

    DOE Patents [OSTI]

    Rashid Khan, M.

    1988-05-05T23:59:59.000Z

    A method for producing a fuel from the pyrolysis of coal or oil shale in the presence of iron oxide in an inert gas atmosphere is described. The method includes the steps of pulverizing feed coal or oil shale, pulverizing iron oxide, mixing the pulverized feed and iron oxide, and heating the mixture in a gas atmosphere which is substantially inert to the mixture so as to form a product fuel, which may be gaseous, liquid and/or solid. The method of the invention reduces the swelling of coals, such as bituminous coal and the like, which are otherwise known to swell during pyrolysis. 4 figs., 8 tabs.

  19. System studies guiding fossil energy RD & D

    SciTech Connect (OSTI)

    NONE

    2007-12-31T23:59:59.000Z

    The article describes the following recently completed studies, all of which may be accessed on NETL's website: http://netl.doe.gov/energy-analyses/ref-shelf.html: Cost and performance baseline for fossil energy power plants - volume 1: bituminous coal and natural gas to electricity (May 2007); Increasing security and reducing carbon emissions of the US transportation sector: a transformational role for coal with biomass (August 2007); Industrial size gasification for syngas, substitute natural gas, and power production (April 2007); and Carbon dioxide capture from existing coal-fired power plants (December 2006). 2 figs.

  20. Wyoming coal-conversion project. Final technical report, November 1980-February 1982. [Proposed WyCoalGas project, Converse County, Wyoming; contains list of appendices with title and identification

    SciTech Connect (OSTI)

    None

    1982-01-01T23:59:59.000Z

    This final technical report describes what WyCoalGas, Inc. and its subcontractors accomplished in resolving issues related to the resource, technology, economic, environmental, socioeconomic, and governmental requirements affecting a project located near Douglas, Wyoming for producing 150 Billion Btu per day by gasifying sub-bituminous coal. The report summarizes the results of the work on each task and includes the deliverables that WyCoalGas, Inc. and the subcontractors prepared. The co-venturers withdrew from the project for two reasons: federal financial assistance to the project was seen to be highly uncertain; and funds were being expended at an unacceptably high rate.

  1. 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)

    2008-12-15T23:59:59.000Z

    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.

  2. EARLY ENTRANCE CO-PRODUCTION PLANT--DECENTRALIZED GASIFICATION COGENERATION TRANSPORTATION FUELS AND STEAM FROM AVAILABLE FEEDSTOCKS

    SciTech Connect (OSTI)

    John W. Rich

    2003-06-01T23:59:59.000Z

    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 January 1, 2003 through March 31, 2003. Phase I Task 6 activities of Preliminary Site Analysis were documented and reported as a separate Topical Report on February 2003. Most of the other technical activities were on hold pending on DOE's announcement of the Clean Coal Power Initiative (CCPI) awards. WMPI was awarded one of the CCPI projects in late January 2003 to engineer, construct and operate a first-of-kind gasification/liquefaction facility in the U.S. as a continued effort for the current WMPI EECP engineering feasibility study. Since then, project technical activities were focused on: (1) planning/revising the existing EECP work scope for transition into CCPI, and (2) ''jump starting'' all environmentally related work in pursue of NEPA and PA DEP permitting approval.

  3. Coal Reburning for Cyclone Boiler NO[sub x] Control Demonstration

    SciTech Connect (OSTI)

    Not Available

    1992-01-01T23:59:59.000Z

    The project involves retrofitting/testing the reburning technology at Wisconsin Power Light's 100 MWe Nelson Dewey unit No. 2 in Cassville, Wisconsin to determine the commercial applicability of this technology to reduce NO[sub x] emission levels. The final set of performance tests on Lamar coal were carried out from September 27 through October 9, 1992. Hazardous air pollutant (HAP) testing was performed on Lamar coal from November 2 through November 9, 1992. Also, parametric optimization testing on western sub-bituminous coal was performed from November 16 through December 11, 1992. Both the HAP and western fuel testing were additions to the original project testing scope of Phase III. As of the end of this quarterly report period, project Phase III testing is complete. Preliminary results with western sub-bituminous coal indicate NO[sub 4] reductions in excess of 50% down to the 50% load range. In general, similar reductions are experienced but at a less aggressive stoichiometry in the reburn zone. Accordingly, an additional few percent of NO[sub 4] reduction at the same stoichiometry are noted with the western fuel compared to Lamar results.

  4. Coal Reburning for Cyclone Boiler NO{sub x} Control Demonstration. Quarterly report No. 11, October--December 1992

    SciTech Connect (OSTI)

    Not Available

    1992-12-31T23:59:59.000Z

    The project involves retrofitting/testing the reburning technology at Wisconsin Power & Light`s 100 MWe Nelson Dewey unit No. 2 in Cassville, Wisconsin to determine the commercial applicability of this technology to reduce NO{sub x} emission levels. The final set of performance tests on Lamar coal were carried out from September 27 through October 9, 1992. Hazardous air pollutant (HAP) testing was performed on Lamar coal from November 2 through November 9, 1992. Also, parametric optimization testing on western sub-bituminous coal was performed from November 16 through December 11, 1992. Both the HAP and western fuel testing were additions to the original project testing scope of Phase III. As of the end of this quarterly report period, project Phase III testing is complete. Preliminary results with western sub-bituminous coal indicate NO{sub 4} reductions in excess of 50% down to the 50% load range. In general, similar reductions are experienced but at a less aggressive stoichiometry in the reburn zone. Accordingly, an additional few percent of NO{sub 4} reduction at the same stoichiometry are noted with the western fuel compared to Lamar results.

  5. Coal rank trends in western Kentucky coal field and relationship to hydrocarbon occurrence

    SciTech Connect (OSTI)

    Hower, J.C.; Rimmer, S.M.; Williams, D.A.; Beard, J.G. (Univ. of Kentucky, Lexington (USA))

    1989-09-01T23:59:59.000Z

    Extensive oil and gas development has occurred in the high volatile C bituminous region north of the Rough Creek fault zone, but few pools are known within the Webster syncline south of the fault zone. The rank of the Middle Pennsylvanian coals can be used to estimate the level of maturation of the Devonian New Albany Shale, a likely source rock for much of the oil and gas in the coal field. Based on relatively few data points, previous studies on the maturation of the New Albany Shale, which lies about 1 km below the Springfield coal, indicate an equivalent medium volatile bituminous (1.0-1.2% R{sub max}) rank in the Fluorspar district. New Albany rank decreases to an equivalent high volatile B/C (0.6% R{sub max}) north of the Rough Creek fault zone. Whereas the shale in the latter region is situated within the oil generation window, the higher rank region is past the peak of the level of maturation of the New Albany Shale. The significance of the New Albany reflectancy is dependent on the suppression of vitrinite reflectance in organic-rich shales. The possibility of reflectance suppression would imply that the shales could be more mature than studies have indicated.

  6. Hardgrove grindability study of Powder River Basin and Appalachian coal components in the blend to a midwestern power station

    SciTech Connect (OSTI)

    Padgett, P.L.; Hower, J.C. [Univ. of Kentucky, Lexington, KY (United States)

    1996-12-31T23:59:59.000Z

    Five coals representing four distinct coal sources blended at a midwestern power station were subjected to detailed analysis of their Hardgrove grindability. The coals are: a low-sulfur, high volatile A bituminous Upper Elkhorn No. 3 coal (Pike County, KY); a medium-sulfur, high volatile A bituminous Pittsburgh coal (southwestern PA); a low-sulfur, subbituminous Wyodak coal from two mines in the eastern Powder River Basin (Campbell County, WY). The feed and all samples processed in the Hardgrove grindability test procedure were analyzed for their maceral and microlithotype content. The high-vitrinite Pittsburgh coal and the relatively more petrographically complex Upper Elkhorn No. 3 coal exhibit differing behavior in grindability. The Pittsburgh raw feed, 16x30 mesh fraction (HGI test fraction), and the {minus}30 mesh fraction (HGI reject) are relatively similar petrographically, suggesting that the HGI test fraction is reasonably representative of the whole feed. The eastern Kentucky coal is not as representative of the whole feed, the HGI test fraction having lower vitrinite than the rejected {minus}30 mesh fraction. The Powder River Basin coals are high vitrinite and show behavior similar to the Pittsburgh coal.

  7. Preliminary Field Evaluation of Mercury Control Using Combustion Modifications

    SciTech Connect (OSTI)

    V. Lissianski; P. Maly; T. Marquez

    2005-01-22T23:59:59.000Z

    In this project EER conducted a preliminary field evaluation of the integrated approach for mercury (Hg) and NO{sub x} control. The approach enhanced the 'naturally occurring' Hg capture by fly ash through combustion optimization, increasing carbon in ash content, and lowering ESP temperature. The evaluation took place in Green Station Units 1 and 2 located near Henderson, Kentucky and operated by Western Kentucky Energy. Units 1 and 2 are equipped with cold-side ESPs and wet scrubbers. Green Station Units 1 and 2 typically fire two types of fuel: a bituminous coal and a blend of bituminous coals based on availability. Testing of Hg emissions in Unit 2 without reburning system in operation and at minimum OFA demonstrated that efficiencies of Hg reduction downstream of the ESP were 30-40%. Testing also demonstrated that OFA system operation at 22% air resulted in 10% incremental increase in Hg removal efficiency at the ESP outlet. About 80% of Hg in flue gas at ESP outlet was present in the oxidized form. Testing of Hg emissions under reburning conditions showed that Hg emissions decreased with LOI increase and ESP temperature decrease. Testing demonstrated that maximum Hg reduction downstream of ESP was 40-45% at ESP temperatures higher than 300 F and 60-80% at ESP temperatures lower than 300 F. The program objective to demonstrate 80% Hg removal at the ESP outlet has been met.

  8. Evaluating gas content of black warrior basin coalbeds from wireline log data

    SciTech Connect (OSTI)

    Colson, J.L. (Schlumberger Well Services (US))

    1991-07-01T23:59:59.000Z

    This paper reports that coalbeds have long been known to contain natural gas in varying amounts. To the mining industry, this is basically a hazard to be controlled and avoided where possible. To the petroleum industry, it is an exploitable resource that holds significant economic potential because of shallow drilling and the promising of long well life. The variability of coal as a gas reservoir raises the need for oil and gas-well explorers to develop the capability of evaluating coalbed gas content to identify and produce coal gas plays. Current petrophysical models for gas reservoir analysis in traditional clastic or carbonate environments are notable inadequate for evaluation of gas content in coal beds. However, numerous physical models exist for coals throughout the country, primarily from the efforts of the mining industry. A theoretical model was chosen and used to establish a method for evaluating gas content of coalbeds in the Black Warrior basin of Alabama. Core data in the form of proximate analysis, ultimate analysis, and gas desorption measurements were used, along with wireline data, to build the models. Results of data analysis in wells with coals ranging from low-volatile bituminous to high-volatile B bituminous are compared with core gas desorption measurements to demonstrate the accuracy of the process.

  9. Air-substrate mercury exchange associated with landfill disposal of coal combustion products

    SciTech Connect (OSTI)

    Mei Xin; Mae S. Gustin; Kenneth Ladwig; Debra F. Pflughoeft-Hassett [University of Nevada, Reno, NV (United States). Department of Natural Resources and Environmental Science

    2006-08-15T23:59:59.000Z

    Previous laboratory studies have shown that lignite-derived fly ash emitted mercury (Hg) to the atmosphere, whereas bituminous- and subbituminous-derived fly ash samples adsorbed Hg from the air. In addition, wet flue gas desulfurization (FGD) materials were found to have higher Hg emission rates than fly ash. This study investigated in situ Hg emissions at a blended bituminous-subbituminous ash land-fill in the Great Lakes area and a lignite-derived ash and FGD solids landfill in the Midwestern United States using a dynamic field chamber. Fly ash and saturated FGD materials emitted Hg to atmosphere at low rates (- 0.1 to 1.2 ng/m{sup 2}hr), whereas FGD material mixed with fly ash and pyrite exhibited higher emission rates ({approximately} 10 ng/m{sup 2}hr) but were still comparable with natural background soils (- 0.3 to 13 ng/m{sup 2}hr). Air temperature, solar radiation, and relative humidity were important factors correlated with measured Hg fluxes. Field study results were not consistent with corresponding laboratory observations in that fluxes measured in the latter were higher and more variable. This is hypothesized to be partially an artifact of the flux measurement methods. 19 refs., 4 figs., 6 tabs.

  10. Pilot-scale study of the effect of selective catalytic reduction catalyst on mercury speciation in Illinois and Powder River Basin coal combustion flue gases

    SciTech Connect (OSTI)

    Lee, C.W.; Srivastava, R.K.; Ghorishi, S.B.; Karwowski, J.; Hastings, T.H.; Hirschi, J.C. [US Environmental Protection Agency, Triangle Park, NC (United States)

    2006-05-15T23:59:59.000Z

    A study was conducted to investigate the effect of selective catalytic reduction (SCR) catalyst on mercury (Hg) speciation in bituminous and subbituminous coal combustion flue gases. Three different Illinois Basin bituminous coals (from high to low sulfur (S) and chlorine (Cl)) and one Powder River Basin (PRB) subbituminous coal with very low S and very low Cl were tested in a pilot-scale combustor equipped with an SCR reactor for controlling nitrogen oxides (NO{sub x}) emissions. The SCR catalyst induced high oxidation of elemental Hg (Hg{sup 0}), decreasing the percentage of Hg{sup 0} at the outlet of the SCR to values <12% for the three Illinois coal tests. The PRB coal test indicated a low oxidation of Hg{sup 0} by the SCR catalyst, with the percentage of Hg{sup 0} decreasing from {approximately} 96% at the inlet of the reactor to {approximately} 80% at the outlet. The low Cl content of the PRB coal and corresponding low level of available flue gas Cl species were believed to be responsible for low SCR Hg oxidation for this coal type. The test results indicated a strong effect of coal type on the extent of Hg oxidation. 16 refs., 4 figs., 3 tabs.

  11. Market assessment of PFBC ash use

    SciTech Connect (OSTI)

    Bland, A. E.; Brown, T. H., Western Research Institute

    1998-01-01T23:59:59.000Z

    Pressurized fluidized bed combustion (PFBC) of coal is undergoing demonstration in the United States, as well as throughout the world. American Electric Power`s (AEP`s) bubbling PFBC 70 MWe Tidd demonstration program in Ohio and pilot-scale development at Foster Wheeler Energia Oy 10 MWth circulating PFBC at Karhula, Finland, have demonstrated the advantages of PFBC technology. Further technology development in the US is planned with the deployment of the technology at the MacIntosh Clean Coal project in Lakeland, Florida. Development of uses for solid wastes from PFBC coal-fired power systems is being actively pursued as part of the demonstration of PFBC technologies. Ashes collected from Foster Wheeler Energia Oy pilot circulating PFBC tests in Karhula, Finland, operating on (1) low sulfur subbituminous and (2) high sulfur bituminous coal; and ash from the AEP`s high-sulfur bituminous coal-fired bubbling PFBC in Brilliant, Ohio, were evaluated in laboratory and pilot-scale ash use testing at Western Research Institute (WRI).

  12. Oxidative derivatization and solubilization of coal. Final report. Period: October 1, 1986 - April 30, 1988

    SciTech Connect (OSTI)

    Schulz, J.G.; Porowski, E.N.; Straub, A.M.

    1988-05-01T23:59:59.000Z

    We investigated the solubilization of coal by oxidative means to produce motor fuels. Nitric acid was used in the first of two approaches taken to cleave aliphatic linkages in coal and reduce the size of its macrostructure. Mild conditions, with temperatures up to a maximum of 75 C, and nitric acid concentrations below 20% by weight, characterize this process. The solid product, obtained in high yields, is soluble in polar organic solvents. Lower alcohols, methanol in particular, are of interest as carrier solvents in diesel fuel applications. Coals investigated were New York State peat, Wyodak subbituminous coal, North Dakota lignite, and Illinois No. 6 bituminous coal. The lower tank coals were easily converted and appear well suited to the process, while the bituminous Illinois No. 6 and Pitt Seam coals were unreactive. We concentrated our efforts on Wyodak coal and North Dakota lignite. Reaction conditions with regards to temperature, acid concentration, and time were optimized to obtain high product selectivity at maximum conversion. A continuous process scheme was developed for single pass coal conversions of about 50% to methanol-soluble product.

  13. The Self-Ignition Temperatures of Bitumen Mixtures Containing Transition Metal Nitrates

    SciTech Connect (OSTI)

    Okada, Ken; Nomura, Masao; Fujii, Yasuhiko [Tokyo Institute of Technology (Japan)

    2000-01-15T23:59:59.000Z

    Information is provided on the self-ignition temperature (SIT) of blown bitumen asphalt mixed with sodium nitrate and some chemicals that are added in the bituminization process to adjust pH and to immobilize the radioactive isotopes of Cs, Sr, and I. In each ignition temperature test, the prepared bitumen sample was heated at a constant rate of temperature increase, and the ignition point was measured. Among the tested chemicals added to the bitumen, Ni(NO{sub 3}){sub 2} shows a relatively large SIT decrease, and furthermore, the mixture of Ni(NO{sub 3}){sub 2} and AgNO{sub 3} has been shown to greatly lower the SIT of blown bitumen. It is suggested that, in general, segregation of these nitrates should be avoided in bituminization, and care should be taken in handling Ag in a Purex reprocessing plant from the viewpoint of waste treatment. Furthermore, the oxidation effects of Fe(NO{sub 3}){sub 3} were tested by measuring torque of the bitumen sample. It was confirmed that the addition of Fe(NO{sub 3}){sub 3} to bitumen rapidly oxidizes the bitumen and increases the viscosity of the bitumen mixture.

  14. CO2 Sequestration in Unmineable Coal Seams: Potential Environmental Impacts

    SciTech Connect (OSTI)

    Hedges, S.W.; Soong, Yee; McCarthy Jones, J.R.; Harrison, D.K.; Irdi, G.A.; Frommell, E.A.; Dilmore, R.M.; Pique, P.J.; Brown, T.D

    2005-09-01T23:59:59.000Z

    An initial investigation into the potential environmental impacts of CO2 sequestration in unmineable coal seams has been conducted, focusing on changes in the produced water during enhanced coalbed methane (ECBM) production using a CO2 injection process (CO2-ECBM). Two coals have been used in this study, the medium volatile bituminous Upper Freeport coal (APCS 1) of the Argonne Premium Coal Samples series, and an as-mined Pittsburgh #8 coal, which is a high volatile bituminous coal. Coal samples were reacted with either synthetic produced water or field collected produced water and gaseous carbon dioxide at 40 ?C and 50 bar to evaluate the potential for mobilizing toxic metals during CO2-ECBM/sequestration. Microscopic and x-ray diffraction analysis of the post-reaction coal samples clearly show evidence of chemical reaction, and chemical analysis of the produced water shows substantial changes in composition. These results suggest that changes to the produced water chemistry and the potential for mobilizing toxic trace elements from coalbeds are important factors to be considered when evaluating deep, unmineable coal seams for CO2 sequestration.

  15. Catalytic steam gasification reactivity of HyperCoals produced from different rank of coals at 600-775{degree}C

    SciTech Connect (OSTI)

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

    2008-11-15T23:59:59.000Z

    HyperCoal is a clean coal with ash content <0.05 wt %. HyperCoals were prepared from a brown coal, a sub-bituminous coal, and a bituminous raw coal by solvent extraction method. Catalytic steam gasification of these HyperCoals was carried out with K{sub 2}CO{sub 3} at 775, 700, 650, and 600 {degree}C, and their rates were compared. HyperCoals produced from low-rank coals were more reactive than those produced from the high-rank coals. XRD measurements were carried out to understand the difference in gasification reactivity of HyperCoals. Arrhenius plot of ln (k) vs 1/T in the temperature range 600-825{degree}C was a curve rather than a straight line. The point of change was observed at 700{degree}C for HyperCoals from low-rank coals and at 775{degree}C for HyperCoals from high-rank coals. Using HyperCoal produced from low-rank coals as feedstock, steam gasification of coal may be possible at temperatures less than 650{degree}C. 22 refs., 6 figs., 2 tabs.

  16. Petrology of the Devonian gas-bearing shale along Lake Erie helps explain gas shows

    SciTech Connect (OSTI)

    Broadhead, R.F.; Potter, P.E.

    1980-11-01T23:59:59.000Z

    Comprehensive petrologic study of 136 thin sections of the Ohio Shale along Lake Erie, when combined with detailed stratigraphic study, helps explain the occurrence of its gas shows, most of which occur in the silty, greenish-gray, organic poor Chagrin Shale and Three Lick Bed. Both have thicker siltstone laminae and more siltstone beds than other members of the Ohio Shale and both units also contain more clayshales. The source of the gas in the Chagrin Shale and Three Lick Bed of the Ohio Shale is believed to be the bituminous-rich shales of the middle and lower parts of the underlying Huron Member of the Ohio Shale. Eleven petrographic types were recognized and extended descriptions are provided of the major ones - claystones, clayshales, mudshales, and bituminous shales plus laminated and unlaminated siltstones and very minor marlstones and sandstones. In addition three major types of lamination were identified and studied. Thirty-two shale samples were analyzed for organic carbon, whole rock hydrogen and whole rock nitrogen with a Perkin-Elmer 240 Elemental Analyzer and provided the data base for source rock evaluation of the Ohio Shale.

  17. Field Testing of a Wet FGD Additive for Enhanced Mercury Control

    SciTech Connect (OSTI)

    Gary Blythe; MariJon Owens

    2007-12-31T23:59:59.000Z

    This document is the final report for DOE-NETL Cooperative Agreement DE-FC26-04NT42309, 'Field Testing of a Wet FGD Additive'. The objective of the project has been to demonstrate the use of two flue gas desulfurization (FGD) additives, Evonik Degussa Corporation's TMT-15 and Nalco Company's Nalco 8034, to prevent the re-emission of elemental mercury (Hg{sup 0}) in flue gas exiting wet FGD systems on coal-fired boilers. Furthermore, the project was intended to demonstrate whether such additives can be used to precipitate most of the mercury (Hg) removed in the wet FGD system as a fine salt that can be separated from the FGD liquor and bulk solid byproducts for separate disposal. The project involved pilot- and full-scale tests of the additives in wet FGD absorbers. The tests were intended to determine required additive dosages to prevent Hg{sup 0} re-emissions and to separate mercury from the normal FGD byproducts for three coal types: Texas lignite/Powder River Basin (PRB) coal blend, high-sulfur Eastern bituminous coal, and low-sulfur Eastern bituminous coal. The project team consists of URS Group, Inc., EPRI, Luminant Power (was TXU Generation Company LP), Southern Company, IPL (an AES company), Evonik Degussa Corporation and the Nalco Company. Luminant Power provided the Texas lignite/PRB co-fired test site for pilot FGD tests and project cost sharing. Southern Company provided the low-sulfur Eastern bituminous coal host site for wet scrubbing tests, the pilot- and full-scale jet bubbling reactor (JBR) FGD systems tested, and project cost sharing. IPL provided the high-sulfur Eastern bituminous coal full-scale FGD test site and cost sharing. Evonik Degussa Corporation provided the TMT-15 additive, and the Nalco Company provided the Nalco 8034 additive. Both companies also supplied technical support to the test program as in-kind cost sharing. The project was conducted in six tasks. Of the six tasks, Task 1 involved project planning and Task 6 involved management and reporting. The other four tasks involved field testing on FGD systems, either at pilot or full scale. These four tasks included: Task 2 - Pilot Additive Testing in Texas Lignite Flue Gas; Task 3 - Full-scale FGD Additive Testing in High-sulfur Eastern Bituminous Flue Gas; Task 4 - Pilot Wet Scrubber Additive Tests at Plant Yates; and Task 5 - Full-scale Additive Tests at Plant Yates. The pilot-scale tests were completed in 2005 and the full-scale test using high-sulfur coal was completed in 2006; only the TMT-15 additive was tested in these efforts. The Task 5 full-scale additive tests conducted at Southern Company's Plant Yates Unit 1 were completed in 2007, and both the TMT-15 and Nalco 8034 additives were tested.

  18. Field Testing of a Wet FGD Additive for Enhanced Mercury Control - Task 5 Full-Scale Test Results

    SciTech Connect (OSTI)

    Gary Blythe; MariJon Owens

    2007-12-01T23:59:59.000Z

    This Topical Report summarizes progress on Cooperative Agreement DE-FC26-04NT42309, 'Field Testing of a Wet FGD Additive'. The objective of the project is to demonstrate the use of two flue gas desulfurization (FGD) additives, Evonik Degussa Corporation's TMT-15 and Nalco Company's Nalco 8034, to prevent the re-emission of elemental mercury (Hg{sup 0}) in flue gas exiting wet FGD systems on coal-fired boilers. Furthermore, the project intends to demonstrate whether the additive can be used to precipitate most of the mercury (Hg) removed in the wet FGD system as a fine salt that can be separated from the FGD liquor and bulk solid byproducts for separate disposal. The project is conducting pilot- and full-scale tests of the additives in wet FGD absorbers. The tests are intended to determine required additive dosages to prevent Hg{sup 0} re-emissions and to separate mercury from the normal FGD byproducts for three coal types: Texas lignite/Powder River Basin (PRB) coal blend, high-sulfur Eastern bituminous coal, and low-sulfur Eastern bituminous coal. The project team consists of URS Group, Inc., EPRI, Luminant Power (was TXU Generation Company LP), Southern Company, IPL (an AES company), Evonik Degussa Corporation and the Nalco Company. Luminant Power has provided the Texas lignite/PRB co-fired test site for pilot FGD tests and cost sharing. Southern Company has provided the low-sulfur Eastern bituminous coal host site for wet scrubbing tests, as well as the pilot- and full-scale jet bubbling reactor (JBR) FGD systems tested. IPL provided the high-sulfur Eastern bituminous coal full-scale FGD test site and cost sharing. Evonik Degussa Corporation is providing the TMT-15 additive, and the Nalco Company is providing the Nalco 8034 additive. Both companies are also supplying technical support to the test program as in-kind cost sharing. The project is being conducted in six tasks. Of the six project tasks, Task 1 involves project planning and Task 6 involves management and reporting. The other four tasks involve field testing on FGD systems, either at pilot or full scale. The four tasks include: Task 2 - Pilot Additive Testing in Texas Lignite Flue Gas; Task 3 - Full-scale FGD Additive Testing in High-sulfur Eastern Bituminous Flue Gas; Task 4 - Pilot Wet Scrubber Additive Tests at Plant Yates; and Task 5 - Full-scale Additive Tests at Plant Yates. The pilot-scale tests and the full-scale test using high-sulfur coal were completed in 2005 and 2006 and have been previously reported. This topical report presents the results from the Task 5 full-scale additive tests, conducted at Southern Company's Plant Yates Unit 1. Both additives were tested there.

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

    SciTech Connect (OSTI)

    Galen H. Richards; Charles Q. Maney; Richard W. Borio; Robert D. Lewis

    2002-12-30T23:59:59.000Z

    ALSTOM Power Inc.'s Power Plant Laboratories, working in concert with ALSTOM Power's Performance Projects Group, has teamed with the U.S. Department of Energy's National Energy Technology Laboratory (DOE NETL) to conduct a comprehensive study to develop/evaluate low-cost, efficient NOx control technologies for retrofit to pulverized coal fired utility boilers. The objective of this project was to develop retrofit NOx control technology to achieve less than 0.15 lb/MMBtu NOx (for bituminous coals) and 0.10 lb/MMBtu NOx (for subbituminous coals) from existing pulverized coal fired utility boilers at a cost which is at least 25% less than SCR technology. Efficient control of NOx is seen as an important, enabling step in keeping coal as a viable part of the national energy mix in this century, and beyond. Presently 57% of U.S. electrical generation is coal based, and the Energy Information Agency projects that coal will maintain a lead in U.S. power generation over all other fuel sources for decades (EIA 1998 Energy Forecast). Yet, coal-based power is being strongly challenged by society's ever-increasing desire for an improved environment and the resultant improvement in health and safety. The needs of the electric-utility industry are to improve environmental performance, while simultaneously improving overall plant economics. This means that emissions control technology is needed with very low capital and operating costs. This project has responded to the industry's need for low NOx emissions by evaluating ideas that can be adapted to present pulverized coal fired systems, be they conventional or low NOx firing systems. The TFS 2000{trademark} firing system has been the ALSTOM Power Inc. commercial offering producing the lowest NOx emission levels. In this project, the TFS 2000{trademark} firing system served as a basis for comparison to other low NOx systems evaluated and was the foundation upon which refinements were made to further improve NOx emissions and related combustion performance. Three coals were evaluated during the bench-scale and large pilot-scale testing tasks. The three coals ranged from a very reactive Powder River Basin coal (PRB) to a moderately reactive Midwestern bituminous coal (HVB) to a less reactive medium volatile Eastern bituminous coal (MVB). Bench-scale testing was comprised of standard ASTM properties evaluation, plus more detailed characterization of fuel properties through drop tube furnace testing and thermogravimetric analysis.

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

    SciTech Connect (OSTI)

    Stone, Richard; Gray, Gordon; Evans, Robert

    2014-07-31T23:59:59.000Z

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

  1. Enzymantic Conversion of Coal to Liquid Fuels

    SciTech Connect (OSTI)

    Richard Troiano

    2011-01-31T23:59:59.000Z

    The work in this project focused on the conversion of bituminous coal to liquid hydrocarbons. The major steps in this process include mechanical pretreatment, chemical pretreatment, and finally solubilization and conversion of coal to liquid hydrocarbons. Two different types of mechanical pretreatment were considered for the process: hammer mill grinding and jet mill grinding. After research and experimentation, it was decided to use jet mill grinding, which allows for coal to be ground down to particle sizes of 5 {mu}m or less. A Fluid Energy Model 0101 JET-O-MIZER-630 size reduction mill was purchased for this purpose. This machine was completed and final testing was performed on the machine at the Fluid Energy facilities in Telford, PA. The test results from the machine show that it can indeed perform to the required specifications and is able to grind coal down to a mean particle size that is ideal for experimentation. Solubilization and conversion experiments were performed on various pretreated coal samples using 3 different approaches: (1) enzymatic - using extracellular Laccase and Manganese Peroxidase (MnP), (2) chemical - using Ammonium Tartrate and Manganese Peroxidase, and (3) enzymatic - using the live organisms Phanerochaete chrysosporium. Spectral analysis was used to determine how effective each of these methods were in decomposing bituminous coal. After analysis of the results and other considerations, such as cost and environmental impacts, it was determined that the enzymatic approaches, as opposed to the chemical approaches using chelators, were more effective in decomposing coal. The results from the laccase/MnP experiments and Phanerochaete chrysosporium experiments are presented and compared in this final report. Spectra from both enzymatic methods show absorption peaks in the 240nm to 300nm region. These peaks correspond to aromatic intermediates formed when breaking down the coal structure. The peaks then decrease in absorbance over time, corresponding to the consumption of aromatic intermediates as they undergo ring cleavage. The results show that this process happens within 1 hour when using extracellular enzymes, but takes several days when using live organisms. In addition, live organisms require specific culture conditions, control of contaminants and fungicides in order to effectively produce extracellular enzymes that degrade coal. Therefore, when comparing the two enzymatic methods, results show that the process of using extracellular lignin degrading enzymes, such as laccase and manganese peroxidase, appears to be a more efficient method of decomposing bituminous coal.

  2. Data base for the analysis of compositional characteristics of coal seams and macerals. Final report. Part 2. A multivariate study of the interrelationships among selected variables of the organic fraction of samples of United States' coals

    SciTech Connect (OSTI)

    Gerencher, J.J. Jr.

    1983-01-01T23:59:59.000Z

    Multivariate statistical techniques have been applied to study interrelationships among 12 variables within a set of 277 coals representing whole-seam channel, column, and core samples obtained from each of the 6 coal provinces of the United States, and varying in rank from lignite through anthracite. The data are maintained in computerized data base at The Pennsylvania State University Coal Research Section. The variables selected are components of the elemental analysis (carbon, oxygen, organic sulfur, hydrogen, and nitrogen), selected components of the proximate analysis (volatile matter and moisture), calorific value, reflectance of vitrinite, and the relative proportions of the 3 maceral groups (total vitrinite, inertinite, and liptinite group macerals). Faactor analyses performed on the entire data set and on subsets separated on the basis of rank, geographic location, and by cluster analysis indicated that rank is the most important factor in determining the amount of variation of each data set. The rank-dependent variables for the entire data set are carbon, reflectance, oxygen, volatile matter, calorific value, and moisture. The maceral groups account for the next greatest source of variation. Organic sulfur is independent of the first 2 factors and is the third most important source of variation. Cluster analyses indicated that the most significant partitioning produces 4 groups which are differentiated primarily on the basis of rank, maceral composition, and organic sulfur content. Factor analyses of the individual groups provide insights into the coalification processes of these more homogeneous coal associations.

  3. Role of microbial iron reduction in the dissolution of iron hydroxysulfate minerals - article no. G01012

    SciTech Connect (OSTI)

    Jones, E.J.P.; Nadeau, T.L.; Voytek, M.A.; Landa, E.R. [US Geological Survey, Reston, VA (United States)

    2006-03-28T23:59:59.000Z

    Reduction of structural sulfate in the iron-hydroxysulfate mineral jarosite by sulfate-reducing bacteria has previously been demonstrated. The primary objective of this work was to evaluate the potential for anaerobic dissolution of the iron-hydroxysulfate minerals jarosite and schwertmannite at neutral pH by iron-reducing bacteria. Mineral dissolution was tested using a long-term cultivar, Geobacter metallireducens strain GS-15, and a fresh isolate Geobacter sp. strain ENN1, previously undescribed. ENN1 was isolated from the discharge site of Shadle Mine, in the southern anthracite coalfield of Pennsylvania, where schwertmannite was the predominant iron-hydroxysulfate mineral. When jarosite from Elizabeth Mine (Vermont) was provided as the sole terminal electron acceptor, resting cells of both G. metallireducens and ENN1 were able to reduce structural Fe(III), releasing Fe{sup +2}, SO{sub 4}{sup -2}, and K{sup +} ions. A lithified jarosite sample from Utah was more resistant to microbial attack, but slow release of Fe{sup +2} was observed. Neither bacterium released Fe{sup +2} from poorly crystalline synthetic schwertmannite. Our results indicate that exposure of jarosite to iron-reducing conditions at neutral pH is likely to promote the mobility of hazardous constituents and should therefore be considered in evaluating waste disposal and/or reclamation options involving jarosite-bearing materials.

  4. Technical support to the Solvent Refined Coal (SRC) demonstration projects: assessment of current research and development

    SciTech Connect (OSTI)

    Edwards, M.S.; Rodgers, B.R.; Brown, C.H.; Carlson, P.K.; Gambill, W.R.; Gilliam, T.M.; Holmes, J.M.; Krishnan, R.P.; Parsly, L.F.

    1980-12-01T23:59:59.000Z

    A program to demonstrate Solvent Refined Coal (SRC) technology has been initiated by the US Department of Energy (DOE) in partnership with two industrial groups. Project management responsibility has been assigned to the Oak Ridge Operations Office (ORO) of DOE. ORO requested that the Oak Ridge National Laboratory assess current research and development (R and D) activities and develop recommendations for those activities that might contribute to successful completion of the SRC demonstration plant projects. The objectives of this final report are to discuss in detail the problem areas in SRC; to discuss the current and planned R and D investigations relevant to the problems identified; and to suggest appropriate R and D activities in support of designs for the SRC demonstration plants. Four types of R and D activities are suggested: continuation of present and planned activities; coordination of activities and results, present and proposed; extension/redirection of activities not involving major equipment purchase or modifications; and new activities. Important examples of the first type of activity include continuation of fired heater, slurry rheology, and slurry mixing studies at Ft. Lewis. Among the second type of activity, coordination of data acquisition and interpretation is recommended in the areas of heat transfer, vapor/liquid equilibria, and physical properties. Principal examples of recommendations for extension/redirection include screening studies at laboratory scale on the use of carbonaceous precoat (e.g., anthracite) infiltration, and 15- to 30-day continuous tests of the Texaco gasifier at the Texaco Montebello facility (using SRC residues).

  5. Feasible experimental study on the utilization of a 300 MW CFB boiler desulfurizating bottom ash for construction applications

    SciTech Connect (OSTI)

    Lu, X.F.; Amano, R.S. [University of Wisconsin, Milwaukee, WI (United States). Dept. of Mechanical Engineering

    2006-12-15T23:59:59.000Z

    CFB boiler ash cannot be used as a cement replacement in concrete due to its unacceptably high sulfur content. The disposal in landfills has been the most common means of handling ash in circulating fluidized bed boiler power plants. However for a 300 MW CFB boiler power plant, there will be 600,000 tons of ash discharged per year and will result in great volumes and disposal cost of ash byproduct. It was very necessary to solve the utilization of CFB ash and to decrease the disposal cost of CFB ash. The feasible experimental study results on the utilization of the bottom ashes of a 300 MW CFB boiler in Baima power plant in China were reported in this paper. The bottom ashes used for test came from the discharged bottom ashes in a 100 MW CFB boiler in which the anthracite and limestone designed for the 300 MW CFB project was burned. The results of this study showed that the bottom ash could be used for cementitious material, road concrete, and road base material. The masonry cements, road concrete with 30 MPa compressive strength and 4.0 MPa flexural strength, and the road base material used for base courses of the expressway, the main road and the minor lane were all prepared with milled CFB bottom ashes in the lab. The better methods of utilization of the bottom ashes were discussed in this paper.

  6. Characterizing and modeling combustion of mild-gasification chars in pressurized fluidized beds

    SciTech Connect (OSTI)

    Daw, C.S.

    1993-03-01T23:59:59.000Z

    Performance estimates for the UCC2, IGTP1, and IGTP2 chars were made for a typical utility PFBC boiler having nominal characteristics similar to those of the American Electric Power 75 MW(e) Tidd PFBC demonstration facility. Table 2 summarizes the assumed boiler operating conditions input to the PFBC simulation code. Input fuel parameters for the chars and reference fuels were determined from their standard ASTM analyses (Table 1) and the results of the bench-scale characterization tests at B&W`s Alliance Research Center. The required characterization information for the reference fuels was available from the B&W data base, and the combustion reactivity information for the mild-gasification chars was generated in the pressurized bench-scale reactor as described earlier. Note that the combustion reactivity parameters for Beulah lignite are those previously measured at low-pressure conditions. It was necessary to use the previous values as the new parameters could not be accurately measured in the pressurized bench-scale facility. Based on very limited measurements of particle size attrition in paste-type feed systems, it was assumed that all of the fuels (including the chars) would have a very small (essentially negligible) degree of attrition in the feed system. Char devolatilization parameters were assumed to be equal to those of anthracite because of the very low levels of volatiles present in UCC2, IGTP1, and IGTP2. Major fuel input parameters and higher heating values are summarized in Table 3.

  7. Characterizing and modeling combustion of mild-gasification chars in pressurized fluidized beds

    SciTech Connect (OSTI)

    Daw, C.S.

    1993-01-01T23:59:59.000Z

    Performance estimates for the UCC2, IGTP1, and IGTP2 chars were made for a typical utility PFBC boiler having nominal characteristics similar to those of the American Electric Power 75 MW(e) Tidd PFBC demonstration facility. Table 2 summarizes the assumed boiler operating conditions input to the PFBC simulation code. Input fuel parameters for the chars and reference fuels were determined from their standard ASTM analyses (Table 1) and the results of the bench-scale characterization tests at B W's Alliance Research Center. The required characterization information for the reference fuels was available from the B W data base, and the combustion reactivity information for the mild-gasification chars was generated in the pressurized bench-scale reactor as described earlier. Note that the combustion reactivity parameters for Beulah lignite are those previously measured at low-pressure conditions. It was necessary to use the previous values as the new parameters could not be accurately measured in the pressurized bench-scale facility. Based on very limited measurements of particle size attrition in paste-type feed systems, it was assumed that all of the fuels (including the chars) would have a very small (essentially negligible) degree of attrition in the feed system. Char devolatilization parameters were assumed to be equal to those of anthracite because of the very low levels of volatiles present in UCC2, IGTP1, and IGTP2. Major fuel input parameters and higher heating values are summarized in Table 3.

  8. Far- and mid-infrared spectroscopy of complex organic matter of astrochemical interest: coal, heavy petroleum fractions, and asphaltenes

    E-Print Network [OSTI]

    Cataldo, F; Manchado, A

    2012-01-01T23:59:59.000Z

    The coexistence of a large variety of molecular species (i.e., aromatic, cycloaliphatic and aliphatic) in several astrophysical environments suggests that unidentified IR emission (UIE) occurs from small solid particles containing a mix of aromatic and aliphatic structures (e.g., coal, petroleum, etc.), renewing the astronomical interest on this type of materials. A series of heavy petroleum fractions namely DAE, RAE, BQ-1, and asphaltenes derived from BQ-1 were used together with anthracite coal and bitumen as model compounds in matching the band pattern of the emission features of proto-planetary nebulae (PPNe). All the model materials were examined in the mid-infrared (2.5-16.7 um) and for the first time in the far-infrared (16.7-200 um), and the IR bands were compared with the UIE from PPNe. The best match of the PPNe band pattern is offered by the BQ-1 heavy aromatic oil fraction and by its asphaltenes fraction. Particularly interesting is the ability of BQ-1 to match the band pattern of the aromatic-ali...

  9. Prospects for coal briquettes as a substitute fuel for wood and charcoal in US Agency for International Development Assisted countries

    SciTech Connect (OSTI)

    Perlack, R.D.; Stevenson, G.G.; Shelton, R.B.

    1986-02-01T23:59:59.000Z

    Fuelwood shortages and potential shortages are widespread throughout the developing world, and are becoming increasingly more prevalent because of the clearing of land for subsistence and plantation agriculture, excessive and inefficient commercial timber harvesting for domestic and export construction, and charcoal production to meet rising urban demands. Further, the environmental and socioeconomic consequences of the resulting deforestation are both pervasive and complex. This report focuses on the substitution of coal briquettes for fuelwood. Although substantial adverse health effects could be expected from burning non-anthracite coal or coal briquettes, a well-developed technique, carbonization, exists to convert coal to a safer form for combustion. The costs associated with briquetting and carbonizing coal indicate that ''smokeless'' coal briquettes can be produced at costs competitive with fuelwood and charcoal. The US Agency for International Development (USAID) is working on implementing this energy option in Haiti and Pakistan by (1) evaluating resources, (2) assessing markets, (3) analyzing technologies, (4) studying government policy and planning, and (5) packaging the idea for the private sector to implement. 26 refs., 2 figs., 12 tabs.

  10. Fundamental investigations of underground coal gasification. Annual report Mar 82-Mar 83

    SciTech Connect (OSTI)

    Dunn, R.D.

    1983-03-01T23:59:59.000Z

    Coal deposits in the Appalachian and Midwest Coal Regions consist primarily of thin relatively deep seams of swelling bituminous coal, but little scientific effort in the United States has been directed toward underground coal gasification in these important industrial areas. In Europe, however, major work is under way on underground coal gasification in thin, deep seams of swelling coal. The principal investigator and a graduate student are participating in field tests in Belgium and supporting laboratory experiments in Germany. Mathematical models are being developed to interpret these experimental data, and a better understanding of the underground coal gasification process is emerging. This understanding is essential for evaluating potential problems, for devising solutions to such problems and for designing field tests.

  11. CONSOL Energy invests in West Virginia CTL plant

    SciTech Connect (OSTI)

    NONE

    2008-10-15T23:59:59.000Z

    Working with Synthesis Energy Systems (SES), America's leading bituminous coal producer assists with the engineering design package for a coal gasification and liquefaction plant to be located near Benwood in West Virginia. Coal will be converted to syngas using SES's proprietary U-GAS technology. The syngas is expected to be used to produce about 720,000 metric tons per year of methanol. The U-GAS technology is licensed from the Gas Technology Institute (GTI). The article explains how the GTI gasification process works. It is based on a surge-stage fluidised bed for production of low-to-medium calorific value synthesis gas from a variety of feedstocks, including coal. 2 figs.

  12. International energy indicators

    SciTech Connect (OSTI)

    Bauer, E.K. (ed.)

    1980-09-01T23:59:59.000Z

    Data are compiled and graphs are presented for Iran: Crude Oil Capacity, Production and Shut-in, 1974-1980; Saudi Arabia: Crude Oil Capacity, Production and Shut-in, 1974-1980; OPEC (Ex-Iran and Saudi Arabia): Capacity, Production and Shut-in, 1974-1980; Non-OPEC Free World and US Production of Crude Oil, 1973-1980; Oil Stocks: Free World, US, Japan and Europe (landed), 1973-1980; Petroleum Consumption by Industrial Countries, 1973-1980; USSR Crude Oil Production, 1974-1980; Free World and US Nuclear Generation Capacity, 1973-1980; US Imports of Crude Oil and Products, 1973-1980; Landed Cost of Saudi Crude in Current and 1974 Dollars; US Trade in Bituminous Coal, 1973-1980; Summary of US Merchandise Trade, 1976-1980; and Energy/GNP Ratio.

  13. Petrographic characterization of Kentucky coal. Final report. Part III. Petrographic characterization of the Upper Elkhorn No. 2 coal zone of eastern Kentucky

    SciTech Connect (OSTI)

    Raione, R.P.; Hower, J.C.

    1984-01-01T23:59:59.000Z

    This report presents the study of the Upper Elkhorn No. 2 coal zone in the Big Sandy Reserve District and the surrounding area of eastern Kentucky. The seams were analyzed using megascopic and microscopic petrography and chemical methods. The Upper Elkhorn No. 2 consists predominantly of clarain. A fair degree of correlation of fusain bands and clay partings between data sites is apparent. Microscopically, the vitrinite group of macerals are dominant. A rank increase from high volatile B to high volatile A bituminous to the southwest was noted. Pseudovitrinite is associated negatively with vitrinite and has a higher reflectance and microhardness than vitrinite. Both factors may indicate source material and/or environmental differences in the respective origins of the maceral. High inertinite and lipinite areas, low ash and sulfur contents, and the distribution of thin coals may be indicative of paleotopographic highs. 62 references, 26 figures, 8 tables.

  14. Intra- and inter-unit variation in fly ash petrography: Examples from a western Kentucky power station

    SciTech Connect (OSTI)

    Hower, J.C.; Rathbone, R.F. [Univ. of Kentucky, Lexington, KY (United States). Center for Applied Energy Research; Goodman, J. [Prestonburg High School, KY (United States)

    1998-12-31T23:59:59.000Z

    Fly ash was collected from eight mechanical and ten baghouse hoppers at each of twin 150-MW wall-fired units in a western Kentucky power station. The fuel burned at that time was a blend of low-sulfur, high volatile bituminous Central Appalachian coals. The baghouse ash showed less variation between units than the mechanical units. The coarser mechanical fly ash showed significant differences in the amount of total carbon and in the ratio of isotropic coke to both total carbons and total coke; the latter excluding inertinite and other unburned, uncoked coal. There was no significant variation in ratios of inorganic fly ash constituents. The inter-unit differences in the amount and forms of mechanical fly ash carbon appear to be related to differences in pulverizer efficiency, leading to greater amounts of coarse coal, therefore unburned carbon, in one of the units.

  15. POC-SCALE TESTING OF AN ADVANCED FINE COAL DEWATERING EQUIPMENT/TECHNIQUE

    SciTech Connect (OSTI)

    B.K. PAREKH; D. TAO; J.G. GROPPO

    1998-02-03T23:59:59.000Z

    The main objective of the proposed program is to evaluate a novel surface modification technique, which utilizes the synergistic effect of metal ions-surfactant combination, for dewatering of ultra-fine clean coal on a proof-of-concept scale of 1 to 2 tph. The novel surface modification technique developed at the UKCAER will be evaluated using vacuum, centrifuge, and hyperbaric filtration equipment. Dewatering tests will be conducted using the fine clean-coal froth produced by the column flotation units at the Powell Mountain Coal Company, Mayflower Preparation Plant in St. Charles, Virginia. The POC-scale studies will be conducted on two different types of clean coal, namely, high-sulfur and low-sulfur clean coal. The Mayflower Plant processes coals from five different seams, thus the dewatering studies results could be generalized for most of the bituminous coals.

  16. KINETIC STUDY OF COAL AND BIOMASS CO-PYROLYSIS USING THERMOGRAVIMETRY

    SciTech Connect (OSTI)

    Wang, Ping; Hedges, Sheila; Chaudharib, Kiran; Turtonb, Richard

    2013-10-29T23:59:59.000Z

    The objectives of this study are to investigate thermal behavior of coal and biomass blends in inert gas environment at low heating rates and to develop a simplified kinetic model using model fitting techniques based on TGA experimental data. Differences in thermal behavior and reactivity in co-pyrolysis of Powder River Basin (PRB) sub-bituminous coal and pelletized southern yellow pine wood sawdust blends at low heating rates are observed. Coal/wood blends have higher reactivity compared to coal alone in the lower temperature due to the high volatile matter content of wood. As heating rates increase, weight loss rates increase. The experiment data obtained from TGA has a better fit with proposed two step first order reactions model compared single first order reaction model.

  17. Recycled brake linings as partial aggregate substitute in asphalt paving. Construction and final report. Report for July 1992-August 1996

    SciTech Connect (OSTI)

    Miller, P.A.; Sukley, R.

    1996-09-01T23:59:59.000Z

    The purpose of this project was to evaluate the performance of asphalt containing various percentages of brake lining as an aggregate, and compare its performance to that of normal asphalt containing natural aggregate. This project is an effort to explore alternate ways to use waste product. Four test section of FB-2 Modified mix containing brake lining materials were placed in July 1992 along with one control section on SR 3022 in Mercer county. To date all sections are performing satisfactory, and Brake linings should be recommended as a viable partial replacement of aggregate in bituminous materials. This study only considered the performance of only off-spec brake linings, therefore, any performance data or enviromental effects of placement of used brake material should be addressed.

  18. Nigeria to step up tar sands activity

    SciTech Connect (OSTI)

    Not Available

    1987-03-01T23:59:59.000Z

    The Nigerian government has directed its Ministry of Mines, Power and Steel to assume responsibility for the exploration and exploitation of tar sands deposits in Bendel, Ondo and Oyo States. The directive resulted from a survey report by the University of Ife's geological consultancy unit on bituminous sand deposits in the area. The statement said the government was satisfied that there were large commercial quantities of the sands in the three states. The survey had reported that Nigeria could recover between 31 and 40 billion barrels of heavy crude from the tar sand deposits. Exploration for hydrocarbons is currently going on in Anambra and Lake Chad basins as well as the Benue Trough. Apart from the Nigerian National Petroleum Corporation, Shell Petroleum and Gulf Oil have begun exploration activities in the Ondo area. Meanwhile, Nigeria has had to import heavy crude from Venezuela, for processing at the Kaduna refinery.

  19. Enhanced mercury oxidation

    SciTech Connect (OSTI)

    Gretta, W.J.; Wu, S.; Kikkawa, H. [Hitachi Power Systems America, Basting Ridge, NJ (United States)

    2009-06-15T23:59:59.000Z

    A new catalyst offers a new way to enhance mercury control from bituminous coal-fired power plants. Hitachi has developed an SCR catalyst which satisfies high Hg{sup 0} oxidation and low SO{sub 2} oxidation requirements under high temperatures (716 to 770 F). This triple action catalysts, TRAC can significantly enhance mercury oxidation and reduce or eliminate the need for additional mercury control measures such as activated carbon injection. After laboratory testing, pilot-scale tests confirmed an activity of 1.4-1.7 times higher than that of conventional SCR catalyst. The new catalyst has been successfully applied in a commercial PRB-fired boiler without the need for halogens to be added to the fuel feed or flue gas. 2 figs.

  20. METHANE de-NOX for Utility PC Boilers

    SciTech Connect (OSTI)

    Joseph Rabovitser; Serguei Nester; Stan Wohadlo

    2005-09-30T23:59:59.000Z

    Large-scale combustion tests with caking bituminous coal has stopped. This stoppage has come about due to limitations in current funding available to continue large scale research and development activities at Riley Power's Commercial Burner Test Facility (CBTF) of the PC Preheat technology. The CBTF was secured and decommissioned in the previous quarter; work this quarter work completed the securing the proper disposition of all PC Preheat experimental equipment at the PSCF and CBTF and completing negotiations with AES Westover (a power plant in Johnson City, New York) to accept 130 tons of residual PRB test coal in storage. The coal transport to Westover occurred at the end of August. GTI was granted a no-cost time extension through September 2005; immediate efforts are focused on completing a draft final report, which is due in October 31, 2005 and the final report in December.

  1. Studies of coupled chemical and catalytic coal conversion methods. Ninth quarterly report, October, November, December 1989

    SciTech Connect (OSTI)

    Stock, L.M.

    1989-12-31T23:59:59.000Z

    A new base catalyzed C-alkylation reaction that employs a mixture of n-butyllithium and potassium t-butoxide in refluxing heptane to produce coal anions that are subsequently treated with n-alkyl halides at 0{degree}C has been developed. Almost quantitative pyridine solubilization was achieved by C-octylation of a Lower Kittanning coal, PSOC 1197. C-Octylation was less successful for the solubilization of bituminous Illinois No. 6 coal, APCSP 3, and subbituminous Wyodak coal, APCSP 2, which gave 35 and 33% soluble material, respectively. Their O-methyl derivatives yielded 43 and 20% soluble material in the same reaction. The observations are in accord with the concept of Ouchi and his associates that higher rank coals, although more aromatic in character, have a lower degree of polymerization than low rank coals. Relatively mild chemical reactions, such as Calkylation, that lead to modest changes in molecular dimensions, can disrupt intermolecular forces and accomplish solubilization.

  2. Studies of coupled chemical and catalytic coal conversion methods

    SciTech Connect (OSTI)

    Stock, L.M.

    1989-01-01T23:59:59.000Z

    A new base catalyzed C-alkylation reaction that employs a mixture of n-butyllithium and potassium t-butoxide in refluxing heptane to produce coal anions that are subsequently treated with n-alkyl halides at 0{degree}C has been developed. Almost quantitative pyridine solubilization was achieved by C-octylation of a Lower Kittanning coal, PSOC 1197. C-Octylation was less successful for the solubilization of bituminous Illinois No. 6 coal, APCSP 3, and subbituminous Wyodak coal, APCSP 2, which gave 35 and 33% soluble material, respectively. Their O-methyl derivatives yielded 43 and 20% soluble material in the same reaction. The observations are in accord with the concept of Ouchi and his associates that higher rank coals, although more aromatic in character, have a lower degree of polymerization than low rank coals. Relatively mild chemical reactions, such as Calkylation, that lead to modest changes in molecular dimensions, can disrupt intermolecular forces and accomplish solubilization.

  3. Investigation of bonding mechanism of coking on semi-coke from lignite with pitch and tar

    SciTech Connect (OSTI)

    Vedat Arslan [Dokuz Eylul University, Izmir (Turkey). Engineering Faculty

    2006-10-15T23:59:59.000Z

    In coking, the bonding ability of inert macerals by reactive macerals is dependent on various parameters and also is related to the wettability of the inert macerals. In this study, the effect of carbonization temperature on the wettability of semi-cokes produced at various temperatures has been investigated. Soma and Yatagan semicokes represent inert macerals, and pitch was used as a reactive structure in the experiments. The briquetted pitch blocks were located on the semi-cokes and heated from the softening temperature of pitch (60{sup o}C) to 140{sup o}C to observe the wettability. In addition, liquid tar was also used to determine the wettability of semi-cokes. From the standpoint of wettability, the temperature of 900{sup o}C was determined to be the critical point for coke produced from sub-bituminous coals. 15 refs., 6 figs., 2 tabs.

  4. Characterization of air toxics from a laboratory coal-fired combustor

    SciTech Connect (OSTI)

    NONE

    1995-04-03T23:59:59.000Z

    Emissions of hazardous air pollutants from coal combustion were studied in a laboratory-scale combustion facility, with emphasis on fine particles in three size ranges of less than 7.5 {mu}m diameter. Vapors were also measured. Substances under study included organic compounds, anions, elements, and radionuclides. Fly ash was generated by firing a bituminous coal in a combuster for 40 h at each of two coal feed rates. Flue gas was sampled under two conditions. Results for organic compounds, anions, and elements show a dependence on particle size consistent with published power plant data. Accumulation of material onto surface layers was inferred from differences in chemical composition between the plume simulating dilution sampler and hot flue samples. Extracts of organic particulate material were fractionated into different polarity fractions and analyzed by GC/MS. In Phase II, these laboratory results will be compared to emissions from a full-scale power plant burning the same coal.

  5. Encoal mild coal gasification project: Final design modifications report

    SciTech Connect (OSTI)

    NONE

    1997-07-01T23:59:59.000Z

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

  6. 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.

    1981-06-01T23:59:59.000Z

    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.

  7. LIMB Demonstration Project Extension

    SciTech Connect (OSTI)

    Not Available

    1988-09-15T23:59:59.000Z

    The basic goal of the Limestone Injection Multistage Burner (LIMB) demonstration is to extend LIMB technology development to a full-scale application on a representative wall-fired utility boiler. The successful retrofit of LIMB to an existing boiler is expected to demonstrate that (a) reductions of 50 percent or greater in SO and NO emissions can be achieved at a fraction of the cost of add-on FGD systems, (b) boiler reliability, operability, and steam production can be maintained at levels existing prior to LIMB retrofit, and (c) technical difficulties attributable to LIMB operation, such as additional slagging and fouling, changes in ash disposal requirements, and an increased particulate load, can be resolved in a cost-effective manner. The primary fuel to be used will be an Ohio bituminous coal having a nominal sulfur content of 3 percent or greater.

  8. LIMB Demonstration Project Extension. Quarterly report no. 3, November, December 1987--January 1988

    SciTech Connect (OSTI)

    Not Available

    1988-03-15T23:59:59.000Z

    The basic goal of the Limestone Injection Multistage Burner (LIMB) demonstration is to extend LIMB technology development to a full-scale application on a representative wall-fired utility boiler. The successful retrofit of LIMB to an existing boiler is expected to demonstrate that (a) reductions of 50 percent or greater in SO{sub x} and NO{sub x} emissions can be achieved at a fraction of the cost of add-on FGD systems, (b) boiler reliability, operability, and steam production can be maintained at levels existing prior to LIMB retrofit, and (c) technical difficulties attributable to LIMB operation, such as additional slagging and fouling, changes in ash disposal requirements, and an increased particulate load, can be resolved in a cost-effective manner. The primary fuel to be used will be an Ohio bituminous coal having a nominal sulfur content of 3 percent or greater.

  9. LIMB Demonstration Project Extension. Quarterly report no. 10, August, September, and October, 1989

    SciTech Connect (OSTI)

    Not Available

    1989-11-15T23:59:59.000Z

    The basic goal of the Limestone Injection Mitigation Burner (LIMB) demonstration is to extend LIMB technology development to a full- scale application on a representative wall-fired utility boiler. The successful retrofit of LIMB to an existing boiler is expected to demonstrate that (a) reductions of 50 percent or greater in SO{sub x} and NO{sub x} emissions can be achieved at a fraction of the cost of add-on FGD systems, (b) boiler reliability, operability, and steam production can be maintained at levels existing prior to LIMB retrofit, and (c) technical difficulties attributable to LIMB operation, such as additional slagging and fouling, changes in ash disposal requirements, and an increased particulate load, can be resolved in a cost-effective manner. The primary fuel to be used will be an Ohio bituminous coal having a nominal sulfur content of 3 percent or greater.

  10. LIMB Demonstration Project Extension

    SciTech Connect (OSTI)

    Not Available

    1989-06-15T23:59:59.000Z

    The basic goal of the Limestone Injection Multistage Burner (LIMB) demonstration is to extend LIMB technology development to a full- scale application on a representative wall-fired utility boiler. The successful retrofit of LIMB to an existing boiler is expected to demonstrate that (a) reductions of 50 percent or greater in SO{sub x} and NO{sub x} emissions can be achieved at a fraction of the cost of add-on FGD systems, (b) boiler reliability, operability, and steam production can be maintained at levels existing prior to LIMB retrofit, and (c) technical difficulties attributable to LIMB operation, such as additional slagging and fouling, changes in ash disposal requirements, and an increased particulate load, can be resolved in a cost-effective manner. The primary fuel to be used will be an Ohio bituminous coal having a nominal sulfur content of 3 percent or greater.

  11. LIMB Demonstration Project Extension

    SciTech Connect (OSTI)

    Not Available

    1989-11-15T23:59:59.000Z

    The basic goal of the Limestone Injection Mitigation Burner (LIMB) demonstration is to extend LIMB technology development to a full- scale application on a representative wall-fired utility boiler. The successful retrofit of LIMB to an existing boiler is expected to demonstrate that (a) reductions of 50 percent or greater in SO{sub x} and NO{sub x} emissions can be achieved at a fraction of the cost of add-on FGD systems, (b) boiler reliability, operability, and steam production can be maintained at levels existing prior to LIMB retrofit, and (c) technical difficulties attributable to LIMB operation, such as additional slagging and fouling, changes in ash disposal requirements, and an increased particulate load, can be resolved in a cost-effective manner. The primary fuel to be used will be an Ohio bituminous coal having a nominal sulfur content of 3 percent or greater.

  12. LIMB Demonstration Project Extension. Quarterly report no. 8, February, March, and April, 1989

    SciTech Connect (OSTI)

    Not Available

    1989-06-15T23:59:59.000Z

    The basic goal of the Limestone Injection Multistage Burner (LIMB) demonstration is to extend LIMB technology development to a full- scale application on a representative wall-fired utility boiler. The successful retrofit of LIMB to an existing boiler is expected to demonstrate that (a) reductions of 50 percent or greater in SO{sub x} and NO{sub x} emissions can be achieved at a fraction of the cost of add-on FGD systems, (b) boiler reliability, operability, and steam production can be maintained at levels existing prior to LIMB retrofit, and (c) technical difficulties attributable to LIMB operation, such as additional slagging and fouling, changes in ash disposal requirements, and an increased particulate load, can be resolved in a cost-effective manner. The primary fuel to be used will be an Ohio bituminous coal having a nominal sulfur content of 3 percent or greater.

  13. LIMB Demonstration Project Extension

    SciTech Connect (OSTI)

    Not Available

    1988-12-15T23:59:59.000Z

    The basic goal of the Limestone Injection Multistage Burner (LIMB) demonstration is to extend LIMB technology development to a full- scale application on a representative wall-fired utility boiler. The successful retrofit of LIMB to an existing boiler is expected to demonstrate that (a) reductions of 50 percent or greater in SO{sub x} and NO{sub x} emissions can be achieved at a fraction of the cost of add-on FGD systems, (b) boiler reliability, operability, and steam production can be maintained at levels existing prior to LIMB retrofit, and (c) technical difficulties attributable to LIMB operation, such as additional slagging and fouling, changes in ash disposal requirements, and an increased particulate load, can be resolved in a cost-effective manner. The primary fuel to be used will be an Ohio bituminous coal having a nominal sulfur content of 3 percent or greater.

  14. LIMB Demonstration Project Extension. Quarterly report No. 6, August--October, 1988

    SciTech Connect (OSTI)

    Not Available

    1988-12-15T23:59:59.000Z

    The basic goal of the Limestone Injection Multistage Burner (LIMB) demonstration is to extend LIMB technology development to a full- scale application on a representative wall-fired utility boiler. The successful retrofit of LIMB to an existing boiler is expected to demonstrate that (a) reductions of 50 percent or greater in SO{sub x} and NO{sub x} emissions can be achieved at a fraction of the cost of add-on FGD systems, (b) boiler reliability, operability, and steam production can be maintained at levels existing prior to LIMB retrofit, and (c) technical difficulties attributable to LIMB operation, such as additional slagging and fouling, changes in ash disposal requirements, and an increased particulate load, can be resolved in a cost-effective manner. The primary fuel to be used will be an Ohio bituminous coal having a nominal sulfur content of 3 percent or greater.

  15. LIMB Demonstration Project Extension

    SciTech Connect (OSTI)

    Not Available

    1988-03-15T23:59:59.000Z

    The basic goal of the Limestone Injection Multistage Burner (LIMB) demonstration is to extend LIMB technology development to a full-scale application on a representative wall-fired utility boiler. The successful retrofit of LIMB to an existing boiler is expected to demonstrate that (a) reductions of 50 percent or greater in SO{sub x} and NO{sub x} emissions can be achieved at a fraction of the cost of add-on FGD systems, (b) boiler reliability, operability, and steam production can be maintained at levels existing prior to LIMB retrofit, and (c) technical difficulties attributable to LIMB operation, such as additional slagging and fouling, changes in ash disposal requirements, and an increased particulate load, can be resolved in a cost-effective manner. The primary fuel to be used will be an Ohio bituminous coal having a nominal sulfur content of 3 percent or greater.

  16. LIMB Demonstration Project Extension

    SciTech Connect (OSTI)

    Not Available

    1989-03-15T23:59:59.000Z

    The basic goal of the Limestone Injection Multistage Burner (LIMB) demonstration is to extend LIMB technology development to a full- scale application on a representative wall-fired utility boiler. The successful retrofit of LIMB to an existing boiler is expected to demonstrate that (a) reductions of 50 percent or greater in SO{sub x} and NO{sub x} emissions can be achieved at a fraction of the cost of add-on FGD systems, (b) boiler reliability, operability, and steam production can be maintained at levels existing prior to LIMB retrofit, and (c) technical difficulties attributable to LIMB operation, such as additional slagging and fouling, changes in ash disposal requirements, and an increased particulate load, can be resolved in a cost-effective manner. The primary fuel to be used will be an Ohio bituminous coal having a nominal sulfur content of 3 percent or greater.

  17. LIMB Demonstration Project Extension. Quarterly report no. 5, May, June and July 1988

    SciTech Connect (OSTI)

    Not Available

    1988-09-15T23:59:59.000Z

    The basic goal of the Limestone Injection Multistage Burner (LIMB) demonstration is to extend LIMB technology development to a full-scale application on a representative wall-fired utility boiler. The successful retrofit of LIMB to an existing boiler is expected to demonstrate that (a) reductions of 50 percent or greater in SO and NO emissions can be achieved at a fraction of the cost of add-on FGD systems, (b) boiler reliability, operability, and steam production can be maintained at levels existing prior to LIMB retrofit, and (c) technical difficulties attributable to LIMB operation, such as additional slagging and fouling, changes in ash disposal requirements, and an increased particulate load, can be resolved in a cost-effective manner. The primary fuel to be used will be an Ohio bituminous coal having a nominal sulfur content of 3 percent or greater.

  18. LIMB Demonstration Project Extension. Quarterly report No. 7, November and December, 1988, and January, 1989

    SciTech Connect (OSTI)

    Not Available

    1989-03-15T23:59:59.000Z

    The basic goal of the Limestone Injection Multistage Burner (LIMB) demonstration is to extend LIMB technology development to a full- scale application on a representative wall-fired utility boiler. The successful retrofit of LIMB to an existing boiler is expected to demonstrate that (a) reductions of 50 percent or greater in SO{sub x} and NO{sub x} emissions can be achieved at a fraction of the cost of add-on FGD systems, (b) boiler reliability, operability, and steam production can be maintained at levels existing prior to LIMB retrofit, and (c) technical difficulties attributable to LIMB operation, such as additional slagging and fouling, changes in ash disposal requirements, and an increased particulate load, can be resolved in a cost-effective manner. The primary fuel to be used will be an Ohio bituminous coal having a nominal sulfur content of 3 percent or greater.

  19. Nucla circulating atmospheric fluidized bed demonstration project. Final report

    SciTech Connect (OSTI)

    Not Available

    1991-10-01T23:59:59.000Z

    Colorado-Ute Electric Association began a study to evaluate options for upgrading and extending the life of its Nucla power station in 1982. Located in southwestern Colorado near the town of Nucla, this station was commissioned in 1959 with a local bituminous coal as its design fuel for three identical stoker-fired units, each rated at 12.6 MW(e). Poor station efficiency, high fuel costs, and spiraling boiler maintenance costs forced the Nucla Station into low priority in the CUEA dispatch order as early as 1981. Among the options CUEA considered was to serve as a host utility to demonstrate Atmospheric Fluidized Bed Combustion (AFBC) technology. The anticipated environmental benefits and apparent attractive economics of a circulating AFBC led to Colorado-Ute`s decision to proceed with the design and construction of a demonstration project in 1984 at the Nucla facility.

  20. Nucla circulating atmospheric fluidized bed demonstration project

    SciTech Connect (OSTI)

    Keith, Raymond E.

    1991-10-01T23:59:59.000Z

    Colorado-Ute Electric Association began a study to evaluate options for upgrading and extending the life of its Nucla power station in 1982. Located in southwestern Colorado near the town of Nucla, this station was commissioned in 1959 with a local bituminous coal as its design fuel for three identical stoker-fired units, each rated at 12.6 MW(e). Poor station efficiency, high fuel costs, and spiraling boiler maintenance costs forced the Nucla Station into low priority in the CUEA dispatch order as early as 1981. Among the options CUEA considered was to serve as a host utility to demonstrate Atmospheric Fluidized Bed Combustion (AFBC) technology. The anticipated environmental benefits and apparent attractive economics of a circulating AFBC led to Colorado-Ute's decision to proceed with the design and construction of a demonstration project in 1984 at the Nucla facility.

  1. Current status of design and construction of ENCOAL Mild Gasification Plant

    SciTech Connect (OSTI)

    Frederick, J.P.; Siddoway, M.A.; Coolidge, D.W.

    1992-01-01T23:59:59.000Z

    The ENCOAL project is demonstrating for the first time the integrated operation of several process steps: a. Coal drying on a rotary grate using convective heatin; b. Coal devolatilization on a rotary grate using convective heating; c. Hot particulate removal with cyclones integral solids cooling; and deactivation-passivation; e. Combustors operating on low-Btu gas from internal streams; f. Solids stabilization for storage and shipment; g. Computer control and optimization of a mild coal gasification process. The product fuels are expected to be used economically in commercial boilers and furnaces and to significantly reduce sulfur emissions at industrial and utility facilities currently burning high sulfur bituminous fuels or fuel oils thereby reducing acid rain-causing pollutants. The design and construction of the ENCOAL demonstration plan was done on a fast track basis, that is, these activities were extensively overlapped.

  2. Current status of design and construction of ENCOAL Mild Gasification Plant

    SciTech Connect (OSTI)

    Frederick, J.P.; Siddoway, M.A.; Coolidge, D.W.

    1992-11-01T23:59:59.000Z

    The ENCOAL project is demonstrating for the first time the integrated operation of several process steps: a. Coal drying on a rotary grate using convective heatin; b. Coal devolatilization on a rotary grate using convective heating; c. Hot particulate removal with cyclones integral solids cooling; and deactivation-passivation; e. Combustors operating on low-Btu gas from internal streams; f. Solids stabilization for storage and shipment; g. Computer control and optimization of a mild coal gasification process. The product fuels are expected to be used economically in commercial boilers and furnaces and to significantly reduce sulfur emissions at industrial and utility facilities currently burning high sulfur bituminous fuels or fuel oils thereby reducing acid rain-causing pollutants. The design and construction of the ENCOAL demonstration plan was done on a fast track basis, that is, these activities were extensively overlapped.

  3. Low NO{sub x}/SO{sub x} Burner retrofit for utility cyclone boilers. Quarterly technical progress report, June--September 1990

    SciTech Connect (OSTI)

    Not Available

    1990-12-31T23:59:59.000Z

    The objective of this project is to demonstrate the LNS Burner as retrofitted to the host cyclone boiler for effective low-cost control of NO{sub x} and SO{sub x} emissions while firing a bituminous coal. The LNS Burner employs a simple, innovative combustion process to burn pulverized coal at high temperatures and provides effective, low-cost control of sulfur dioxide (SO{sub 2}) and nitrogen oxides (NO{sub x}) emissions. The coal ash contains sulfur and is removed in the form of molten slag and flyash. Cyclone-fired boiler units are typically older units firing high-sulfur bituminous coals at very high temperatures which results in very high NO{sub x} and SO{sub x} emissions. The addition of conventional emission control equipment, such as wet scrubbers, to these older cyclone units in order to meet current and future environmental regulations is generally not economic. Further, the units are generally not compatible with low sulfur coal switching for S0{sub 2} control or selective catalytic reduction technologies for NO{sub x} control. Because the LNS Burner operates at the same very high temperatures as a typical cyclone boiler and produces a similar slag product, it may offer a viable retrofit option for cyclone boiler emission control. This was confirmed by the Cyclone Boiler Retrofit Feasibility Study carried out by TransAlta and an Operating Committee formed of cyclone boiler owners in 1989. An existing utility cyclone boiler, was then selected for the evaluation of the cost and performance study. It was concluded that the LNS Burner retrofit would be a cost-effective option for control of cyclone boiler emissions. A full-scale demonstration of the LNS Burner retrofit was selected in October 1988 as part of the DOE`s Clean Coal Technology Program Round II.

  4. Low NO sub x /SO sub x Burner retrofit for utility cyclone boilers

    SciTech Connect (OSTI)

    Not Available

    1990-01-01T23:59:59.000Z

    The objective of this project is to demonstrate the LNS Burner as retrofitted to the host cyclone boiler for effective low-cost control of NO{sub x} and SO{sub x} emissions while firing a bituminous coal. The LNS Burner employs a simple, innovative combustion process to burn pulverized coal at high temperatures and provides effective, low-cost control of sulfur dioxide (SO{sub 2}) and nitrogen oxides (NO{sub x}) emissions. The coal ash contains sulfur and is removed in the form of molten slag and flyash. Cyclone-fired boiler units are typically older units firing high-sulfur bituminous coals at very high temperatures which results in very high NO{sub x} and SO{sub x} emissions. The addition of conventional emission control equipment, such as wet scrubbers, to these older cyclone units in order to meet current and future environmental regulations is generally not economic. Further, the units are generally not compatible with low sulfur coal switching for S0{sub 2} control or selective catalytic reduction technologies for NO{sub x} control. Because the LNS Burner operates at the same very high temperatures as a typical cyclone boiler and produces a similar slag product, it may offer a viable retrofit option for cyclone boiler emission control. This was confirmed by the Cyclone Boiler Retrofit Feasibility Study carried out by TransAlta and an Operating Committee formed of cyclone boiler owners in 1989. An existing utility cyclone boiler, was then selected for the evaluation of the cost and performance study. It was concluded that the LNS Burner retrofit would be a cost-effective option for control of cyclone boiler emissions. A full-scale demonstration of the LNS Burner retrofit was selected in October 1988 as part of the DOE's Clean Coal Technology Program Round II.

  5. Coal system improvements at Union Electric's Labadie Plant

    SciTech Connect (OSTI)

    Graham, D.; Mahr, D.

    1998-07-01T23:59:59.000Z

    Union Electric's Labadie Plant is a 2,400 MWe (4 x 600) coal-fired power generating station. It is located 35 miles west of St. Louis. The four units were commissioned between 1970 and 1973. Units No. 1 and 2 have individual stacks, while Units No. 3 and 4 have a common stack. In response to the lower sulfur requirements of Clean Air Act Amendments, a fuel switching project was implemented in 1991. The plant was originally designed to burn a bituminous, Midwestern coal from the Illinois Basin. This fuel is characterized as a relatively high Btu, high sulfur coal. To met sulfur emission standards, Union Electric modified the boilers, precipitators, and coal handling system to accommodate Powder River Basin (PRB) coal. PRB coal has a lower heating value, 8,500 Btu/lb, versus 12,000 Btu/lb. for the Illinois coal. It is more economical than the available high Btu, low sulfur coals. A switch from Illinois coal to PRB coal has helped the Labadie Plant meet new air quality standards and minimize fuel cost. The increased belt speeds and inherent characteristics of PRB coal amplified handling problems. Dust, spillage increased and the impact on plant operations was more severe. To combat these problems, Union Electric implemented an ongoing improvement program. As experienced was gained, a number of solutions were initiated through several engineering/construction programs and a number of solutions contributed by coal yard personnel. While many of these improvements were a direct result of the switch to PRB coal, they would also be useful on systems handling bituminous coal. New ideas were needed to meet plant objectives of doing more with fewer people. The improvement at Labadie is apparent throughout the coal yard, in access, safety, and cleanliness. Plant improvement is a continuing task. Additional areas within the coal yard are being more closely examined to determine if they can benefit from new techniques that might be applied.

  6. Coal plasticity at high heating rates and temperatures. Final technical progress report

    SciTech Connect (OSTI)

    Gerjarusak, S.; Peters, W.A.; Howard, J.B.

    1995-05-01T23:59:59.000Z

    Plastic coals are important feedstocks in coke manufacture, coal liquefaction, gasification, and combustion. During these processes, the thermoplastic behavior of these coals is also important since it may contribute to desirable or undesirable characteristics. For example, during liquefaction, the plastic behavior is desired since it leads to liquid-liquid reactions which are faster than solid-liquid reactions. During gasification, the elastic behavior is undesired since it leads to caking and agglomeration of coal particles which result in bed bogging in fixed or fluidized bed gasifiers. The plastic behavior of different coals was studied using a fast-response plastometer. A modified plastometer was used to measure the torque required to turn at constant angular speed a cone-shaped disk embedded in a thin layer of coal. The coal particles were packed between two metal plates which are heated electrically. Heating rates, final temperatures, pressures, and durations of experiment ranged from 200--800 K/s, 700--1300 K, vacuum-50 atm helium, and 0--40 s, respectively. The apparent viscosity of the molten coal was calculated from the measured torque using the governing equation of the cone-and-plate viscometer. Using a concentrated suspension model, the molten coal`s apparent viscosity was related to the quantity of the liquid metaplast present during pyrolysis. Seven coals from Argonne National Laboratory Premium Coal Sample Bank were studied. Five bituminous coals, from high-volatile to low-volatile bituminous, were found to have very good plastic behavior. Coal type strongly affects the magnitude and duration of plasticity. Hvb coals were most plastic. Mvb and lvb coals, though the maximum plasticity and plastic period were less. Low rank coals such as subbituminous and lignite did not exhibit any plasticity in the present studies. Coal plasticity is moderately well correlated with simple indices of coal type such as the elemental C,O, and H contents.

  7. Occupational and traning requirements for expanded coal production (as of October 1980). [Forecasting to 1995

    SciTech Connect (OSTI)

    Not Available

    1982-04-01T23:59:59.000Z

    This study was initiated because of the anticipated rapid growth in trained personnel requirements in bituminous coal mining, and because the industry had already experienced significant problems in recruiting skilled manpower in the course of its employment expansion during the 1970's. Employment in bituminous coal mining is projected to nearly double, from 234,000 in 1977 to 456,000 in 1995, as the net result of a projected threefold increase in coal output to nearly 2.0 billion in 1995 and of an expected significant improvement in overall productivity. A large proportion of current coal mining employees are in occupations which require significant amounts of training for effective work performance. Employment growth to 1955 will be most rapid in those occupations requiring the greatest training or educational preparation. The new training infrastructure which has emerged to meet these needs includes both internal, company-operated training programs and those offered by various external providers. Among the latter are: Vocational schools, community colleges, and university extension departments; public agencies, such as MSHA and state mining departments; coal industry trade associations; and vendors or training consultant groups. The Conference Board survey of coal industry training programs, conducted in late 1979, was designed to provide comprehensive data on the scope of the coal industry's own training activities and on related training issues, based on a mail questionnaire survey addressed to all companies producing 300,000 or more tons per year. The training programs are described with emphasis on time changes, regional effects and implications for a coordinated plan.

  8. EERC pilot-scale CFBC evaluation facility Project CFB test results

    SciTech Connect (OSTI)

    Mann, M.D.; Hajicek, D.R.; Henderson, A.K.; Moe, T.A.

    1992-09-01T23:59:59.000Z

    Project CFB was initiated at the University of North Dakota Energy and Environmental Research Center (EERC) in May 1988. Specific goals of the project were to (1) construct a circulating fluidized-bed combustor (CFBC) facility representative of the major boiler vendors' designs with the capability of producing scalable data, (2) develop a database for use in making future evaluations of CFBC technology, and (3) provide a facility for evaluating fuels, free of vendor bias for use in the - energy industry. Five coals were test-burned in the 1-MWth unit: North Dakota and Asian lignites, a Wyoming subbituminous, and Colorado and Pennsylvania bituminous coats. A total of 54 steady-state test periods were conducted, with the key test parameters being the average combustor temperature, excess air, superficial gas velocity, calcium-to-sulfur molar ratio, and the primary air-to-secondary air split. The capture for a coal fired in a CFBC is primarily dependent upon the total alkali-to-sulfur ratio. The required alkali-to ratio for 90% sulfur retention ranged from 1.4 to 4.9, depending upon coal type. While an alkali-to-ratio of 4.9 was required to meet 90% sulfur retention for the Salt Creek coal versus 1.4 for the Asian lignite, the total amount of sorbent addition required is much less for the Salt Creek coal, 4.2 pound sorbent per million Btu coal input, versus 62 pound/million Btu for the Asian lignite. The bituminous coals tested show optimal capture at combustor temperatures of approximately 1550[degree]F, with low-rank coals having optimal sulfur capture approximately 100[degree]F lower.

  9. EERC pilot-scale CFBC evaluation facility Project CFB test results. Topical report, Task 7.30

    SciTech Connect (OSTI)

    Mann, M.D.; Hajicek, D.R.; Henderson, A.K.; Moe, T.A.

    1992-09-01T23:59:59.000Z

    Project CFB was initiated at the University of North Dakota Energy and Environmental Research Center (EERC) in May 1988. Specific goals of the project were to (1) construct a circulating fluidized-bed combustor (CFBC) facility representative of the major boiler vendors` designs with the capability of producing scalable data, (2) develop a database for use in making future evaluations of CFBC technology, and (3) provide a facility for evaluating fuels, free of vendor bias for use in the - energy industry. Five coals were test-burned in the 1-MWth unit: North Dakota and Asian lignites, a Wyoming subbituminous, and Colorado and Pennsylvania bituminous coats. A total of 54 steady-state test periods were conducted, with the key test parameters being the average combustor temperature, excess air, superficial gas velocity, calcium-to-sulfur molar ratio, and the primary air-to-secondary air split. The capture for a coal fired in a CFBC is primarily dependent upon the total alkali-to-sulfur ratio. The required alkali-to ratio for 90% sulfur retention ranged from 1.4 to 4.9, depending upon coal type. While an alkali-to-ratio of 4.9 was required to meet 90% sulfur retention for the Salt Creek coal versus 1.4 for the Asian lignite, the total amount of sorbent addition required is much less for the Salt Creek coal, 4.2 pound sorbent per million Btu coal input, versus 62 pound/million Btu for the Asian lignite. The bituminous coals tested show optimal capture at combustor temperatures of approximately 1550{degree}F, with low-rank coals having optimal sulfur capture approximately 100{degree}F lower.

  10. Synthesis gas production with an adjustable H{sub 2}/CO ratio through the coal gasification process: effects of coal ranks and methane addition

    SciTech Connect (OSTI)

    Yan Cao; Zhengyang Gao; Jing Jin; Hongchang Zhou; Marten Cohron; Houying Zhao; Hongying Liu; Weiping Pan [Western Kentucky University (WKU), Bowling Green, KY (United States). Institute for Combustion Science and Environmental Technology (ICSET)

    2008-05-15T23:59:59.000Z

    Direct production of synthesis gas using coal as a cheap feedstock is attractive but challenging due to its low H{sub 2}/CO ratio of generated synthesis gas. Three typical U.S. coals of different ranks were tested in a 2.5 in. coal gasifier to investigate their gasification reactivity and adjustability on H{sub 2}/CO ratio of generated synthesis gas with or without the addition of methane. Tests indicated that lower-rank coals (lignite and sub-bituminous) have higher gasification reactivity than bituminous coals. The coal gasification reactivity is correlated to its synthesis-gas yield and the total percentage of H{sub 2} and CO in the synthesis gas, but not to the H{sub 2}/CO ratio. The H{sub 2}/CO ratio of coal gasification was found to be correlated to the rank of coals, especially the H/C ratio of coals. Methane addition into the dense phase of the pyrolysis and gasification zone of the cogasification reactor could make the best use of methane in adjusting the H{sub 2}/CO ratio of the generated synthesis gas. The maximum methane conversion efficiency, which was likely correlated to its gasification reactivity, could be achieved by 70% on average for all tested coals. The actual catalytic effect of generated coal chars on methane conversion seemed coal-dependent. The coal-gasification process benefits from methane addition and subsequent conversion on the adjustment of the H{sub 2}/CO ratio of synthesis gas. The methane conversion process benefits from the use of coal chars due to their catalytic effects. This implies that there were likely synergistic effects on both. 25 refs., 3 figs., 3

  11. Effect of coal type, residence time, and combustion configuration on the submicron aerosol composition and size distribution from pulverized coal combustion

    SciTech Connect (OSTI)

    Linak, W.P.

    1985-01-01T23:59:59.000Z

    Pulverized samples of Utah bituminous, Beulah (North Dakota) low Na lignite, Deulah high Na lignite and Texas (San Miguel) lignite coals were burned at a rate of 2.5 kg/hr in a laboratory furnace under various (overall fuel lean) combustion conditions. Particle size distributions (PSD) and size segregated particle filter samples were taken at various positions within the convection section. Temperature and gas concentrations were measured throughout. The evolution of the submicron PSD within the convection section for the four coals was similar, although the location of the initial particle mode at the convection section inlet varied with coal type. While stage combustion of the Utah bituminous coal had a variable effect on the volume of submicron aerosol produced, staged combustion of two of the three lignites (Beulah low Na and Texas) caused a definite increase in the submicron aerosol volume. Chemical analysis of the size segregated particle samples show the trace elements, As, Pb, Zn, and the major elements, Na and K to be enriched in the submicron aerosol. Auger depth profiles show these small particles to be comprised of a core enriched in Fe, Si, Ca and Mg and surface layers enriched in Na and K. These results point to a mechanism of homogeneous nucleation of low vapor pressure species followed by successive layering of progressively more volatile species. Volatile species are enriched in the submicron aerosol due to the large surface areas provided. Modeling efforts show that while coagulation may be the dominant mechanism to describe the aerosol evolving within the convection section, it cannot be used solely to predict the PSD. Another mechanism, presumably surface area dependent growth (condensation) must be included.

  12. Enhanced Combustion Low NOx Pulverized Coal Burner

    SciTech Connect (OSTI)

    David Towle; Richard Donais; Todd Hellewell; Robert Lewis; Robert Schrecengost

    2007-06-30T23:59:59.000Z

    For more than two decades, Alstom Power Inc. (Alstom) has developed a range of low cost, infurnace technologies for NOx emissions control for the domestic U.S. pulverized coal fired boiler market. This includes Alstom's internally developed TFS 2000{trademark} firing system, and various enhancements to it developed in concert with the U.S. Department of Energy. As of the date of this report, more than 270 units representing approximately 80,000 MWe of domestic coal fired capacity have been retrofit with Alstom low NOx technology. Best of class emissions range from 0.18 lb/MMBtu for bituminous coal to 0.10 lb/MMBtu for subbituminous coal, with typical levels at 0.24 lb/MMBtu and 0.13 lb/MMBtu, respectively. Despite these gains, NOx emissions limits in the U.S. continue to ratchet down for new and existing boiler equipment. On March 10, 2005, the Environmental Protection Agency (EPA) announced the Clean Air Interstate Rule (CAIR). CAIR requires 25 Eastern states to reduce NOx emissions from the power generation sector by 1.7 million tons in 2009 and 2.0 million tons by 2015. Low cost solutions to meet such regulations, and in particular those that can avoid the need for a costly selective catalytic reduction system (SCR), provide a strong incentive to continue to improve low NOx firing system technology to meet current and anticipated NOx control regulations. The overall objective of the work is to develop an enhanced combustion, low NOx pulverized coal burner, which, when integrated with Alstom's state-of-the-art, globally air staged low NOx firing systems will provide a means to achieve: Less than 0.15 lb/MMBtu NOx emissions when firing a high volatile Eastern or Western bituminous coal, Less than 0.10 lb/MMBtu NOx emissions when firing a subbituminous coal, NOx reduction costs at least 25% lower than the costs of an SCR, Validation of the NOx control technology developed through large (15 MWt) pilot scale demonstration, and Documentation required for economic evaluation and commercial application. During the project performance period, Alstom performed computational fluid dynamics (CFD) modeling and large pilot scale combustion testing in its Industrial Scale Burner Facility (ISBF) at its U.S. Power Plant Laboratories facility in Windsor, Connecticut in support of these objectives. The NOx reduction approach was to optimize near-field combustion to ensure that minimum NOx emissions are achieved with minimal impact on unburned carbon in ash, slagging and fouling, corrosion, and flame stability/turn-down. Several iterations of CFD and combustion testing on a Midwest coal led to an optimized design, which was extensively combustion tested on a range of coals. The data from these tests were then used to validate system costs and benefits versus SCR. Three coals were evaluated during the bench-scale and large pilot-scale testing tasks. The three coals ranged from a very reactive subbituminous coal to a moderately reactive Western bituminous coal to a much less reactive Midwest bituminous coal. Bench-scale testing was comprised of standard ASTM properties evaluation, plus more detailed characterization of fuel properties through drop tube furnace testing and thermogravimetric analysis. Bench-scale characterization of the three test coals showed that both NOx emissions and combustion performance are a strong function of coal properties. The more reactive coals evolved more of their fuel bound nitrogen in the substoichiometric main burner zone than less reactive coal, resulting in the potential for lower NOx emissions. From a combustion point of view, the more reactive coals also showed lower carbon in ash and CO values than the less reactive coal at any given main burner zone stoichiometry. According to bench-scale results, the subbituminous coal was found to be the most amenable to both low NOx, and acceptably low combustibles in the flue gas, in an air staged low NOx system. The Midwest bituminous coal, by contrast, was predicted to be the most challenging of the three coals, with the Western bituminous coal predicted to beh

  13. Vertical Profiles Of {sup 226}Ra, {sup 232}Th And {sup 40}K Activities In Rocks From The Irati Formation Of The Parana Sedimentary Basin, Southern Brazil

    SciTech Connect (OSTI)

    Ferreira, Ademar de O.; Bastos, Rodrigo O.; Appoloni, Carlos R. [Laboratorio de Fisica Nuclear Aplicada-Departamento de Fisica-CCE Universidade Estadual de Londrina-Campus Universitario Rodovia Celso Garcia Cid s/n, Cx. Postal 6001 86051-990 Londrina (Puerto Rico)

    2008-08-07T23:59:59.000Z

    Naturally occurring radioisotopes are present in different concentrations in sedimentary rocks, reflecting the origin of the sediments, the depositional environment, and more recent events such as weathering and erosion. Using a high-resolution {gamma}-ray spectrometry methodology, sedimentary rocks were measured to assess the concentration activities of the natural radioisotopes. The surveyed rocks are from the Irati formation in the Parana sedimentary basin, which are exposed by an abandoned, open-pit limestone mine, in the city of Sapopema, southern Brazil. The exposed vertical profile is 5 m, and its stratigraphy is represented by an alternation of limestone and bituminous shale (layers being a few decimeters thick), and some millimeter rhythm layers with limestone and bituminous shale laminas. Eleven samples were collected along this profile, each of them dried in the open air during 48 hours, sieved through 4 mm mesh and sealed in cylindrical recipients. Measurements were accomplished using a 66% relative efficiency HPGE detector connected to a standard gamma ray spectrometry electronic chain. The detector efficiency in the range of 60 to 1800 keV was carried out with the certified IAEA-385 sediment sample. The Lower Limit of Detection (LLD) to the system is 2.40 Bq{center_dot}kg{sup -1} for {sup 226}Ra, 1.84 Bq{center_dot}kg{sup -1} for {sup 232}Th and 4.20 Bq{center_dot}kg{sup -1} for {sup 40}K. Activity concentrations were determined for {sup 226}Ra (from 16.22 to 151.55 Bq{center_dot}kg{sup -1}), {sup 232}Th (from 2.93 to 56.12 Bq{center_dot}kg{sup -1}) and {sup 40}K (from 38.45 to 644.63 Bq{center_dot}kg{sup -1}). The layers enriched with organic matter presented the higher values of activity. The measured concentrations of the natural radioisotopes were lower for limestone samples (average values and respective deviations were 22.81{+-}0.22 Bq{center_dot}kg{sup -1} for {sup 226}Ra, 4.21{+-}0.07 Bq{center_dot}kg{sup -1} for {sup 232}Th, and 50.11{+-}0.82 Bq{center_dot}kg{sup -1} for {sup 40}K). Higher concentrations were measured for the bituminous shale samples (average values and respective deviations were 108.10{+-}12.17 Bq{center_dot}kg{sup -1} for {sup 226}Ra, 43.69{+-}0.30 Bq{center_dot}kg{sup -1} for {sup 232}Th, and 465.82{+-}3.99 Bq{center_dot}kg{sup -1} for {sup 40}K). The concentrations were intermediate for the rhythmite samples (average values and respective deviations were 50.69{+-}1.09 Bq{center_dot}kg{sup -1} for {sup 226}Ra, 7.63{+-}0.21 Bq{center_dot}kg{sup -1} for {sup 232}Th, and 85.96{+-}2.47 Bq{center_dot}kg{sup -1} for {sup 40}K). As the analyzed rocks are raw materials for the ceramic, cement and soil correction compound industries, the results of this work furnish data to estimate the contribution of these products to the general public's radiation exposure.

  14. Final Treatment Center Project for Liquid and Wet Radioactive Waste in Slovakia

    SciTech Connect (OSTI)

    Kravarik, K.; Stubna, M.; Pekar, A.; Krajc, T.; Zatkulak, M.; Holicka, Z. [VUJE, Inc., Okruzna 5, 918 64 Trnava (Slovakia); Slezak, M. [SE - VYZ, 919 31 Jaslovske Bohunice (Slovakia)

    2006-07-01T23:59:59.000Z

    The Final Treatment Center (FTC) for Mochovce nuclear power plant (NPP) is designed for treatment and final conditioning of radioactive liquid and wet waste produced from plant operation. Mochovce NNP uses a Russian VVER-440 type reactor. Treated wastes comprise radioactive concentrates, spent resin and sludge. VUJE Inc. as an experienced company in field of treatment of radioactive waste in Slovakia has been chosen as main contractor for technological part of FTC. This paper describes the capacity, flow chart, overall waste flow and parameters of the main components in the FTC. The initial project was submitted for approval to the Slovak Electric plc. in 2003. The design and manufacture of main components were performed in 2004 and 2005. FTC construction work started early in 2004. Initial non-radioactive testing of the system is planned for summer 2006 and then radioactive tests are to be followed. A one-year trial operation of facility is planned for completion in 2007. SE - VYZ will be operates the FTC during trial operation and after its completion. SE - VYZ is subsidiary company of Slovak Electric plc. and it is responsible for treatment with radioactive waste and spent fuel in the Slovak republic. SE - VYZ has, besides of other significant experience with operation of Jaslovske Bohunice Treatment Centre. The overall capacity of the FTC is 870 m{sup 3}/year of concentrates and 40 m{sup 3}/year of spent resin and sludge. Bituminization and cementation were provided as main technologies for treatment of these wastes. Treatment of concentrate is performed by bituminization. Concentrate and bitumen are metered into a thin film evaporator with rotating wiping blades. Surplus water is evaporated and concentrate salts are embedded in bitumen. Bitumen product is discharged into 200 l steel drums. Spent resin and sludge are decanted, dried and mixed with bitumen. These mixtures are also discharged into 200 l steel drums. Drums are moved along bituminization line on a roller conveyor. After the drums cool, they are capped and removed from the conveyor and placed in a storage hall. Drums with bitumen product are loaded into Fiber Reinforced Concrete containers (FRC) and grouted with cement. Cement grout is prepared from mixture of cement, additive and radioactive concentrates. By formulating the cement grout with evaporator concentrates the maximum radioactivity is fixed in cement matrix and volume of final waste product is minimized. A batch mixer with rotating blades is used produce the cement grout. FRCs loaded with bitumen drums are placed on roller conveyor and moved along the cementation line. Grouted FRCs are stored in the expedition hall for 28 days of curing and then transported to final disposal. After placed in operation the FTC provides treatment for all liquid and wet LLW produced from the operation of the Mochovce NPP. The final product of the FTC is a FRC loaded with 7 drums of waste fixed in bitumen and the space between the drums is grouted with cement. This container meets all limits for final disposal in the National Radioactive Waste Repository at Mochovce. (authors)

  15. Oxidation of Mercury in Products of Coal Combustion

    SciTech Connect (OSTI)

    Peter Walsh; Giang Tong; Neeles Bhopatkar; Thomas Gale; George Blankenship; Conrad Ingram; Selasi Blavo Tesfamariam Mehreteab; Victor Banjoko; Yohannes Ghirmazion; Heng Ban; April Sibley

    2009-09-14T23:59:59.000Z

    Laboratory measurements of mercury oxidation during selective catalytic reduction (SCR) of nitric oxide, simulation of pilot-scale measurements of mercury oxidation and adsorption by unburned carbon and fly ash, and synthesis of new materials for simultaneous oxidation and adsorption of mercury, were performed in support of the development of technology for control of mercury emissions from coal-fired boilers and furnaces. Conversion of gas-phase mercury from the elemental state to water-soluble oxidized form (HgCl{sub 2}) enables removal of mercury during wet flue gas desulfurization. The increase in mercury oxidation in a monolithic V{sub 2}O{sub 5}-WO{sub 3}/TiO{sub 2} SCR catalyst with increasing HCl at low levels of HCl (< 10 ppmv) and decrease in mercury oxidation with increasing NH{sub 3}/NO ratio during SCR were consistent with results of previous work by others. The most significant finding of the present work was the inhibition of mercury oxidation in the presence of CO during SCR of NO at low levels of HCl. In the presence of 2 ppmv HCl, expected in combustion products from some Powder River Basin coals, an increase in CO from 0 to 50 ppmv reduced the extent of mercury oxidation from 24 {+-} 3 to 1 {+-} 4%. Further increase in CO to 100 ppmv completely suppressed mercury oxidation. In the presence of 11-12 ppmv HCl, increasing CO from 0 to {approx}120 ppmv reduced mercury oxidation from {approx}70% to 50%. Conversion of SO{sub 2} to sulfate also decreased with increasing NH{sub 3}/NO ratio, but the effects of HCl and CO in flue gas on SO{sub 2} oxidation were unclear. Oxidation and adsorption of mercury by unburned carbon and fly ash enables mercury removal in a particulate control device. A chemical kinetic mechanism consisting of nine homogeneous and heterogeneous reactions for mercury oxidation and removal was developed to interpret pilot-scale measurements of mercury oxidation and adsorption by unburned carbon and fly ash in experiments at pilot scale, burning bituminous coals (Gale, 2006) and blends of bituminous coals with Powder River Basin coal (Gale, 2005). The removal of mercury by fly ash and unburned carbon in the flue gas from combustion of the bituminous coals and blends was reproduced with satisfactory accuracy by the model. The enhancement of mercury capture in the presence of calcium (Gale, 2005) explained a synergistic effect of blending on mercury removal across the baghouse. The extent of mercury oxidation, on the other hand, was not so well described by the simulation, because of oversensitivity of the oxidation process in the model to the concentration of unburned carbon. Combined catalysts and sorbents for oxidation and removal of mercury from flue gas at low temperature were based on surfactant-templated silicas containing a transition metal and an organic functional group. The presence of both metal ions and organic groups within the pore structure of the materials is expected to impart to them the ability to simultaneously oxidize elemental mercury and adsorb the resulting oxidized mercury. Twelve mesoporous organosilicate catalysts/sorbents were synthesized, with and without metals (manganese, titanium, vanadium) and organic functional groups (aminopropyl, chloropropyl, mercaptopropyl). Measurement of mercury oxidation and adsorption by the candidate materials remains for future work.

  16. ADVANCED MULTI-PRODUCT COAL UTILIZATION BY-PRODUCT PROCESSING PLANT

    SciTech Connect (OSTI)

    Robert Jewell; Thomas Robl; John Groppo

    2005-03-01T23:59:59.000Z

    The objective of the project is to build a multi-product ash beneficiation plant at Kentucky Utilities 2,200-MW Ghent Generating Station, located in Carroll County, Kentucky. This part of the study includes the examination of the feedstocks for the beneficiation plant. The ash, as produced by the plant, and that stored in the lower pond were examined. The ash produced by the plant was found to be highly variable as the plant consumes high and low sulfur bituminous coal, in Units 1 and 2 and a mixture of subbituminous and bituminous coal in Units 3 and 4. The ash produced reflected this consisting of an iron-rich ({approx}24%, Fe{sub 2}O{sub 3}), aluminum rich ({approx}29% Al{sub 2}O{sub 3}) and high calcium (6%-7%, CaO) ash, respectively. The LOI of the ash typically was in the range of 5.5% to 6.5%, but individual samples ranged from 1% to almost 9%. The lower pond at Ghent is a substantial body, covering more than 100 acres, with a volume that exceeds 200 million cubic feet. The sedimentation, stratigraphy and resource assessment of the in place ash was investigated with vibracoring and three-dimensional, computer-modeling techniques. Thirteen cores to depths reaching nearly 40 feet, were retrieved, logged in the field and transported to the lab for a series of analyses for particle size, loss on ignition, petrography, x-ray diffraction, and x-ray fluorescence. Collected data were processed using ArcViewGIS, Rockware, and Microsoft Excel to create three-dimensional, layered iso-grade maps, as well as stratigraphic columns and profiles, and reserve estimations. The ash in the pond was projected to exceed 7 million tons and contain over 1.5 million tons of coarse carbon, and 1.8 million tons of fine (<10 {micro}m) glassy pozzolanic material. The size, quality and consistency of the ponded material suggests that it is the better feedstock for the beneficiation plant.

  17. Upgrading low rank coal using the Koppelman Series C process

    SciTech Connect (OSTI)

    Merriam, N.W., Western Research Institute

    1998-01-01T23:59:59.000Z

    Development of the K-Fuel technology began after the energy shortage of the early 1970s in the United States led energy producers to develop the huge deposits of low-sulfur coal in the Powder River Basin (PRB) of Wyoming. PRB coal is a subbituminous C coal containing about 30 wt % moisture and having heating values of about 18.6 megajoules/kg (8150 Btu/lb). PRB coal contains from 0.3 to 0.5 wt % sulfur, which is nearly all combined with the organic matrix in the coal. It is in much demand for boiler fuel because of the low-sulfur content and the low price. However, the low-heating value limits the markets for PRB coal to boilers specially designed for the high- moisture coal. Thus, the advantages of the low-sulfur content are not available to many potential customers having boilers that were designed for bituminous coal. This year about 250 million tons of coal is shipped from the Powder River Basin of Wyoming. The high- moisture content and, consequently, the low-heating value of this coal causes the transportation and combustion of the coal to be inefficient. When the moisture is removed and the heating value increased the same bundle of energy can be shipped using one- third less train loads. Also, the dried product can be burned much more efficiently in boiler systems. This increase in efficiency reduces the carbon dioxide emissions caused by use of the low-heating value coal. Also, the processing used to remove water and restructure the coal removes sulfur, nitrogen, mercury, and chlorides from the coal. This precombustion cleaning is much less costly than stack scrubbing. PRB coal, and other low-rank coals, tend to be highly reactive when freshly mined. These reactive coals must be mixed regularly (every week or two) when fresh, but become somewhat more stable after they have aged for several weeks. PRB coal is relatively dusty and subject to self-ignition compared to bituminous coals. When dried using conventional technology, PRB coal is even more dusty and more susceptible to spontaneous combustion than the raw coal. Also, PRB coal, if dried at low temperature, typically readsorbs about two- thirds of the moisture removed by drying. This readsorption of moisture releases the heat of adsorption of the water which is a major cause of self- heating of low-rank coals at low temperature.

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

    SciTech Connect (OSTI)

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

    2013-09-30T23:59:59.000Z

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

  19. Advanced coal liquefaction research. Quarterly technical progress report, July 1, 1983-September 30, 1983

    SciTech Connect (OSTI)

    None

    1984-04-01T23:59:59.000Z

    Work this quarter focused on staged liquefaction. The effect of residence time on conversion in single pass experiments was found to be quite different for the subbituminous Belle Ayr Mine and bituminous Illinois No. 6 coals studied. With bituminous coal, conversion to soluble material is quite high and the limit of conversion is approached in only a few minutes. With a subbituminous coal, however, conversion is much lower and the limit of conversion is approached much more slowly. Short contact time (SCT) dissolution of Belle Ayr coal was studied as a possible first stage in a two-stage process. Conversion, hydrocarbon gas yield and hydrogen consumption were increased as residence time or temperature were increased. Conversion was also significantly increased by partial slurry recycle. Pyrite was found to be the most effective slurry catalyst for increasing conversion, followed by ammonium molybdate emulsion and finally nickel-molybdenum on alumina. Illinois No. 6 coal was liquefied in two stages. Conditions in the first stage dissolution were varied to determine the effect on upgradability in the second stage. An SCT (6 minute) coal dissolution stage is preferred over one at 30 minutes because hydrocarbon gas yield was much lower while overall oil yields for the combined dissolution and upgrading stages were nearly the same. Use of a NiMo/Al/sub 2/O/sub 3/ catalyst in a trickle-bed second stage resulted in a higher oil yield and lower product heteroatom content than use of the same catalyst in the slurry phase. The total oil yield was lower with a pyrite slurry catalyst than with a NiMo/Al/sub 2/O/sub 3/ slurry catalyst. With Belle Ayr coal and added pyrite, there was no change in total oil yield, conversion or product quality brought about by adding an 8-minute first stage at 450/sup 0/C (842/sup 0/F) to a 2-hour second stage operated at 420/sup 0/C (788/sup 0/F). 39 figures, 12 tables.

  20. HIGH PRESSURE COAL COMBUSTON KINETICS PROJECT

    SciTech Connect (OSTI)

    Stefano Orsino

    2005-03-30T23:59:59.000Z

    As part of the U.S. Department of Energy (DoE) initiative to improve the efficiency of coal-fired power plants and reduce the pollution generated by these facilities, DOE has funded the High-Pressure Coal Combustion Kinetics (HPCCK) Projects. A series of laboratory experiments were conducted on selected pulverized coals at elevated pressures with the specific goals to provide new data for pressurized coal combustion that will help extend to high pressure and validate models for burnout, pollutant formation, and generate samples of solid combustion products for analyses to fill crucial gaps in knowledge of char morphology and fly ash formation. Two series of high-pressure coal combustion experiments were performed using SRI's pressurized radiant coal flow reactor. The first series of tests characterized the near burner flame zone (NBFZ). Three coals were tested, two high volatile bituminous (Pittsburgh No.8 and Illinois No.6), and one sub-bituminous (Powder River Basin), at pressures of 1, 2, and 3 MPa (10, 20, and 30 atm). The second series of experiments, which covered high-pressure burnout (HPBO) conditions, utilized a range of substantially longer combustion residence times to produce char burnout levels from 50% to 100%. The same three coals were tested at 1, 2, and 3 MPa, as well as at 0.2 MPa. Tests were also conducted on Pittsburgh No.8 coal in CO2 entrainment gas at 0.2, 1, and 2 MPa to begin establishing a database of experiments relevant to carbon sequestration techniques. The HPBO test series included use of an impactor-type particle sampler to measure the particle size distribution of fly ash produced under complete burnout conditions. The collected data have been interpreted with the help of CFD and detailed kinetics simulation to extend and validate devolatilization, char combustion and pollutant model at elevated pressure. A global NOX production sub-model has been proposed. The submodel reproduces the performance of the detailed chemical reaction mechanism for the NBFZ tests.

  1. Process performance of Ahlstrom Pyroflow PCFB pilot plant

    SciTech Connect (OSTI)

    Sellakumar, K.M. [R& D Center, Ahlstrom Pyropower, Inc., San Diego, CA (United States); Isaksson, J.; Tiensuu, J. [Ahlstroem Pyropower, Inc., Karhula (Finland). Hans Ahlstroem Lab.

    1993-05-01T23:59:59.000Z

    Ahlstrom Pyropower has designed and built a 10 MW{sub th} (34 MMBtu) pressurized circulating fluidized bed (PCFB) pilot plant in Karhula, Finland. The unit is now operating. Data from this unit supports the design of a nominal 80 MW, Des Moines Energy Center 1 (DMEC-1) PCFB Repowering Project. The pilot plant PCFB combustor is of square cross-section. It is housed in a 3.6 m (11.8 ft) diameter pressure vessel. A high pressure high temperature gas cleaning unit downstream of the PCFB exhaust is installed in a separate 2.6 m (8.5 ft) diameter pressure vessel. The maximum plant operating pressure is 16 bar (232 psia). The fuel is fed in slurry form; sorbent is also fed along with the fuel. The net heat input per unit cross section of the combustor is the highest of any known combustion mode. The heat release can go up to 40 MW/m{sup 2} (12.6 MMBtu/ft{sup 2} hr). Many types of coals including high sulfur, bituminous Illinois No. 6 coal and Western sub bituminous, low sulfur Powder River Basin coal were tested. Combustion efficiencies in the range of 99.5 to 99.9% have been consistently observed. Emissions of various gases such as NO{sub x} SO{sub 2} and CO at different operating pressures and loads were monitored. The gas emissions have been lower than expected based on atmospheric circulating fluidized bed boiler experience. The sulfur retention is over 95 % with a Ca/S molar ratio of 1 to 2 for high sulfur Illinois No.6 coal. A GAVS molar ratio of 2.5 to 3.5 was observed to retain 95 % of sulfur with low sulfur Powder River Basin coal. All gaseous emissions during testing with Illinois No. 6 coal and Powder River Basin coal are well within the projected limits for the DMEC1 project. Emission data from tests with Illinois No. 6 coal and Powder River Basin coal are presented in the paper.

  2. Process performance of Ahlstrom Pyroflow PCFB pilot plant

    SciTech Connect (OSTI)

    Sellakumar, K.M. (R D Center, Ahlstrom Pyropower, Inc., San Diego, CA (United States)); Isaksson, J.; Tiensuu, J. (Ahlstroem Pyropower, Inc., Karhula (Finland). Hans Ahlstroem Lab.)

    1993-05-01T23:59:59.000Z

    Ahlstrom Pyropower has designed and built a 10 MW[sub th] (34 MMBtu) pressurized circulating fluidized bed (PCFB) pilot plant in Karhula, Finland. The unit is now operating. Data from this unit supports the design of a nominal 80 MW, Des Moines Energy Center 1 (DMEC-1) PCFB Repowering Project. The pilot plant PCFB combustor is of square cross-section. It is housed in a 3.6 m (11.8 ft) diameter pressure vessel. A high pressure high temperature gas cleaning unit downstream of the PCFB exhaust is installed in a separate 2.6 m (8.5 ft) diameter pressure vessel. The maximum plant operating pressure is 16 bar (232 psia). The fuel is fed in slurry form; sorbent is also fed along with the fuel. The net heat input per unit cross section of the combustor is the highest of any known combustion mode. The heat release can go up to 40 MW/m[sup 2] (12.6 MMBtu/ft[sup 2] hr). Many types of coals including high sulfur, bituminous Illinois No. 6 coal and Western sub bituminous, low sulfur Powder River Basin coal were tested. Combustion efficiencies in the range of 99.5 to 99.9% have been consistently observed. Emissions of various gases such as NO[sub x] SO[sub 2] and CO at different operating pressures and loads were monitored. The gas emissions have been lower than expected based on atmospheric circulating fluidized bed boiler experience. The sulfur retention is over 95 % with a Ca/S molar ratio of 1 to 2 for high sulfur Illinois No.6 coal. A GAVS molar ratio of 2.5 to 3.5 was observed to retain 95 % of sulfur with low sulfur Powder River Basin coal. All gaseous emissions during testing with Illinois No. 6 coal and Powder River Basin coal are well within the projected limits for the DMEC1 project. Emission data from tests with Illinois No. 6 coal and Powder River Basin coal are presented in the paper.

  3. SAMPLING, ANALYSIS, AND PROPERTIES OF PRIMARY PM-2.5: APPLICATION TO COAL-FIRED UTILITY BOILERS

    SciTech Connect (OSTI)

    Allen L. Robinson; Spyros N. Pandis; Eric Lipsky; Charles Stainer; Natalie Anderson; Satoshi Takahama; Sarah Rees

    2003-02-01T23:59:59.000Z

    A dilution sampler was used to examine the effects of dilution ratio and residence time on the particulate emissions from a pilot-scale pulverized coal combustor. Measurements include the particle size distribution from 0.003 to 2.5 {micro}m, PM{sub 2.5} mass emission rate and PM2.5 composition (OC/EC, major ions, and elemental). Hot filter samples were also collected simultaneously in order to compare the dilution sampler measurement with standard stack sampling methodologies such as EPA Method 5. Measurements were made both before and after the bag-house, the particle control device used on the coal combustor. Measurements were made with three different coal types and a coal-biomass blend. The residence time and dilution ratio do not influence the PM{sub 2.5} mass emission rate, but have a significant effect on the size distribution and total number emissions. Measurements made before the bag-house showed increasing the residence time dramatically decreases the total particle number concentration, and shifts the particle mass to larger sizes. The effects of residence time can be explained quantitatively by the coagulation of the emitted particles. Measurements made after the bag-house were not affected by coagulation due to the lower concentration of particles. Nucleation of sulfuric acid vapor within the dilution was an important source of ultrafine particles. This nucleation is strongly a function of dilution ratio because of the competition between condensation and nucleation. At low dilution ratios condensation dominates and little nucleation is observed; increasing the dilution ratio promotes nucleation because of the corresponding decrease in available surface area per unit volume for condensation. No nucleation was observed after the bag house where conditions greatly favor nucleation over condensation; we suspect that the bag house removed the SO{sub 3} in the flue gas. Exhaust SO{sub 3} levels were not measured during these experiments. Dilution caused the enrichment of selenium, ammonium and sulfate in the PM{sub 2.5} emissions compared to the hot filter samples. The enrichment of selenium was independent of dilution ratio or residence time. The enrichment of ammonium and sulfate increased with increasing dilution ratio. PM{sub 2.5} emission profiles for four different fuels (two eastern bituminous coals, a western sub-bituminous coal, and coal-wood blend) were developed. These profiles compared well with profiles from similar coal sources, while showing unique characteristics due to differences in fuel composition.

  4. DEVELOPMENT OF A VALIDATED MODEL FOR USE IN MINIMIZING NOx EMISSIONS AND MAXIMIZING CARBON UTILIZATION WHEN CO-FIRING BIOMASS WITH COAL

    SciTech Connect (OSTI)

    Larry G. Felix; P. Vann Bush

    2002-07-01T23:59:59.000Z

    This is the seventh Quarterly Technical Report for DOE Cooperative Agreement No. DE-FC26-00NT40895. A statement of the project objectives is included in the Introduction of this report. Two additional biomass co-firing test burns were conducted during this quarter. In the first test (Test 12), up to 20% by weight dry hardwood sawdust and switchgrass was comilled with Galatia coal and injected through the single-register burner. Liquid ammonia was intermittently added to the primary air stream to increase fuel-bound nitrogen and simulate cofiring with chicken litter. Galatia coal is a medium-sulfur ({approx} 1.2% S), high chlorine ({approx}0.5%) Illinois Basin coal. In the second test (Test 13), up to 20% by weight dry hardwood sawdust and switchgrass was comilled with Jim Walters No.7 mine coal and injected through the single-register burner. Jim Walters No.7 coal is a low-volatility, low-sulfur ({approx} 0.7% S) Eastern bituminous coal. The results of these tests are presented in this quarterly report. Progress has continued to be made in implementing a modeling approach to combine reaction times and temperature distributions from computational fluid dynamic models of the pilot-scale combustion furnace with char burnout and chemical reaction kinetics to predict NO{sub x} emissions and unburned carbon levels in the furnace exhaust. The Configurable Fireside Simulator has been delivered from REI, Inc. and is being tested with exiting CFD solutions. Preparations are under way for a final pilot-scale combustion experiment using the single-register burner fired with comilled mixtures of Jim Walters No.7 low-volatility bituminous coal and switchgrass. Because of the delayed delivery of the Configurable Fireside Simulator, it is planned to ask for a no-cost time extension for the project until the end of this calendar year. Finally, a paper describing this project that included preliminary results from the first four cofiring tests was presented at the 12th European Conference and Technology Exhibition on Biomass for Energy, Industry and Climate Protection in Amsterdam, The Netherlands, in June, 2002.

  5. ULTRA HIGH EFFICIENCY ESP DEVELOPMENT FOR AIR TOXICS CONTROL

    SciTech Connect (OSTI)

    David K. Anderson

    1999-11-01T23:59:59.000Z

    Because more than 90 percent of U.S. coal-fired utility boilers are equipped with electrostatic precipitators (ESPs), retrofitable ESP technologies represent a logical approach towards achieving the Department of Energy's (DOE) goal of a major reduction in fine particulate and mercury emissions (air toxics) from coal based power systems. EPA's recent issuance of significantly tightened ambient air standards for particles smaller than 2.5 {micro}m (PM{sub 2.5}) creates a new urgency for developing cost-effective means to control fine particulate emissions. This challenge is compounded by the on-going switch in the utility industry to low-sulfur Powder River Basin (PRB) coals, that generate higher resistivity and difficult-to-collect fly ash. Particulate emissions can increase by a factor of ten when a utility switches to a low-sulfur coal. Numerous power plants are presently limited in operation by the inability of their ESPs to control opacity at high loads. In Phase I of this program, ABB investigated five technologies to improve the collection of fine particulate and trace metals in ESPs. These included: (1) flue-gas cooling, (2) flue-gas humidification, (3) pulsed energization, (4) wet ESP and precharger modules, and (5) sorbent injection for mercury control. Tests were conducted with an Eastern bituminous coal and a Powder River Basin sub-bituminous low-sulfur coal in an integrated pilot-scale combustor and ESP test facility. The impacts of the different retrofit technologies on ESP performance, individually and in combination, were evaluated indepth through advanced sampling and measurement techniques. In Phase II, the most promising concepts identified from Phase I testing, flue-gas cooling and humidification, pulsed energization, and sorbent injection at low flue-gas temperatures for mercury control, were integrated into a commercially oriented sub-scale system for field testing at Commonwealth Edison's Waukegan Unit No. 8. The main objective of the proposed Phase II testing was to determine longer term ESP performance and mercury capture improvements with the above enhancements for a range of low-sulfur coals currently fired by utilities. Unanticipated cost growth in readying the Pilot Plant for shipment and during slipstream construction at the utility host site resulted in the issuance of a preemptive stop work order from ABB until a detailed technical and budgetary review of the project could be completed. Four program recovery scenarios were developed and presented to the DOE. After careful review of these options, it was decided to terminate the program and although the Pilot Plant installation was essentially completed, no testing was performed. The Pilot Plant was subsequently decommissioned and the host site returned to its preprogram condition.

  6. Surface Area, Volume, Mass, and Density Distributions for Sized Biomass Particles

    SciTech Connect (OSTI)

    Ramanathan Sampath

    2007-06-30T23:59:59.000Z

    This final technical report describes work performed at Morehouse College under DOE Grant No. DE-FC26-04NT42130 during the period July 01, 2004 to June 30, 2007 which covers the entire performance period of the project. 25 individual biomass particles (hardwood sawdust AI14546 in the size range of 100-200 microns) were levitated in an electrodynamic balance (EDB) and their external surface area, volume, and drag coefficient/mass (C{sub d}/m) ratios were characterized applying highly specialized video based and high-speed diode array imaging systems. Analysis methods were employed using shape and drag information to calculate mass and density distributions for these particles. Results of these measurements and analyses were validated by independent mass measurements using a particle weighing and counting technique. Similar information for 28 PSOC 1451D bituminous coal particles was retrieved from a previously published work. Using these two information, density correlations for coal/biomass blends were developed. These correlations can be used to estimate the density of the blend knowing either the volume fraction or the mass fraction of coal in the blend. The density correlations presented here will be useful in predicting the burning rate of coal/biomass blends in cofiring combustors. Finally, a discussion on technological impacts and economic projections of burning biomass with coal in US power plants is presented.

  7. Coal diesel combined-cycle project. Comprehensive report to Congress: Clean Coal Technology Program

    SciTech Connect (OSTI)

    Not Available

    1994-05-01T23:59:59.000Z

    One of the projects selected for funding is a project for the design, construction, and operation of a nominal 90 ton-per-day 14-megawatt electrical (MWe), diesel engine-based, combined-cycle demonstration plant using coal-water fuels (CWF). The project, named the Coal Diesel Combined-Cycle Project, is to be located at a power generation facility at Easton Utilities Commission`s Plant No. 2 in Easton, Talbot County, Maryland, and will use Cooper-Bessemer diesel engine technology. The integrated system performance to be demonstrated will involve all of the subsystems, including coal-cleaning and slurrying systems; a selective catalytic reduction (SCR) unit, a dry flue gas scrubber, and a baghouse; two modified diesel engines; a heat recovery steam generation system; a steam cycle; and the required balance of plant systems. The base feedstock for the project is bituminous coal from Ohio. The purpose of this Comprehensive Report is to comply with Public Law 102-154, which directs the DOE to prepare a full and comprehensive report to Congress on each project selected for award under the CCT-V Program.

  8. Coal transformation chemistry. Second quarterly progress report, June 1, 1980-August 31, 1980

    SciTech Connect (OSTI)

    Stock, Leon M.; Alemany, L. B.; Handy, C. I.; King, H. -H.

    1980-01-01T23:59:59.000Z

    A review of the information concerning the structure of Illinois No. 6 coal obtained in this laboratory and elsewhere provides the basis for a proposed structure for this bituminous coal. All the available facts concerning reduction, reductive alkylation, hydrogen atom exchange, oxidation, functional group analysis and so forth have been used to define a structural segment consisting of about 1000 atoms with a molecular weight in excess of 6000. This work is discussed in Part A. The study of the reductive alkylation reaction of Illinois No. 6 coal in liquid ammonia has been directed toward the optimization of the reaction conditions for the achievement of maximum solubility. The latest results indicate that about 55% of the original Illinois No. 6 coal can be converted to products which are soluble in tetrahydrofuran using potassium in liquid ammonia as the reducing agent and n-butyl iodide in tetrahydrofuran as the reducing alkylating agent. These observations are treated in Part B. The effort on donor solvent coal chemistry was directed to the role played by pericyclic reactions in the liquefaction process. The reactivity of a number of donors has been examined including 1,2- and 1,4-dihydronaphthalene. Although the research is not yet complete, the preliminary results indicate that free radical processes occur preferentially. Thus, the pericyclic reactions appear to be unimportant at the threshold reaction temperatures of 350 to 425/sup 0/C. This work is described in Part C.

  9. Advanced Coal Conversion Process Demonstration Project

    SciTech Connect (OSTI)

    Not Available

    1992-04-01T23:59:59.000Z

    Western Energy Company (WECO) was selected by the Department of Energy (DOE) to demonstrate the Advanced Coal Conversion Process (ACCP) which upgrades low rank coals into high Btu, low sulfur, synthetic bituminous coal. As specified in the Corporate Agreement, RSCP is required to develop an Environmental Monitoring Plan (EMP) which describes in detail the environmental monitoring activities to be performed during the project execution. The purpose of the EMP is to: (1) identify monitoring activities that will be undertaken to show compliance to applicable regulations, (2) confirm the specific environmental impacts predicted in the National Environmental Policy Act documentation, and (3) establish an information base of the assessment of the environmental performance of the technology demonstrated by the project. The EMP specifies the streams to be monitored (e.g. gaseous, aqueous, and solid waste), the parameters to be measured (e.g. temperature, pressure, flow rate), and the species to be analyzed (e.g. sulfur compounds, nitrogen compounds, trace elements) as well as human health and safety exposure levels. The operation and frequency of the monitoring activities is specified, as well as the timing for the monitoring activities related to project phase (e.g. preconstruction, construction, commissioning, operational, post-operational). The EMP is designed to assess the environmental impacts and the environmental improvements resulting from construction and operation of the project.

  10. Advanced Coal Conversion Process Demonstration Project. Environmental Monitoring Plan

    SciTech Connect (OSTI)

    Not Available

    1992-04-01T23:59:59.000Z

    Western Energy Company (WECO) was selected by the Department of Energy (DOE) to demonstrate the Advanced Coal Conversion Process (ACCP) which upgrades low rank coals into high Btu, low sulfur, synthetic bituminous coal. As specified in the Corporate Agreement, RSCP is required to develop an Environmental Monitoring Plan (EMP) which describes in detail the environmental monitoring activities to be performed during the project execution. The purpose of the EMP is to: (1) identify monitoring activities that will be undertaken to show compliance to applicable regulations, (2) confirm the specific environmental impacts predicted in the National Environmental Policy Act documentation, and (3) establish an information base of the assessment of the environmental performance of the technology demonstrated by the project. The EMP specifies the streams to be monitored (e.g. gaseous, aqueous, and solid waste), the parameters to be measured (e.g. temperature, pressure, flow rate), and the species to be analyzed (e.g. sulfur compounds, nitrogen compounds, trace elements) as well as human health and safety exposure levels. The operation and frequency of the monitoring activities is specified, as well as the timing for the monitoring activities related to project phase (e.g. preconstruction, construction, commissioning, operational, post-operational). The EMP is designed to assess the environmental impacts and the environmental improvements resulting from construction and operation of the project.

  11. Coal Reburning for Cyclone Boiler NO{sub x} Control Demonstration. Quarterly report No. 10, July--September 1992

    SciTech Connect (OSTI)

    Not Available

    1992-12-18T23:59:59.000Z

    The Coal Reburning for Cyclone Boiler NO{sub x}, Control Demonstration project progress for July, August, and September 1992 is identified in this tenth quarterly report and pertains to the on-going activities of Phase III Operation and Disposition. The project involves retrofitting/testing the reburning technology at Wisconsin Power & Light`s 100 MWe Nelson Dewey Unit {number_sign}2 in Cassville, Wisconsin to determine the commercial applicability of this technology to reduce NO{sub x} emission levels. Phase III activities emphasized continuation of long-term testing. WP&L is operating the reburn system in full automatic in a load following mode, using Lamar coal, which is an Indiana bituminous medium sulfur content fuel. Reductions in NO{sub x} emissions continue at the 50%+ level with no apparent significant adverse impacts to boiler operation. As of the end of September, a second set of performance tests were initiated to determine if any performance impacts as a result of long-term operation have occurred. Data evaluation continued in an effort to design a testing sequence to more precisely evaluate reburn impact on unburned carbon. These tests will be carried out during the second set of performance tests in early October. Performance and mathematical modeling are being carried out to understand the cause of the reduction in furnace exit gas temperature observed during reburn testing on Lamar coal and to predict whether the same phenomenon will occur on future units where reburn technology is being considered.

  12. Coal Reburning for Cyclone Boiler NO[sub x] Control Demonstration

    SciTech Connect (OSTI)

    Not Available

    1992-12-18T23:59:59.000Z

    The Coal Reburning for Cyclone Boiler NO[sub x], Control Demonstration project progress for July, August, and September 1992 is identified in this tenth quarterly report and pertains to the on-going activities of Phase III Operation and Disposition. The project involves retrofitting/testing the reburning technology at Wisconsin Power Light's 100 MWe Nelson Dewey Unit [number sign]2 in Cassville, Wisconsin to determine the commercial applicability of this technology to reduce NO[sub x] emission levels. Phase III activities emphasized continuation of long-term testing. WP L is operating the reburn system in full automatic in a load following mode, using Lamar coal, which is an Indiana bituminous medium sulfur content fuel. Reductions in NO[sub x] emissions continue at the 50%+ level with no apparent significant adverse impacts to boiler operation. As of the end of September, a second set of performance tests were initiated to determine if any performance impacts as a result of long-term operation have occurred. Data evaluation continued in an effort to design a testing sequence to more precisely evaluate reburn impact on unburned carbon. These tests will be carried out during the second set of performance tests in early October. Performance and mathematical modeling are being carried out to understand the cause of the reduction in furnace exit gas temperature observed during reburn testing on Lamar coal and to predict whether the same phenomenon will occur on future units where reburn technology is being considered.

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

    SciTech Connect (OSTI)

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

    1991-11-01T23:59:59.000Z

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

  14. Comparison of salient features of alternative CO{sub 2} recovery processes

    SciTech Connect (OSTI)

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

    1994-06-01T23:59:59.000Z

    In the case of direct coal combustion, the recovery of carbon dioxide (CO{sub 2}) is complicated by dilution of the flue gas with nitrogen (N{sub 2}) from the combustion air, as well as with excess air, which invariably accompanies coal combustion. For a representative boiler using bituminous coal, the mole fraction of CO{sub 2} in the flue gas is in the range of 10--15%. For coal gasification, no excess air is provided. In fact, the air supplied is inadequate for complete combustion. The mole fraction of carbon monoxide (CO) plus CO{sub 2} in the fuel gas from the Kellogg-Rust-Westinghouse (KRW) gasifier, which is the gasifier for which these CO{sub 2} recovery processes are designed, is about 22% for an air-blown gasifier and 59.1% for an oxygen-blown gasifier. The CO can be converted to CO{sub 2} via the water-gas shift reaction. Because of the higher CO{sub 2} partial pressure, recovery of the CO{sub 2} from this shifted synthesis gas requires a less costly recovery system than that which would be required for recovery following direct coal combustion in air. This analysis is intended to provide a first-order estimate of the effects of CO{sub 2} recovery on the cost and performance of a gasifier and to compare these effects for common commercial CO{sub 2} recovery processes.

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

    SciTech Connect (OSTI)

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

    1991-11-01T23:59:59.000Z

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

  16. DEVELOPMENT OF CONTINUOUS SOLVENT EXTRACTION PROCESSES FOR COAL DERIVED CARBON PRODUCTS

    SciTech Connect (OSTI)

    Elliot Kennel; Chong Chen; Dady Dadyburjor; Mark Heavner; Manoj Katakdaunde; Liviu Magean; James Mayberry; Alfred Stiller; Joseph Stoffa; Christopher Yurchick; John Zondlo

    2009-12-31T23:59:59.000Z

    This NETL sponsored effort seeks to develop continuous technologies for the production of carbon products, which may be thought of as the heavier products currently produced from refining of crude petroleum and coal tars obtained from metallurgical grade coke ovens. This effort took binder grade pitch, produced from liquefaction of West Virginia bituminous grade coal, all the way to commercial demonstration in a state of the art arc furnace. Other products, such as crude oil, anode grade coke and metallurgical grade coke were demonstrated successfully at the bench scale. The technology developed herein diverged from the previous state of the art in direct liquefaction (also referred to as the Bergius process), in two major respects. First, direct liquefaction was accomplished with less than a percent of hydrogen per unit mass of product, or about 3 pound per barrel or less. By contrast, other variants of the Bergius process require the use of 15 pounds or more of hydrogen per barrel, resulting in an inherent materials cost. Second, the conventional Bergius process requires high pressure, in the range of 1500 psig to 3000 psig. The WVU process variant has been carried out at pressures below 400 psig, a significant difference. Thanks mainly to DOE sponsorship, the WVU process has been licensed to a Canadian Company, Quantex Energy Inc, with a commercial demonstration unit plant scheduled to be erected in 2011.

  17. Effects of temperature and acidic pre-treatment on Fenton-driven oxidation of MTBE-spent granular activated carbon

    SciTech Connect (OSTI)

    Kan, E.; Huling, S.G. [Robert S. Kerr Environmental Research Center, Ada, OK (United States)

    2009-03-01T23:59:59.000Z

    The effects of temperature and acidic pretreatment on Fenton-driven chemical oxidation of methyl tert-butyl ether (MTBE)-spent granular activated carbon (GAC, derived from bituminous coal) were investigated. Limiting factors in MTBE removal in GAC include the heterogeneous distribution of amended Fe, and slow intraparticle diffusive transport of MTBE and hydrogen peroxide (H{sub 2}O{sub 2}) into the 'reactive zone'. Acid pretreatment of GAC before Fe amendment altered the surface chemistry of the GAC, lowered the pH point of zero charge, and resulted in greater penetration and more uniform distribution of Fe in GAC. This led to a condition where Fe, MTBE, and H{sub 2}O{sub 2} coexisted over a larger volume of the GAC contributing to greater MTBE oxidation and removal. H{sub 2}O{sub 2} reaction and MTBE removal in GAC increased with temperature. Modeling H{sub 2}O{sub 2} transport and reaction in GAC indicated that H{sub 2}O{sub 2} penetration was inversely proportional with temperature and tortuosity, and occurred over a larger fraction of the total volume of small GAC particles (0.3 mm diameter) relative to large particles (1.2 mm diameter). Acidic pretreatment of GAC, Fe-amendment, elevated reaction temperature, and use of small GAC particles are operational parameters that improve Fenton-driven oxidation of MTBE in GAC. 29 refs., 6 figs., 1 tab.

  18. Cross-shift peak expiratory flow changes are unassociated with respirable coal dust exposure among South African coal miners

    SciTech Connect (OSTI)

    Naidoo, R.N.; Robins, T.G.; Becklake, M.; Seixas, N.; Thompson, M.L. [University of KwaZulu Natal, Durban (South Africa)

    2007-12-15T23:59:59.000Z

    he objectives of this study were to determine whether cross-shift changes in peak expiratory flow rate (PEFR) were related to respirable dust exposure in South African coalminers. Fifty workers were randomly selected from a cohort of 684 miners from 3 bituminous coal mines in Mpumalanga, South Africa. Peak expiratory efforts were measured prior to the commencement of the shift, and at the end of the shift on at least two occasions separated by at least 2 weeks, with full shift personal dust sampling being conducted on each occasion for each participant. Interviews were conducted, work histories were obtained and cumulative exposure estimates were constructed. Regression models examined the associations of cross-shift changes in PEFR with current and cumulative exposure, controlling for shift, smoking and past history of tuberculosis. There were marginal differences in cross-shift PEFR (ranging from 0.1 to 2 L/min). Linear regression analyses showed no association between cross-shift change in PEFR and current or cumulative exposure. The specific shift worked by participants in the study showed no effect. Our study showed no association between current respirable dust exposure and cross-shift changes in PEFR. There was a non-significant protective effect of cumulative dust exposure on the outcome, suggesting the presence of a 'healthy worker survivor effect' in this data.

  19. Pulverization Induced Charge: In-Line Dry Coal Cleaning

    SciTech Connect (OSTI)

    Schaefer, J.L.; Stencel, J.M.

    1997-05-13T23:59:59.000Z

    The technical feasibility of separating mineral matter and pyrite from coal as it is transported from pulverizers to boilers in pulverized coal combustion units will be examined. The charge imparted on coal during pulverization and transport to pulverized coal (PC) burners in a utility boiler will be quantified. In addition to field charge measurements, an existing computational model will be extended to numerically simulate charged particle motion in a turbulent gas through an electric field. Results from the field tests and numerical modeling will be employed in design and construction of a laboratory scale pulverizer/classifier. This laboratory unit will be used to quantify the magnitude and differential charge imparted on bituminous and subbituminous coals during pulverization and classification at temperatures and with gaseous constituents typical to utility PC units. An electrostatic separator, designed for in-line operation between pulverizers and PC boilers, will be used to clean prepulverized coals. Theoretical and experimental data are to be used in preparing a preliminary design for a full-scale, (15 ton/hr) in-line, electrostatic coal cleaning device. Finally, the economic potential for application to PC units will be assessed.

  20. PULVERIZATION INDUCED CHARGE: IN-LINE DRY COAL CLEANING

    SciTech Connect (OSTI)

    JOHN M. STENCEL

    1998-07-01T23:59:59.000Z

    The technical feasibility of separating mineral matter and pyrite from coal as it is transported from pulverizers to burners in pulverized coal combustion units will be examined. The charge imparted on coal during pulverization and transport to pulverized coal (PC) burners in a utility boiler will be quantified. In addition to field charge measurements, an existing computational model will be extended to numerically simulate charged particle motion in a turbulent gas through an electric field. Results from the field tests and numerical modeling will be employed in design and construction of a laboratory scale pulverizer/classifier. This laboratory unit will be used to quantify the magnitude and differential charge imparted on bituminous and subbituminous coals during pulverization and classification at temperatures and with gaseous constituents typical to utility PC units. An electrostatic separator, designed for in-line operation between pulverizers and PC boilers, will be used to clean prepulverized coals. Theoretical and experimental data are to be used in preparing a preliminary design for a full-scale, (15 ton/hr) in-line, electrostatic coal cleaning device. Finally, the economic potential for application to PC units will be assessed.

  1. Pulverization Induced Charge: In-Line Dry Coal Cleaning

    SciTech Connect (OSTI)

    John M. Stencel

    1998-05-26T23:59:59.000Z

    The technical feasibility of separating mineral matter and pyrite from coal as it is transported from pulverizers to burners in pulverized coal combustion units will be examined. The charge imparted on coal during pulverization and transport to pulverized coal (PC) burners in a utility boiler will be quantified. In addition to field charge measurements, an existing computational model will be extended to numerically simulate charged particle motion in a turbulent gas through an electric field. Results from the field tests and numerical modeling will be employed in design and construction of a laboratory scale pulverizer/classifier. This laboratory unit will be used to quantify the magnitude and differential charge imparted on bituminous and subbituminous coals during pulverization and classification at temperatures and with gaseous constituents typical to utility PC units. An electrostatic separator, designed for in-line operation between pulverizers and PC boilers, will be used to clean prepulverized coals. Theoretical and experimental data are to be used in preparing a preliminary design for a full-scale, (15 ton/hr) in-line, electrostatic coal cleaning device. Finally, the economic potential for application to PC units will be assessed.

  2. Petrology of Jurassic (Kimmeridgian) coals, Atlantic Continental Shelf, New Jersey

    SciTech Connect (OSTI)

    Hower, J.C.; Wild, G.D. (Univ. of Kentucky, Lexington, KY (United States))

    1993-08-01T23:59:59.000Z

    Ten coals of Kimmeridgian age were recovered from the COST B-3 borehole, offshore New Jersey. Separation of the coal from other cuttings was done at 1.8 specific gravity, meaning that partings and mineral-rich lithotypes were lost in processing. The coals are distributed over an interval of 3.49 to 3.93 km depth. Coal rank, by vitrinite maximum reflectance, spans the lower portion of the high volatile A bituminous range. A single Cretaceous coal with 0.32%R[sub max] occurs at 2.08 km depth. Vitrinite content ranges from 51 to over 90% with vitrinite content generally increasing upward in the section. Telinite with resinite cell fillings is an important vitrinite form. Resinite occurs in concentrations of up to 9% in the Jurassic coals and is nearly 12% in the Cretaceous lignite. Fusinite plus semifusinite ranges from 2 to 31%. Inertinite occurs in a wide variety of forms from low-reflectance semifusinite to massive, structureless fusinite. Inertodetrinite also is a component of the abundant detrital bands of some of the Jurassic coals. The gravity separation did not eliminate all mineral matter. Massive pyrite and marcasite occur in several coals and clay occurs with the detrital minerals.

  3. Pulverization Induced Charge: In-Line Dry Coal Cleaning

    SciTech Connect (OSTI)

    John M. Stencel

    1998-01-21T23:59:59.000Z

    The technical feasibility of separating mineral matter and pyrite from coal as it is transported from pulverizers to burners in pulverized coal combustion units will be examined. The charge imparted on coal during pulverization and transport to pulverized coal (PC) burners in a utility boiler will be quantified. In addition to field charge measurements, an existing computational model will be extended to numerically simulate charged particle motion in a turbulent gas through an electric field. Results from the field tests and numerical modeling will be employed in design and construction of a laboratory scale pulverizer/classifier. This laboratory unit will be used to quantify the magnitude and differential charge imparted on bituminous and subbituminous coals during pulverization and classification at temperatures and with gaseous constituents typical to utility PC units. An electrostatic separator, designed for in-line operation between pulverizers and PC boilers, will be used to clean prepulverized coals. Theoretical and experimental data are to be used in preparing a preliminary design for a full-scale, (15 ton/hr) in-line, electrostatic coal cleaning device. Finally, the economic potential for application to PC units will be assessed.

  4. Influence of conversion to low NO{sub x} combustion on fly ash petrology and mineralogy: A case study

    SciTech Connect (OSTI)

    Robl, T.L.; Hower, J.C.; Graham, U.M.; Rathbone, R.F. [Univ. of Kentucky, Lexington, KY (United States). Center for Applied Energy Research; Medina, S.S. [East Kentucky Power Cooperative, Winchester, KY (United States)

    1995-12-31T23:59:59.000Z

    The wall-fired 116 MW unit 2 at the John Sherman Cooper Station, Pulaski County, Kentucky, was converted to low-NO{sub x} combustion in the winter of 1993--1994. The fly ash from before and after conversion was studied in detail. The coal feed, which did not change significantly over the study, was from southeastern Kentucky and had an ash range of 10--12% and a sulfur range of 1.5--1.9%. The coal rank was high volatile bituminous A with a vitrinite reflectance (R{sub max}) of about 0.8%. The coal had about 17% by volume inertinite macerals (mineral-free basis). The fly ash carbon can be divided into three types: anisotropic coke, isotropic coke and inertinite. The post-conversion fly ash has nearly twice the amount of carbon as the pre-conversion ash and shows an increase in anisotropic coke. Mullite and quartz were observed petrographically to be more abundant in the post-conversion fly ash, although only the mullite increase was confirmed by XRD. The proportion of glass is slightly less in the post-conversion ash and is accompanied by one-third drop in the amount of cenospheres.

  5. Low-Cost Options for Moderate Levels of Mercury Control

    SciTech Connect (OSTI)

    Sharon Sjostrom

    2006-03-31T23:59:59.000Z

    On March 15, 2005, EPA issued the Clean Air Mercury Rule, requiring phased-in reductions of mercury emissions from electric power generators. ADA-ES, Inc., with support from DOE/NETL and industry partners, is conducting evaluations of EPRI's TOXECON II{trademark} process and of high-temperature reagents and sorbents to determine the capabilities of sorbent/reagent injection, including activated carbon, for mercury control on different coals and air emissions control equipment configurations. DOE/NETL targets for total mercury removal are {ge}55% (lignite), {ge}65% (subbituminous), and {ge}80% (bituminous). Based on work done to date at various scales, meeting the removal targets appears feasible. However, work needs to progress to more thoroughly document and test these promising technologies at full scale. This is the final site report for tests conducted at MidAmerican's Louisa Station, one of three sites evaluated in this DOE/NETL program. The other two sites in the program are MidAmerican's Council Bluff Station and Entergy's Independence Station. MidAmerican's Louisa Station burns Powder River Basin (PRB) coal and employs hot-side electrostatic precipitators with flue gas conditioning for particulate control. This part of the testing program evaluated the effect of reagents used in the existing flue gas conditioning on mercury removal.

  6. Results of the PDF{trademark} test burn at Clifty Creek Station

    SciTech Connect (OSTI)

    Johnson, S.A.; Knottnerus, B.

    1996-10-01T23:59:59.000Z

    Process Derived Fuel (PDF{sup TM}) from the ENCOAL process is different from other coals used to generate steam for the power industry. Although PDF{sup TM} is currently produced from Powder River Basin (PRB) subbituminous coal, the coal structure changes during processing. Compared to the parent coal, PDF{sup TM} contains much less moisture and slightly lower volatile matter resulting in a higher heating value and higher ash per million Btu. These coal properties can potentially benefit utility boiler performance. Combining the high combustion reactivity typical of PRB coals with significantly reduced moisture should produce higher flame zone temperatures and shorter flames. As a result, some boilers may experience increased steam production, better burnout, or lower excess air. The objective of the work contracted to Quinapoxet Engineering was to quantify the impacts of burning PDF{sup TM} on boiler performance at Clifty Creek Unit 3. A unique optical temperature monitor called SpectraTemp was used to measure changes in furnace exit gas temperature (FEGT) with time and boiler operating parameters for both PDF{sup TM} blends as well as a baseline coal blend consisting of 60% PRB coal, 20% Ohio coal, and 20% low-volatile eastern bituminous coal from Virginia. FEGT was then related to net plant heat rate, NO{sub x} emissions, and electrostatic precipitator performance.

  7. Sampling of power plant stacks for air toxic emissions: Final report for Phases 1 and 2

    SciTech Connect (OSTI)

    NONE

    1995-04-28T23:59:59.000Z

    A test program to collect and analyze size-fractionated stack gas particulate samples for selected inorganic hazardous air pollutants (HAPs) was conducted . Specific goals of the program are (1) the collection of one-gram quantities of size-fractionated stack gas particulate matter for bulk (total) and surface chemical characterization, and (2) the determination of the relationship between particle size, bulk and surface (leachable) composition, and unit load. The information obtained from this program identifies the effects of unit load, particle size, and wet FGD system operation on the relative toxicological effects of exposure to particulate emissions. Field testing was conducted in two phases. The Phase I field program was performed over the period of August 24 through September 20, 1992, at the Tennessee Valley Authority Widows Creek Unit 8 Power Station, located near Stevenson (Jackson County), Alabama, on the Tennessee River. Sampling activities for Phase II were conducted from September 11 through October 14, 1993. Widows Creek Unit 8 is a 575-megawatt plant that uses bituminous coal averaging 3.7% sulfur and 13% ash. Downstream of the boiler, a venture wet scrubbing system is used for control of both sulfur dioxide and particulate emissions. There is no electrostatic precipitator (ESP) in this system. This system is atypical and represents only about 5% of the US utility industry. However, this site was chosen for this study because of the lack of information available for this particulate emission control system.

  8. Fluidization characteristics of power-plant fly ashes and fly ash-charcoal mixtures. [MS Thesis; 40 references

    SciTech Connect (OSTI)

    Nguyen, C.T.

    1980-03-01T23:59:59.000Z

    As a part of the continuing research on aluminum recovery from fly ash by HiChlor process, a plexiglass fluidization column system was constructed for measurement of fluidization parameters for power-plant fly ashes and fly ash-charcoal mixtures. Several bituminous and subbituminous coal fly ashes were tested and large differences in fluidization characteristics were observed. Fly ashes which were mechanically collected fluidized uniformly at low gas flow rates. Most fly ashes which were electrostatically precipitated exhibited channeling tendency and did not fluidize uniformly. Fluidization characteristics of electrostatically collected ashes improve when the finely divided charcoal powder is added to the mixture. The fluidization of the mixture was aided initially by a mechanical stirrer. Once the fluidization had succeeded, the beds were ready to fluidize without the assistance of a mechanical action. Smooth fluidization and large bed expansion were usually observed. The effects of charcoal size and aspect ratio on fluidization characteristics of the mixtures were also investigated. Fluidization characteristics of a fly ash-coal mixture were tested. The mixture fluidized only after being oven-dried for a few days.

  9. Low-Rank Coal Grinding Performance Versus Power Plant Performance

    SciTech Connect (OSTI)

    Rajive Ganguli; Sukumar Bandopadhyay

    2008-12-31T23:59:59.000Z

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

  10. Coal upgrading program for Usti nad Labem, Czech Republic: Task 8.3. Topical report, October 1994--August 1995

    SciTech Connect (OSTI)

    Young, B.C.; Musich, M.A.

    1995-10-01T23:59:59.000Z

    Coal has been a major energy source in the Czech Republic given its large coal reserves, especially brown coal and lignite (almost 4000 million metric tons) and smaller reserves of hard, mainly bituminous, coal (over 800 million tons). Political changes since 1989 have led to the reassessment of the role of coal in the future economy as increasing environmental regulations affect the use of the high-sulfur and high-ash brown coal and lignite as well as the high-ash hard coal. Already, the production of brown coal has declined from 87 million metric tons per year in 1989 to 67 million metric tons in 1993 and is projected to decrease further to 50 million metric tons per year of brown coal by the year 2000. As a means of effectively utilizing its indigenous coal resources, the Czech Republic is upgrading various technologies, and these are available at different stages of development, demonstration, and commercialization. The purpose of this review is to provide a database of information on applicable technologies that reduce the impact of gaseous (SO{sub 2}, NO{sub x}, volatile organic compounds) and particulate emissions from the combustion of coal in district and residential heating systems.

  11. Fate of trace elements in UK coals during gasification processes

    SciTech Connect (OSTI)

    Bushell, A.J.; Williamson, J. [Imperial College of Science, Technology and Medicine, London (United Kingdom)

    1996-12-31T23:59:59.000Z

    Five UK coals were selected to cover the range of mineral matter and ash contents typically encountered in UK bituminous coals. Trace element analysis was performed on both the whole coals and size separated fractions using ICP analysis for 21 trace elements, including Be, Cr, Co, Ni, As, Cd, Sb, Hg, and Pb, elements deemed to be the most environmentally hazardous. Small quantities of each coal were gasified in a laboratory gasifier in an atmosphere of N{sub 2} containing 15% O{sub 2}. Samples of bed ash, cyclone ash, and a fine gas-filtered ash were collected and analyzed to determine the partition of the trace elements between the gasification products. Mass balance calculations showed that the recovery of the trace elements varied from 20 to 97%; the low recovery of some trace elements highlighting the difficulties of collecting representative samples from a laboratory system. A parallel study on samples taken from a pilot plant gasifier showed significantly higher recovery rates, indicating the value of larger scale trials.

  12. Task 3.0: Advanced power systems. Semi-annual report, April 1--June 30, 1993

    SciTech Connect (OSTI)

    McCollor, D.P.; Zygarlicke, C.J.; Mann, M.D.; Willson, W.G.; Hurley, J.P.

    1993-07-01T23:59:59.000Z

    A variety of activities are incorporated into the Advanced Power Systems program. Tasks included are (1) fuel utilization properties, (2) pressurized combustion, (3) catalytic gasification, and (4) hot-gas cleanup. ATRAN is stochastic and combines initial coal inorganics in a random manner in order to predict the resulting fly ash particle size and composition. ASHPERT, is an expert system yielding a first-order estimate of fly ash size and composition. Both models are designed to emulate pulverized-coal combustion. Input data required include identity, chemistry, size, quantity, and mineral-to-coal associations. The pressurized combustion task has focused on the construction of a versatile reactor system to simulate pressurized fluidized-bed combustion. Both castable and monolithic refractories have been investigated in determining slag prevention under a variety of conditions. Catalytic gasification coupled with a molten carbonate fuel cell offers an extremely efficient and environmentally sound power generating system using coal. Work with an Illinois No. 6 bituminous coal has not been successful. Continued efforts will focus on using the more reactive low-rank coals to try to achieve this goal. Hot-gas cleanup is the critical issue in many of the proposed advanced power system operations on coal. The key to successful ash removal is an understanding of the properties of the ash to be collected as well as the interactions of this material with the barrier itself. The knowledge base under development will assist in assessing many of these barrier material issues for a variety of coal ashes.

  13. Geologic evaluation of critical production parameters for coalbed methane resources. Part 2. Black Warrior Basin. Annual report, August 1987-July 1988

    SciTech Connect (OSTI)

    Epsman, M.L.; Wilson, G.V.; Pashin, J.C.; Tolson, J.S.; Ward, W.E.

    1988-12-01T23:59:59.000Z

    Coal in the Brookwood and Oak Grove fields in Alabama generally ranges from low- to medium-volatile bituminous rank. Lithologic and stratigraphic evidence indicates that the coal was deposited in structurally influenced alluvial environments. Coal beds are thickest and easily mined on structurally stable, uplifted fault block and the coal beds thin and split in the more heavily faulted downdropped areas, which are amenable to coalbed degasification. In Brookwood field, mine dewatering and deep degasification zones may act in concert, causing upward movement of saline water along faults. In Oak Grove field, mine dewatering evidently creates areas of low fluid pressure and promotes downward movement of fresh water along faults. Production of methane is greatest in wells producing the most water. The method of well stimulation is of minor importance in Brookwood field, however, in Oak Grove field the water-sand-fracture method gives the highest initial-production rate. High-yield wells are located close to faults and lineaments. Lower productivity in Brookwood field may be related to venting of methane in nearby underground mines.

  14. Selenium And Arsenic Speciation in Fly Ash From Full-Scale Coal-Burning Utility Plants

    SciTech Connect (OSTI)

    Huggins, F.E.; Senior, C.L.; Chu, P.; Ladwig, K.; Huffman, G.P.; /Kentucky U. /Reaction Engin. Int. /Elect. Power Res. Inst., Palo Alto

    2007-07-09T23:59:59.000Z

    X-ray absorption fine structure spectroscopy has been used to determine directly the oxidation states and speciation of selenium and arsenic in 10 fly ash samples collected from full-scale utility plants. Such information is needed to assess the health risk posed by these elements in fly ash and to understand their behavior during combustion and in fly ash disposal options, such as sequestration in tailings ponds. Selenium is found predominantly as Se(IV) in selenite (SeO{sub 3}{sup 2-}) species, whereas arsenic is found predominantly as As(V) in arsenate (AsO{sub 4}{sup 3-}) species. Two distinct types of selenite and arsenate spectra were observed depending upon whether the fly ash was derived from eastern U.S. bituminous (Fe-rich) coals or from western subbituminous or lignite (Ca-rich) coals. Similar spectral details were observed for both arsenic and selenium in the two different types of fly ash, suggesting that the post-combustion behavior and capture of both of these elements are likely controlled by the same dominant element or phase in each type of fly ash.

  15. CHARACTERIZATION OF COAL COMBUSTION BY-PRODUCTS FOR THE RE-EVOLUTION OF MERCURY INTO ECOSYSTEMS

    SciTech Connect (OSTI)

    J.A. Withum; R.M. Statnick

    2001-09-01T23:59:59.000Z

    EPA and state environmental agencies are suggesting that mercury (Hg) in coal combustion by-products is re-emitted into local ecosystems by additional processing to final products (i.e., wallboard, etc.), by dissolution into groundwater, or by reactions with anaerobic bacteria. This perception may limit the opportunities to use coal combustion by-products in recycle/reuse applications. In this program, CONSOL Energy is conducting a comprehensive sampling and analytical program to address this concern. If the results of this work demonstrate that re-emissions of Hg from waste disposal and by-product utilization are over-stated, additional regulations regarding coal combustion, waste disposal, and waste material utilization will not be required. This will result in continued low energy cost that is beneficial to the national economy and stability of local economies that are dependent on coal. In this quarter, laboratory equipment was assembled and blank test runs were made, manufactured aggregate and spray dryer ash samples were collected and leached, and fly ash and FGD slurry samples from an Ohio bituminous coal-fired utility were collected for leaching.

  16. INVESTIGATION OF AMMONIA ADSORPTION ON FLY ASH DUE TO INSTALLATION OF SELECTIVE CATALYTIC REDUCTION SYSTEMS

    SciTech Connect (OSTI)

    G.F. Brendel; J.E. Bonetti; R.F. Rathbone; R.N. Frey Jr.

    2000-11-01T23:59:59.000Z

    This report summarizes an investigation of the potential impacts associated with the utilization of selective catalytic reduction (SCR) systems at coal-fired power plants. The study was sponsored by the U.S. Department of Energy Emission Control By-Products Consortium, Dominion Generation, the University of Kentucky Center for Applied Energy Research and GAI Consultants, Inc. SCR systems are effective in reducing nitrogen oxides (NOx) emissions as required by the Clean Air Act (CAA) Amendments. However, there may be potential consequences associated with ammonia contamination of stack emissions and combustion by-products from these systems. Costs for air quality, landfill and pond environmental compliance may increase significantly and the marketability of ash may be seriously reduced, which, in turn, may also lead to increased disposal costs. The potential impacts to air, surface water, groundwater, ash disposal, ash utilization, health and safety, and environmental compliance can not be easily quantified based on the information presently available. The investigation included: (1) a review of information and data available from published and unpublished sources; (2) baseline ash characterization testing of ash samples produced from several central Appalachian high-volatile bituminous coals from plants that do not currently employ SCR systems in order to characterize the ash prior to ammonia exposure; (3) an investigation of ammonia release from fly ash, including leaching and thermal studies; and (4) an evaluation of the potential impacts on plant equipment, air quality, water quality, ash disposal operations, and ash marketing.

  17. Pinon Pine Power Project. Annual report, January 1--December 31, 1996

    SciTech Connect (OSTI)

    NONE

    1997-12-31T23:59:59.000Z

    This annual report has been prepared to present the status of the Pinon Pine Power Project, a nominal 107 MWe (gross) coal-fired integrated gasification combined-cycle (IGCC) power plant addition to Sierra Pacific Power Company`s (SPPCo) system. This project will also serve as a demonstration project cost-shared by the US Department of Energy (DOE) and SPPCo under DOE`s Clean Coal Technology (CCT) Program. The goal of the CCT Program is to demonstrate advanced coal utilization technologies that are energy efficient, reliable and able to achieve substantial reductions in emissions as compared with existing coal technologies. The Pinon Pine Power Project will demonstrate an IGCC system utilizing the Kellogg-Rust-Westinghouse (KRW) fluidized-bed gasification process operating in an air-blown mode with in-bed desulfurization and hot gas clean-up with a western bituminous coal as the design fuel. Testing will also be performed on a high-sulfur eastern coal. The Pinon Pine Power Project will be constructed and operated at SPPCo`s Tracy Power Station, an existing power generation facility located on a rural 724-acre plot approximately 17 miles east of Reno, NV. This new unit is designated as Tracy Unit No. 4.

  18. Pinon Pine Power Project. Annual report, August 1992--December 1993

    SciTech Connect (OSTI)

    NONE

    1994-11-01T23:59:59.000Z

    This annual report has been prepared to present the status of the Pinon Pine Power Project, a nominal 104 MWe (gross) integrated gasification combined-cycle (IGCC) power plant addition to Sierra Pacific Power Company`s (SPPCo) system. This project will also serve as a demonstration project cost-shared by the US Department of Energy (DOE) and SPPCo under DOE`s Clean Coal Technology (CCT) Program. The goal of the CCT Program is to demonstrate advanced coal utilization technologies that are energy efficient and reliable and that are able to achieve substantial reductions in emissions as compared with existing coal technologies. The Pinon Pine Power Project will demonstrate an IGCC system utilizing the Kellogg-Rust-Westinghouse (KRW) fluidized-bed gasification process operating in an air-blown mode with in-bed desulfurization and hot gas clean-up with a western bituminous coal. The Pinon Pine Power Project will be constructed and operated at SPPCo`s Tracy Power Station, an existing power generation facility located on a rural 724-acre plot approximately 17 miles east of Reno, NV.

  19. Studies of burial metamorphism in the Cretaceous sediments of the Southern Benue Trough and Anambra, Basin, Nigeria

    SciTech Connect (OSTI)

    Akande, S.O. [Univ. of Ilorin (Nigeria); Erdtmann, B.D. [Technical Univ., Berlin (Germany)

    1995-08-01T23:59:59.000Z

    Organic matter reflectance, illite crystallinity and fluid inclusion techniques are applied to the evaluation of burial history of Cretaceous sediments in the southern Benue Trough and Anambra Basin. The successions are invaded by intrusives, volcanic rocks and intra-formational veins especially in the Albian sections of the Abakaliki anticline and sub-bituminous coals in the Lower Maastrichtian sections of the Anambra Basin. Vitrinite reflectance (Rm) data from exposed NW/SE sections from Enugu to Abakaliki are ca: .55% in the Lower Maastrichtian coals and shales, 0.67% in the Coniacian shales, 0.91 in the Turonian shales and 4.31% in the Albian shales. A corresponding decrease in illite crystallinity indices coupled with a decrease in the percentage of smectite from 30% to 0% (%S in I/S) was observed on the NW/SE section. Fluid inclusion temperatures from vein quartz in the Albian shales range from 170 to 250{degrees}C. Our data suggest that sediments in the study area were buried to ranks within and beyond the oil window at their present outcrop levels. Possibilities for Cretaceous targets should be sought in the deeper non emergent sections of the Benue Trough and the Anambra Basin.

  20. National Coal Quality Inventory (NACQI)

    SciTech Connect (OSTI)

    Robert Finkelman

    2005-09-30T23:59:59.000Z

    The U.S. Geological Survey (USGS) conducted the National Coal Quality Inventory (NaCQI) between 1999 and 2005 to address a need for quality information on coals that will be mined during the next 20-30 years. Collaboration between the USGS, State geological surveys, universities, coal burning utilities, and the coal mining industry plus funding support from the Electric Power Research Institute (EPRI) and the U.S. Department of Energy (DOE) permitted collection and submittal of coal samples for analysis. The chemical data (proximate and ultimate analyses; major, minor and trace element concentrations) for 729 samples of raw or prepared coal, coal associated shale, and coal combustion products (fly ash, hopper ash, bottom ash and gypsum) from nine coal producing States are included. In addition, the project identified a new coal reference analytical standard, to be designated CWE-1 (West Elk Mine, Gunnison County, Colorado) that is a high-volatile-B or high-volatile-A bituminous coal with low contents of ash yield and sulfur, and very low, but detectable contents of chlorine, mercury and other trace elements.

  1. Market Assessment and Technical Feasibility Study of Pressurized Fluidized Bed Combustion Ash Use

    SciTech Connect (OSTI)

    Bland, A.E.; Brown, T.H. [Western Research Inst., Laramie, WY (United States)

    1996-12-31T23:59:59.000Z

    Western Research Institute in conjunction with the Electric Power Research Institute, Foster Wheeler Energy International, Inc. and the U.S. Department of Energy Technology Center (METC), has undertaken a research and demonstration program designed to examine the market potential and the technical feasibility of ash use options for pressurized fluidized bed combustion (PFBC) ashes. The assessment is designed to address six applications, including: (1) structural fill, (2) road base construction, (3) supplementary cementing materials in portland cement, (4) synthetic aggregate, and (5) agricultural/soil amendment applications. Ash from low-sulfur subbituminous coal-fired Foster Wheeler Energia Oy pilot circulating PFBC tests in Karhula, Finland, and ash from the high-sulfur bituminous coal-fired American Electric Power (AEP) bubbling PFBC in Brilliant, Ohio, were evaluated in laboratory and pilot-scale ash use testing. This paper addresses the technical feasibility of ash use options for PFBC unit using low- sulfur coal and limestone sorbent (karhula ash) and high-sulfur coal and dolomite sorbents (AEP Tidd ash).

  2. Performance simulation of fluidized-bed coal combustors

    SciTech Connect (OSTI)

    Chandran, R.R.; Sutherland, D.D. (The Babcock and Wilcox Co., R and D Div., Alliance, OH (US))

    1988-06-01T23:59:59.000Z

    A code, referred to as FBCSIM, is being developed to predict large-scale atmospheric fluidized-bed combustor (AFBC) performance with fundamental fuel data from bench-scale test units as input. This work is carried out as a part of AFBC fuels characterization program sponsored by the Electric Power Research Institute (EPRI). The code accounts for the physics of fluidization, which is unit specific, and the chemistry of combustion, which is fuel specific. The code includes a 3-D model and modules on bed hydrodynamics, chemical kinetics, solid distribution, and transport phenomena. The model for in-bed combustion incorporates a two-region particle mixing formulation. The code for in-bed combustion has been validated for different AFBC unit sizes (0.1, 2, and 20 MW) and different coals (two bituminous and a lignite). Sensitivity analyses have been carried out to identify the controlling variables and guide experimental work. Computer simulations have also been performed to delineate system response to operational parameters.

  3. Selecting fines recycle methods to optimize fluid bed combustor performance

    SciTech Connect (OSTI)

    Rickman, W.S.; Fields, D.E.; Brimhall, W.L.; Callahan, S.F.

    1980-05-01T23:59:59.000Z

    Testing and analysis of a number of different fines recycle methods for fluid bed combustors has led to a generalized modeling technique. This model accounts for the effect of pertinent variables in determining overall combustion efficiencies. Computer application of this model has allowed trade-off studies to be performed that show the overall process effects of changes in individual operating parameters. Verification of the model has been accomplished in processing campaigns while combusting fuels such as graphite and bituminous coal. A 0.4 MW test unit was used for the graphite experimental work. Solid fuel was typically crushed to 5 mm maximum screen size. Bed temperatures were normally controlled at 900/sup 0/C; the combustor was an atmospheric unit with maximum in-bed pressures of 0.2 atm. Expanded bed depths ranged from 1.5 to 3 meters. Additional data was taken from recycle tests sponsored by EPRI on the B and W 6 ft x 6 ft fluid bed combustor. These tests used high sulfur coal in a 1.2 meter deep, 850/sup 0/C atmospheric fluidized bed of limestone, with low recycle rates and temperatures. Close agreement between the model and test data has been noted, with combustion efficiency predictions matching experimental results within 1%.

  4. Polycyclic aromatic compounds in fluidized bed combustion of coal

    SciTech Connect (OSTI)

    Walsh, P.M.; Beer, J.M.; Biermann, K.; Chiu, K.S.

    1983-08-01T23:59:59.000Z

    Polycyclic aromatic compounds (PAC) have been determined in the gas and particulate effluents from fluidized bed combustion of coal, lignite, and oil shale by a number of investigators. A bibliography of the reports of these investigations is contained in a paper by Chiu, Walsh, Beer, and Biemann (1983). The concentrations of PAC in the effluents are often quite low, but depend upon the combustor configuration and operating conditions. The goal of the present investigation is to develop a mechanism consistent with measured rates of formation and destruction of PAC in atmospheric pressure fluidized bed combustion (AFBC), so that a rational approach may be taken to adjustment of conditions for minimization of PAC in the effluents. PAC are determined in samples taken from the freeboard (space above the bed), rather than from the exhaust, to observe the evolution of the PAC distribution within the combustor. Mass fractions of the most abundant PAC observed in the freeboard during AFBC of high volatile bituminous coal were reported by Chiu, et al (1983). Some correlation of the rates of disappearance of PAC with particle concentration was noted by Dutta, Chiu, Walsh, Beer, and Biemann (1983). In the present paper theoretical estimates of the rates at which PAC might be consumed by heterogeneous reactions are compared with experimental rates estimated from PAC profiles determined by Chiu et al (1983).

  5. Performance simulation of fluidized-bed coal combustors

    SciTech Connect (OSTI)

    Chandran, R.R.; Sutherland, D.D. (Babcock Wilcox Company, Alliance, OH (USA))

    1988-01-01T23:59:59.000Z

    A code, referred to as FBCSIM, is being developed to predict large-scale atmospheric fluidized-bed combustor (AFBC) performance with fundamental fuel data from bench-scale test units as input. This work is carried out as a part of AFBC fuels characterization program sponsored by the Electric Power Research Institute (EPRI). The code accounts for the physics of fluidization, which is unit specific, and the chemistry of combustion, which is fuel specific. The code includes a 3-D model and modules on bed hydrodynamics, chemical kinetics, solid distribution, and transport phenomena. The model for in-bed combustion incorporates a two-region particle mixing formulation. The code for in-bed combustion has been validated for different AFBC unit sizes (0.1, 2, and 20 MW) and different coals (two bituminous and a lignite). Sensitivity analyses have been carried out to identify the controlling variables and guide experimental work. Computer simulations have also been performed to delineate system response to operational parameters.

  6. Evaluating the status of the Texaco gasifier

    SciTech Connect (OSTI)

    Perry, H.

    1981-01-01T23:59:59.000Z

    Conclusions after a series of runs at steady state conditions in the pilot plant are: (1) Western Kentucky No. 9 coal (either run-of-mine or washed) can be gasified without pretreatment; (2) other coking bituminous coal may also be able to be gasified without pretreatment; (3) pretreatment is not required to achieve satisfactory ash agglomeration; (4) balanced ash agglomeration with satisfactory removal of the agglomerates has been achieved and stable operation of ash agglomeration is possible during periods of short upset; (5) solutions appear to have been found for prevention of clinkering and sintering by alternative venturi design, modification in the oxygen feed system and increasing the superficial velocity of the gas; (6) under certain circumstances fines recycle has been achieved with stable operation and fluidization; (7) the process can be operated at pressures up to 60 psig without adversely affecting other process parameters; (8) a wide range of operating conditions can be used while maintaining system operability; and (9) in a single test water cooling of the cyclone appears to prevent ash deposition on the cooled surfaces which confirms the experience of Westinghouse with ash deposition prevention in their fluidized bed gasifier. 11 references, 12 tables.

  7. Air-blown Integrated Gasification Combined Cycle demonstration project

    SciTech Connect (OSTI)

    Not Available

    1991-01-01T23:59:59.000Z

    Clean Power Cogeneration, Inc. (CPC) has requested financial assistance from DOE for the design construction, and operation of a normal 1270 ton-per-day (120-MWe), air-blown integrated gasification combined-cycle (IGCC) demonstration plant. The demonstration plant would produce both power for the utility grid and steam for a nearby industrial user. The objective of the proposed project is to demonstrate air-blown, fixed-bed Integrated Gasification Combined Cycle (IGCC) technology. The integrated performance to be demonstrated will involve all the subsystems in the air-blown IGCC system to include coal feeding; a pressurized air-blown, fixed-bed gasifier capable of utilizing caking coal; a hot gas conditioning systems for removing sulfur compounds, particulates, and other contaminants as necessary to meet environmental and combustion turbine fuel requirements; a conventional combustion turbine appropriately modified to utilize low-Btu coal gas as fuel; a briquetting system for improved coal feed performance; the heat recovery steam generation system appropriately modified to accept a NO{sub x} reduction system such as the selective catalytic reduction process; the steam cycle; the IGCC control systems; and the balance of plant. The base feed stock for the project is an Illinois Basin bituminous high-sulfur coal, which is a moderately caking coal. 5 figs., 1 tab.

  8. Development of an advanced, continuous mild gasification process for the production of co-products technical evaluation. Final report

    SciTech Connect (OSTI)

    Ness, R.O. Jr.; Runge, B.; Sharp, L.

    1992-11-01T23:59:59.000Z

    The University of North Dakota Energy and Environmental Research Center (EERC) and the AMAX Research and Development Center are cooperating in the development of a Mild Gasification process that will rapidly devolatilize coals of all ranks at relatively low temperatures between 930{degree} and 1470{degree}F (500{degree}and 800{degree}C) and near atmospheric pressure to produce primary products that include a reactive char, a hydrocarbon condensate, and a low-Btu gas. These will be upgraded in a ``coal refinery`` system having the flexibility to optimize products based on market demand. Task 2 of the four-task development sequence primarily covered bench-scale testing on a 10-gram thermogravimetric analyzer (TGA) and a 1 to 4-lb/hr continuous fluidized-bed reactor (CFBR). Tests were performed to determine product yields and qualities for the two major test coals-one a high-sulfur bituminous coal from the Illinois Basin (Indiana No. 3) and the other a low-sulfur subbituminous coal from the Powder River Basin (Wyodak). Results from Task 3, on product upgrading tests performed by AMAX Research and Development (R&D), are also reported. Task 4 included the construction, operation of a Process Research Unit (PRU), and the upgrading of the products. An economic evaluation of a commercial facility was made, based on the data produced in the PRU, CFBR, and the physical cleaning steps.

  9. Power Systems Development Facility Gasification Test Campaign TC17

    SciTech Connect (OSTI)

    Southern Company Services

    2004-11-30T23:59:59.000Z

    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.

  10. Development of an advanced, continuous mild gasification process for the production of co-products technical evaluation

    SciTech Connect (OSTI)

    Ness, R.O. Jr.; Runge, B.; Sharp, L.

    1992-11-01T23:59:59.000Z

    The University of North Dakota Energy and Environmental Research Center (EERC) and the AMAX Research and Development Center are cooperating in the development of a Mild Gasification process that will rapidly devolatilize coals of all ranks at relatively low temperatures between 930[degree] and 1470[degree]F (500[degree]and 800[degree]C) and near atmospheric pressure to produce primary products that include a reactive char, a hydrocarbon condensate, and a low-Btu gas. These will be upgraded in a coal refinery'' system having the flexibility to optimize products based on market demand. Task 2 of the four-task development sequence primarily covered bench-scale testing on a 10-gram thermogravimetric analyzer (TGA) and a 1 to 4-lb/hr continuous fluidized-bed reactor (CFBR). Tests were performed to determine product yields and qualities for the two major test coals-one a high-sulfur bituminous coal from the Illinois Basin (Indiana No. 3) and the other a low-sulfur subbituminous coal from the Powder River Basin (Wyodak). Results from Task 3, on product upgrading tests performed by AMAX Research and Development (R D), are also reported. Task 4 included the construction, operation of a Process Research Unit (PRU), and the upgrading of the products. An economic evaluation of a commercial facility was made, based on the data produced in the PRU, CFBR, and the physical cleaning steps.

  11. The application of soft X-ray microscopy to the in-situ analysis of sporopollenin/sporinite in a rank variable suite of organic rich sediments

    SciTech Connect (OSTI)

    Cody, G.D.; Botto, R.E. [Argonne National Lab., IL (United States). Chemistry Div.; Ade, H. [North Carolina State Univ., Raleigh, NC (United States). Dept. of Physics; Wirick, S. [State Univ. of New York, Stony Brook, NY (United States). Dept. of Physics

    1997-07-01T23:59:59.000Z

    Soft X-ray imaging and carbon near edge absorption fine structure spectroscopy (C-NEXAFS) has been used for the in-situ analysis of sporinite in a rank variable suite of organic rich sediments extending from recent up to high volatile A bituminous coal. The acquisition of chemically based images (contrast based on the 1s - 1{pi}* transition of unsaturated carbon), revealed a homogeneous chemical structure in the spore exine. C-NEXAFS microanalysis indicates chemical structural evolution in sporopollenin/sporinite with increases in maturation. The most significant change in the C-NEXAFS spectrum is an increase in unsaturated carbon, presumably aromatic, with rank. The rate of aromatization in sporinite exceeds that of the surrounding vitrinite. Increases in the concentration of unsaturated carbon are compensated by losses of aliphatic and hydroxylated aliphatic carbon components. Carboxyl groups are present in low and variable concentrations. Absorption due to carboxyl persists in the most mature specimen in this series, a high volatile A rank coal. The reactions which drive sporopollenin chemical structural evolution during diagenesis presumably involve dehydration, Diels-Alder cyclo-addition, and dehydrogenation reactions which ultimately lead to a progressively aromatized bio/geopolymer.

  12. Development and evaluation of coal/water mixture combustion technology. Final report

    SciTech Connect (OSTI)

    Scheffee, R.S.; Rossmeissl, N.P.; Skolnik, E.G.; McHale, E.T.

    1981-08-01T23:59:59.000Z

    The objective was to advance the technology for the preparation, storage, handling and combustion of highly-loaded coal/water mixtures. A systematic program to prepare and experimentally evaluate coal/water mixtures was conducted to develop mixtures which (1) burn efficiently using combustion chambers and burners designed for oil, (2) can be provided at a cost less than that of No. 6 oil, and (3) can be easily transported and stored. The program consisted of three principal tasks. The first was a literature survey relevant to coal/water mixture technology. The second involved slurry preparation and evaluation of rheological and stability properties, and processing techniques. The third consisted of combustion tests to characterize equipment and slurry parameters. The first task comprised a complete search of the literature, results of which are tabulated in Appendix A. Task 2 was involved with the evaluation of composition and process variables on slurry rheology and stability. Three bituminous coals, representing a range of values of volatile content, ash content, and hardness were used in the slurries. Task 3 was concerned with the combustion behavior of coal/water slurry. The studies involved first upgrading of an experimental furnace facility, which was used to burn slurry fuels, with emphasis on studying the effect on combustion of slurry properties such as viscosity and particle size, and the effect of equipment parameters such as secondary air preheat and atomization.

  13. Survey and conceptual flow sheets for coal conversion plant handling-preparation and ash/slag removal operations

    SciTech Connect (OSTI)

    Zapp, F.C.; Thomas, O.W.; Silverman, M.D.; Dyslin, D.A.; Holmes, J.M.

    1980-03-01T23:59:59.000Z

    This study was undertaken at the request of the Fossil Fuel Processing Division of the Department of Energy. The report includes a compilation of conceptual flow sheets, including major equipment lists, and the results of an availability survey of potential suppliers of equipment associated with the coal and ash/slag operations that will be required by future large coal conversion plant complexes. Conversion plant flow sheet operations and related equipment requirements were based on two representative bituminous coals - Pittsburgh and Kentucky No. 9 - and on nine coal conversion processes. It appears that almost all coal handling and preparation and ash/slag removal equipment covered by this survey, with the exception of some coal comminution equipment, either is on hand or can readily be fabricated to meet coal conversion plant capacity requirements of up to 50,000 short tons per day. Equipment capable of handling even larger capacities can be developed. This approach appears to be unjustified, however, because in many cases a reasonable or optimum number of trains of equipment must be considered when designing a conversion plant complex. The actual number of trains of equipment selected will be influenced by the total requied capacity of the complex, the minimum on-line capacity that can be tolerated in case of equipment failure, reliability of specific equipment types, and the number of reactors and related feed injection stations needed for the specific conversion process.

  14. A technique to control mercury from flue gas: The Thief Process

    SciTech Connect (OSTI)

    O'Dowd, W.J.; Pennline, H.W.; Freeman, M.C.; Granite, E.J.; Hargis, R.A.; Lacher, C.J.; Karash, A.

    2006-12-01T23:59:59.000Z

    The Thief Process is a mercury removal process that may be applicable to a broad range of pulverized coal-fired combustion systems. This is one of several sorbent injection technologies under development by the U.S. Department of Energy for capturing mercury from coal-fired electric utility boilers. A unique feature of the Thief Process involves the production of a thermally activated sorbent in situ at the power plant. The sorbent is obtained by inserting a lance, or thief, into the combustor, in or near the flame, and extracting a mixture of partially combusted coal and gas. The partially combusted coal or sorbent has adsorptive properties suitable for the removal of vapor-phase mercury at flue gas temperatures that are typical downstream of a power plant preheater. One proposed scenario, similar to activated carbon injection (ACI), involves injecting the extracted sorbent into the downstream ductwork between the air preheater and the particulate collection device of the power plant. Initial laboratory-scale and pilot-scale testing, using an eastern bituminous coal, focused on the concept validation. Subsequent pilot-scale testing, using a Powder River Basin (PRB) coal, focused on the process development and optimization. The results of the experimental studies, as well as an independent experimental assessment, are detailed. In addition, the results of a preliminary economic analysis that documents the costs and the potential economic advantages of the Thief Process for mercury control are discussed.

  15. Phase I: the pipeline-gas demonstration plant. Demonstration plant engineering and design. Volume 18. Plant Section 2700 - Waste Water Treatment

    SciTech Connect (OSTI)

    none,

    1981-05-01T23:59:59.000Z

    Contract No. EF-77-C-01-2542 between Conoco Inc. and the US Department of Energy provides for the design, construction, and operation of a demonstration plant capable of processing bituminous caking coals into clean pipeline quality gas. The project is currently in the design phase (Phase I). This phase is scheduled to be completed in June 1981. One of the major efforts of Phase I is the process and project engineering design of the Demonstration Plant. The design has been completed and is being reported in 24 volumes. This is Volume 18 which reports the design of Plant Section 2700 - Waste Water Treatment. The objective of the Waste Water Treatment system is to collect and treat all plant liquid effluent streams. The system is designed to permit recycle and reuse of the treated waste water. Plant Section 2700 is composed of primary, secondary, and tertiary waste water treatment methods plus an evaporation system which eliminates liquid discharge from the plant. The Waste Water Treatment Section is designed to produce 130 pounds per hour of sludge that is buried in a landfill on the plant site. The evaporated water is condensed and provides a portion of the make-up water to Plant Section 2400 - Cooling Water.

  16. The methods of steam coals usage for coke production

    SciTech Connect (OSTI)

    Korobetskii, I.A.; Ismagilov, M.S.; Nazimov, S.A.; Sladkova, I.L.; Shudrikov, E.S.

    1998-07-01T23:59:59.000Z

    Nowadays, high volatile bituminous coals are broadly used for metallurgical coke production in Russia. The share of such coals in the coking blend is variable from 20 to 40% by weight. There are some large coal deposits in Kuznetskii basin which have coals with low caking tendency. The low caking properties of such coals limit of its application in the coking process. At the same time the usage of low caking coals for coke production would allow flexibility of the feedstock for coke production. Preliminary tests, carried out in COAL-C's lab has shown some differences in coal properties with dependence on the size distribution. That is why the separation of the well-caking fraction from petrographically heterogeneous coals and its further usage in coking process may be promising. Another way for low caking coals application in the coke industry is briquettes production from such coals. This method has been known for a very long time. It may be divided into two possible directions. First is a direct coking of briquettes from the low caking coals. Another way is by adding briquettes to coal blends in defined proportion and combined coking. The possibility of application of coal beneficiation methods mentioned above was investigated in present work.

  17. Determination of the effects caused by different polymers on coal fluidity during carbonization using high-temperature {sup 1}H NMR and rheometry

    SciTech Connect (OSTI)

    Miguel Castro Diaz; Lucky Edecki; Karen M. Steel; John W. Patrick; Colin E. Snape [Nottingham University, Nottingham (United Kingdom). Nottingham Fuel and Energy Centre, School of Chemical, Environmental and Mining Engineering

    2008-01-15T23:59:59.000Z

    The effects of blending polyethylene (PE), polystyrene (PS), poly(ethyleneterephthalate) (PET), a flexible polyurethane (FPU), and a car shredded fluff waste (CSF) on fluidity development of a bituminous coal during carbonization have been studied by means of high-torque, small-amplitude controlled-strain rheometry and in situ high-temperature {sup 1}H NMR spectroscopy. The most detrimental effects were caused by PET and PS, which completely destroyed the fluidity of the coal. The CSF had a deleterious effect on coal fluidity similar to that of PET, although the deleterious effect on the viscoelastic properties of the coal were less pronounced than those of PET and PS. On the contrary, the addition of 10 wt % PE caused a slight reduction in the concentration of fluid hydrogen and an increase in the minimum complex viscosity, and the addition of 10 wt % FPU reduced the concentration of fluid hydrogen without changing the viscoelastic properties of the coal. Although these results suggest that these two plastics could potentially be used as additives in coking blends without compromising coke porosity, it was found that the semicoke strengths were reduced by adding 2 wt % FPU and 5 wt % PE. Therefore, it is unlikely that more than 2 wt % of a plastic waste could be added to a coal blend without deterioration in coke quality. 35 refs., 11 figs., 3 tabs.

  18. Novel bimetallic dispersed catalysts for temperature-programmed coal liquefaction. Final report

    SciTech Connect (OSTI)

    Chunshan Song; Schobert, H.H.; Parfitt, D.P. [and others

    1997-11-01T23:59:59.000Z

    Development of new catalysts is a promising approach to more efficient coal liquefaction. It has been recognized that dispersed catalysts are superior to supported catalysts for primary liquefaction of coals, because the control of initial coal dissolution or depolymerization requires intimate contact between the catalyst and coal. This research is a fundamental and exploratory study on catalytic coal liquefaction, with the emphasis on exploring novel bimetallic dispersed catalysts for coal liquefaction and the effectiveness of temperature-programmed liquefaction using dispersed catalysts. The primary objective of this research was to explore novel bimetallic dispersed catalysts from organometallic molecular precursors, that could be used in low concentrations but exhibit relatively high activity for efficient hydroliquefaction of coals under temperature-programmed conditions. We have synthesized and tested various catalyst precursors in liquefaction of subbituminous and bituminous coals and in model compound studies to examine how do the composition and structure of the catalytic precursors affect their effectiveness for coal liquefaction under different reaction conditions, and how do these factors affect their catalytic functions for hydrogenation of polyaromatic hydrocarbons, for cleavage of C-C bonds in polycyclic systems such as 4-(1-naphthylmethyl)bibenzyl, for hydrogenolysis of C-O bond such as that in dinaphthylether, for hydrodeoxygenation of phenolic compounds and other oxygen-containing compounds such as xanthene, and for hydrodesulfurization of polycyclic sulfur compounds such as dibenzothiophene. The novel bimetallic and monometallic precursors synthesized and tested in this project include various Mo- and Fe-based compounds.

  19. Structure, constitution and utilization of low rank Indian coal

    SciTech Connect (OSTI)

    Iyengar, M.S.; Iyengar, V.A. [M.S. Iyengar and Associates, New Delhi (India)

    1996-12-31T23:59:59.000Z

    This paper briefly reviews the work done on lignite and sub-bituminous coals. Surface area and moisture adsorption dependency on functional group is described. The role of hydrogen bonding in the briquetting of lignite and of alkyl groups in inducing caking properties are discussed. The dualistic behavior of abnormal coals as both a low and high rank coal is also discussed in relation to the nature of their sulphur groups. On the utilization side, processes are described for: (1) Utilization of non-caking coal in the reduction of iron ore. Coal is first briquetted using a lime-tar binder. It is then carbonized for reducing iron ore. The bar is recovered and recycled. (2) Production of carbon black from low rank coals. In this process, coal is carbonized at high temperature in a fluidized bed. Carbon black, for tire industry, is obtained with char as by-product. (3) Utilization of flue gases of industry is also discussed. In this new approach, the flue gas is reduced to synthesis gas by additional fuel and the inevitable surplus heat. The viability of the process is illustrated by details of a recent study in a cement plant. In addition to the above, the implication of recycling flue gas in automobile engines to make them more environment friendly and cost effective, is also discussed.

  20. Confined zone dispersion flue gas desulfurization demonstration. Quarterly report No. 10, February 17--May 31, 1993

    SciTech Connect (OSTI)

    Not Available

    1993-11-15T23:59:59.000Z

    The CZD process involves injecting a finely atomized slurry of reactive lime into the flue gas duct work of a coal-fired utility boiler. The principle of the confined zone is to form a wet zone of slurry droplets in the middle of the duct walls. The lime slurry reacts with part of the SO{sub 2} in the gas, and the reaction products dry to form solid particles. A solids collector, typically an electrostatic precipitator (ESP) downstream from the point of injection, captures the reaction products along with the fly ash entrained in the flue gas. The demonstration is being conducted at Penelec`s Seward Station, Unit No. 15. This boiler is a 147 MWe coal-fired unit, which utilizes Pennsylvania bituminous coal (approximately 1.2 to 2.5% sulfur). One of the two flue gas ducts leading from the boiler has been retrofitted with the CZD technology. The first existing ESP installed in the station is immediately behind the air preheater. The second ESP, installed about 15 years ago, is about 80 feet away from the first ESP. The goal of this demonstration is to prove the technical and economic feasibility of the CZD technology on a commercial scale. The process is expected to achieve 50% SO{sub 2}

  1. Studies of the combustion of coal/refuse derived fuels using thermogravimetric-Fourier transform infrared-mass spectrometry

    SciTech Connect (OSTI)

    Lu, H.; Li, J.; Lloyd, W.G. [and others

    1995-08-01T23:59:59.000Z

    The materials used in this project included two bituminous coals, a medium molecular weight PVC resin, cellulose, and shredded newspaper. Analytical data for the samples are given. A TA Instruments Model 951 Thermogravimetric Analyzer (TG) interfaced to a Perkin Elmer 1650 Fourier Transform Infrared Spectrometer (FTIR) was used in this study. The horizontal quartz furnace of the TG was connected to the 10 cm gas cell of the FTIR using an insulated teflon tube heated to a temperature of 150{degrees}C. The TG was also interfaced to a VG Thermolab Mass Spectrometer (MS) using a fused silica capillary sampling tube heated to approximately 170{degrees}C. A teflon splitter divides the gases from the TG into two parts, one to the FTIR ({approximately}95%), and the other to the MS ({approximately}5%). A schematic of the TG-FTIR-MS system, is presented. In the TG experiments, all samples ({approximately}300 mg each) were heated in air (50 ML/min) at a rate of 10{degrees}C/min to 700{degrees}C. The spectra and profiles of gaseous species evolving from the TG system were recorded and analyzed by the TGA-FTIR-MS analytical system. The results of the experiments are given.

  2. H-coal liquefaction: moving toward commercial reality

    SciTech Connect (OSTI)

    Schneiderman, S.J.

    1982-01-01T23:59:59.000Z

    The successful operation of the H-Coal pilot plant has allowed Ashland management to vigorously pursue the option to build a commercial plant. Ashland Synthetic Fuels has applied to the United States Synthetic Fuels Corporation for a loan guarantee to construct a commercial H-Coal liquefaction facility in Breckinridge County, Kentucky. Ashland would like to develop this project with four other partners. In November 1981, Bechtel Inc., joined Ashland in the development of the Breckinridge Project. Under this recent agreement, the two companies will cooperate to prepare a detailed project cost estimate, an environmental impact statement, secure the necessary permits, and form a joint venture group to facilitate the involvement of other companies to develop this facility. The future of the Breckinridge project depends completely on the United States Synthetic Fuels Corporation. If this government agency declines to supply the loan guarantees for this project there is little chance the facility will be built. Capital requirements have been estimated at $5,200,000,000. The proposed Breckinridge liquefaction facility would process 18,500 tons of high-sulphur bituminous coal per day and produce 50,000 barrels per day of liquid product.

  3. TVA`s Cumberland Units 1&2 SO{sub 2} removal system - an update

    SciTech Connect (OSTI)

    Buckner, J.H. [Tennessee Valley Authority, Chattanooga, TN (United States); Brodsky, I.S. [Raytheon Engineers & Constructors, Philadelphia, PA (United States); Muraskin, D.J. [ABB Environmental Systems, Birmingham, AL (United States)

    1995-06-01T23:59:59.000Z

    Tennessee Valley Authority`s Cumberland Fossil Plant (CUF) is a Phase I facility listed under the 1990 CAA Amendments. Units 1 & 2 are two 1300 MWe coal fired units which presently bum an eastern bituminous coal containing approximately 2.8% sulfur. The Flue Gas Desulfurization (FGD) system reduces sulfur dioxide (SO{sub 2}) emissions from Units 1 and 2 by means of wet limestone - forced oxidation scrubbing. The absorber modules were provided by ABB Environmental Systems (ABBES) with balance of plant engineering, construction management, and startup provided by Raytheon Engineers and Constructors (RE&C) under a partnership arrangement with TVA. The FGD systems for Unit 1 & 2 were brought on-line October 12, 1994 and December 14, 1994, respectively. This paper will present a brief description of the overall project, the design basis, challenging problems and solutions during construction and initial startup. Specific topics will include: (1) Optimization studies underway; (2) Unique design aspects of the facility; (3) A description of the absorber and supporting systems including the limestone barge unloader, ball mill system for reagent preparation, and draft system upgrades; and (4) Experience gained in management of a large project under the unique partnership agreement.

  4. Kinetics of coal pyrolysis and devolatilization

    SciTech Connect (OSTI)

    Not Available

    1986-01-01T23:59:59.000Z

    Research continued on coal devolatilization. Results are presented for rapid devolatilization experiments performed with the 20 -- 30 micron size cut of the reference coal - PSOC 1451D - a high volatile bituminous, Appalachian Province coal. In agreement with behavior observed in rapid, radiant transient heating experiments -flash lamp - and moderate heating rate - heated grid - experiments for the same coal, the devolatilization process is observed to occur in four distinct phases: intraparticle heavy hydrocarbon detachment and transport; heavy hydrocarbon desorption; low temperature reformation reactions producing light gases; high temperature secondary reactions of tars and char degassing. Mass fraction yields light fast yields and tar and char characteristics are presented for a range of reactor temperatures which support the phenomenological picture. A phenomenological model is presented which indicates the distinct phases of devolatilization and the importance of heat transfer conditions on both the overall rate of particle mass loss and the observable volatiles product distribution. The approach taken to model heat transfer conditions in each of the devolatilization reactors employed in the overall investigation is outlined. Predicted weight loss results are shown for three different sets of overall devolatilization kinetic parameters given heat transfer conditions in the UTRC Hot Wall - Hot Gas reactor. 47 figs., 1 tab.

  5. Co-production of electricity and alternate fuels from coal. Final report, August 1995

    SciTech Connect (OSTI)

    NONE

    1995-12-31T23:59:59.000Z

    The Calderon process and its process development unit, PDU, were originally conceived to produce two useful products from a bituminous coal: a desulfurized medium BTU gas containing primarily CO, H{sub 2}, CH{sub 4}, CO{sub 2}, and H{sub 2}O; and a desulfurized low BTU gas containing these same constituents plus N{sub 2} from the air used to provide heat for the process through the combustion of a portion of the fuel. The process was viewed as a means for providing both a synthesis gas for liquid fuel production (perhaps CH{sub 3}OH, alternatively CH{sub 4} or NH{sub 3}) and a pressurized, low BTU fuel gas, for gas turbine based power generation. The Calderon coal process comprises three principle sections which perform the following functions: coal pyrolysis in a continuous, steady flow unit based on coke oven technology; air blown, slagging, coke gasification in a moving bed unit based on a blast furnace technology; and a novel, lime pebble based, product gas processing in which a variety of functions are accomplished including the cracking of hydrocarbons and the removal of sulfur, H{sub 2}S, and of particulates from both the medium and low BTU gases. The product gas processing unit, based on multiple moving beds, has also been conceived to regenerate the lime pebbles and recover sulfur as elemental S.

  6. Use of molecular modeling to determine the interaction and competition of gases within coal for carbon dioxide sequestration

    SciTech Connect (OSTI)

    Jeffrey D. Evanseck; Jeffry D. Madura; Jonathan P. Mathews

    2006-04-21T23:59:59.000Z

    Molecular modeling was employed to both visualize and probe our understanding of carbon dioxide sequestration within a bituminous coal. A large-scale (>20,000 atoms) 3D molecular representation of Pocahontas No. 3 coal was generated. This model was constructed based on a the review data of Stock and Muntean, oxidation and decarboxylation data for aromatic clustersize frequency of Stock and Obeng, and the combination of Laser Desorption Mass Spectrometry data with HRTEM, enabled the inclusion of a molecular weight distribution. The model contains 21,931 atoms, with a molecular mass of 174,873 amu, and an average molecular weight of 714 amu, with 201 structural components. The structure was evaluated based on several characteristics to ensure a reasonable constitution (chemical and physical representation). The helium density of Pocahontas No. 3 coal is 1.34 g/cm{sup 3} (dmmf) and the model was 1.27 g/cm{sup 3}. The structure is microporous, with a pore volume comprising 34% of the volume as expected for a coal of this rank. The representation was used to visualize CO{sub 2}, and CH{sub 4} capacity, and the role of moisture in swelling and CO{sub 2}, and CH{sub 4} capacity reduction. Inclusion of 0.68% moisture by mass (ash-free) enabled the model to swell by 1.2% (volume). Inclusion of CO{sub 2} enabled volumetric swelling of 4%.

  7. LIMB Demonstration Project Extension

    SciTech Connect (OSTI)

    Not Available

    1991-09-15T23:59:59.000Z

    The basic goal of the Limestone Injection Multistage Burner (LIMB) demonstration is to extend LIMB technology development to a full- scale application on a representative wall-fired utility boiler. The successful retrofit of LIMB to an existing boiler is expected to demonstrate that (1) reductions of 50 percent or greater in SO{sub x} and NO{sub x} emissions can be achieved at a fraction of the cost of add-on FGD systems; (2) boiler reliability, operability, and steam production can be maintained at levels existing prior to LIMB retrofit; and (3) technical difficulties attributable to LIMB operation, such as additional slagging and fouling, changes in ash disposal requirements, and an increased particulate load, can be resolved in a cost-effective manner. The primary fuel to be used will be an Ohio bituminous coal having a nominal sulfur content of 3 percent or greater. The demonstration project consists of several distinct phases: a preliminary phase to develop the LIMB process design applicable to the host boiler, a construction and start-up phase, and an operating and evaluation phase. The first major activity, the development of the Edgewater LIMB design, was completed in January 1986 and detailed engineering is now complete. Major boiler-related components were installed during a September 1986 boiler outage. Start-up activities began in March of 1987 with tuning of the low NO{sub x} burners. Sorbent injection activities were underway as of July 1987. 3 figs.

  8. Cleavage of carbon-sulfur bonds in coal and substituted dibenzyl sulfides

    SciTech Connect (OSTI)

    Green, T.K.; Wang, L.; Estill, W.J.; Bixler, B. [Western Kentucky Univ., Bowling Green, KY (United States)

    1996-10-01T23:59:59.000Z

    S-methylation of a bituminous coal using {sup 13}C-enriched methyl iodide in the presence of silver tetrafluoroborate produces significant quantities of trimethylsulfonium ion as determined by {sup 13}C NMR. This result suggests that carbon-sulfur bonds in coal are being cleaved. In an effort to determine the types of structures in coal responsible for this ion, a series of model substituted dibenzyl sulfides were S-methylated. The substrates included 4,4{prime}dimethoxydibenzylsulfide (1), 4,4{prime}dimethyldibenzylsulfide (2), dibenzylsulfide (3), 4,4{prime}dichlorodibenzylsufide (4). All substrates are cleaved to varying degrees in refluxing DCE (83{degrees}C) to produce a mixture of methyldibenzyl-, dimethylbenzyl- and trimethylsulfonium ions. The relative amounts of these ions depends on the substituent, with the degree of C-S bond cleavage increasing with the electron-donating ability of the substituent in the order (1) > (2) > (3) > (4). A mechanism is proposed consistent with this substituent effect which involves an intermediate benzyl carbocation - sulfide ion-dipole complex.

  9. Production and Optimization of Direct Coal Liquefaction derived Low Carbon-Footprint Transportation Fuels

    SciTech Connect (OSTI)

    Steven Markovich

    2010-06-30T23:59:59.000Z

    This report summarizes works conducted under DOE Contract No. DE-FC26-05NT42448. The work scope was divided into two categories - (a) experimental program to pretreat and refine a coal derived syncrude sample to meet transportation fuels requirements; (b) system analysis of a commercial scale direct coal liquefaction facility. The coal syncrude was derived from a bituminous coal by Headwaters CTL, while the refining study was carried out under a subcontract to Axens North America. The system analysis included H{sub 2} production cost via six different options, conceptual process design, utilities requirements, CO{sub 2} emission and overall plant economy. As part of the system analysis, impact of various H{sub 2} production options was evaluated. For consistence the comparison was carried out using the DOE H2A model. However, assumptions in the model were updated using Headwaters database. Results of Tier 2 jet fuel specifications evaluation by the Fuels & Energy Branch, US Air Force Research Laboratory (AFRL/RZPF) located at Wright Patterson Air Force Base (Ohio) are also discussed in this report.

  10. Predictable SCR co-benefits for mercury control

    SciTech Connect (OSTI)

    Pritchard, S. [Cormtech Inc. (USA)

    2009-01-15T23:59:59.000Z

    A test program, performed in cooperation with Dominion Power and the Babcock and Wilcox Co., was executed at Dominion Power's Mount Storm power plant in Grant County, W. Va. The program was focused on both the selective catalytic reduction (SCR) catalyst capability to oxide mercury as well as the scrubber's capability to capture and retain the oxidized mercury. This article focuses on the SCR catalyst performance aspects. The Mount Storm site consists of three units totaling approximately 1,660 MW. All units are equipped with SCR systems for NOx control. A full-scale test to evaluate the effect of the SCR was performed on Unit 2, a 550 MWT-fired boiler firing a medium sulfur bituminous coal. This test program demonstrated that the presence of an SCR catalyst can significantly affect the mercury speciation profile. Observation showed that in the absence of an SCR catalyst, the extent of oxidation of element a mercury at the inlet of the flue gas desulfurization system was about 64%. The presence of a Cornertech SCR catalyst improved this oxidation to levels greater than 95% almost all of which was captured by the downstream wet FGD system. Cornertech's proprietary SCR Hg oxidation model was used to accurately predict the field results. 1 ref., 2 figs., 1 tab.

  11. Seminole Electric FGD study reveals corrosion mechanisms, duct material performance

    SciTech Connect (OSTI)

    Wess, T.J.; Crum, J.R.; Shoemaker, L.E.

    1994-12-01T23:59:59.000Z

    This article describes how once the corrosion rates of the materials used in the construction of scrubbers are known, specifying for longevity becomes an easier task. To properly evaluate the corrosion resistance of the materials used to fabricate the ducts, dampers, structural supports and other elements of a particular system, a testing scheme that systematically exposes material samples to the many environments representing areas of varying corrosivity is ideal. Because the exact composition, pH, and temperature of liquids and vapors in these areas are usually not known, gathering and analyzing samples of these elements is a prudent part of a systems' evaluation. Field testing of this type was conducted at the Seminole Generating Station which consists of two 650-MW coal-fired electric generating units that typically burn western Kentucky and eastern Illinois sub-bituminous coal with a sulfur content up to 3% and a 0.2%--0.3% chloride content. The plant has a typical wet limestone FGD system that sprays a solution of crushed limestone downward in a vertical rubber-lined scrubber module against a rising flue gas flow stream. There are five parallel scrubber modules available and a direct chimney bypass line that is used only during start up or during emergency conditions. Specially-welded test panels containing four different alloys and two weld filler metals were used in the field tests.

  12. Advanced emissions control development project. Phase I, Final report, November 1, 1993--February 19, 1996

    SciTech Connect (OSTI)

    NONE

    1996-02-29T23:59:59.000Z

    The primary objective of the Advanced Emissions Control Development Program (AECDP) is to develop practical, cost-effective strategies for reducing the emissions of air toxics from coal-fired boilers. Ideally, the project aim is to effectively control air toxic emissions through the use of conventional flue gas cleanup equipment such as electrostatic precipitators (ESP`s), fabric filters (baghouse), and wet flue gas desulfurization. B&W`s Clean Environment Development Facility (CEDF) and the AECDP equipment combined to form a state-of-the-art facility for integrated evaluation of combustion and post-combustion emissions control options. Phase 1 activities were primarily aimed at providing a reliable, representative test facility for conducting air toxic emissions control development work later in the project. This report summarizes the AECDP Phase I activities which consisted of the design, installation, shakedown, verification, and air toxics benchmarking of the AECDP facility. All verification and air toxic tests were conducted with a high sulfur, bituminous Ohio coal.

  13. Process for hydrocracking carbonaceous material in liquid carrier

    DOE Patents [OSTI]

    Duncan, Dennis A. (Downers Grove, IL)

    1980-01-01T23:59:59.000Z

    Solid carbonaceous material is hydrocracked to provide aliphatic and aromatic hydrocarbons for use as gaseous and liquid fuels or chemical feed stock. Particulate carbonaceous material such as coal in slurry with recycled product oil is preheated in liquid state to a temperature of 600.degree.-1200.degree. F. in the presence of hydrogen gas. The product oil acts as a sorbing agent for the agglomerating bitumins to minimize caking within the process. In the hydrocracking reactor, the slurry of oil and carbonaceous particles is heated within a tubular passageway to vaporize the oil and form a gas-solid mixture which is further heated to a hydropyrolysis temperature in excess of 1200.degree. F. The gas-solid mixture is quenched by contact with additional oil to condense normally liquid hydrocarbons for separation from the gases. A fraction of the hydrocarbon liquid product is recycled for quenching and slurrying with the carbonaceous feed. Hydrogen is recovered from the gas for recycle and additional hydrogen is produced by gasification of residual char.

  14. DOE Underground-Coal-Conversion-Program field-test activities for 1979 and 1980. [Pricetown 1, Hoe Creek 3, Hanna IV, and SDB 1

    SciTech Connect (OSTI)

    Bartke, T.C.

    1983-08-01T23:59:59.000Z

    Under the US Department of Energy's Underground-Coal-Conversion program, four field tests were completed in 1979 and preparations were begun in 1980 for two additional field tests to be operated in 1981. The Laramie Energy Technology Center (LETC) and Sandia National Laboratories (SNL) completed Hanna IV, an air gasification test in Wyoming subbituminous coal. The Morgantown Energy Technology Center (METC) completed Pricetown 1, an air gasification test in West Virginia bituminous coal. Lawrence Livermore National Laboratory (LLNL) completed Hoe Creek 3, a steam-oxygen gasification test in Wyoming subbituminous coal. Gulf Research and Development Co. completed Steeply Dipping Beds (SDB) Test 1, primarily an air gasification test in Wyoming subbituminous coal and the first SDB test in the US. In 1980, Gulf R and D Co. began preparation of SDB Test 2, scheduled for operation in the fall of 1981. The DOE project teams at LETC, METC, LLNL, and SNL, in association with the Washington Irrigation and Development Co. (WIDCo), Washington Water Power (WWP), and the State of Washington, are preparing a field test site in the Centralia-Chehalis coal district of Washington. A series of large coal block tests will be completed prior to the field test, scheduled for operation in 1982 or 1983. This field test will utilize a directionally drilled link and steam-oxygen gasification system. This paper summarizes the results of the four recently completed field tests and the plans for additional tests.

  15. Pricetown I underground coal gasification field test: operations report

    SciTech Connect (OSTI)

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

    1981-01-01T23:59:59.000Z

    An Underground Coal Gasification (UCG) field test in bituminous coal was successfully completed near Pricetown, West Virginia. The primary objective of this field test was to determine the viability of the linked vertical well (LVV) technology to recover the 900 foot deep, 6 foot thick coal seam. A methane rich product gas with an average heating value of approximately 250 Btu/SCF was produced at low air injection flow rates during the reverse combustion linkage phase. Heating value of the gas produced during the linkage enhancement phase was 221 Btu/SCF with air injection. The high methane formation has been attributed to the thermal and hydrocracking of tars and oils along with hydropyrolysis and hydrogasification of coal char. The high heating value of the gas was the combined effect of residence time, flow pattern, injection flow rate, injection pressure, and back pressure. During the gasification phase, a gas with an average heating value of 125 Btu/SCF was produced with only air injection, which resulted in an average energy production of 362 MMBtu/day.

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

    SciTech Connect (OSTI)

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

    1981-08-21T23:59:59.000Z

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

  17. Advanced emissions control development program: Phase 2 final report, February 29, 1996--August 31, 1997. Revision 1

    SciTech Connect (OSTI)

    Evans, A.P.; Holmes, M.J.; Redinger, K.E.

    1998-04-01T23:59:59.000Z

    The objective of the advanced emissions control development program (AECDP) is to develop practical, cost-effective strategies for reducing the emissions of air toxics from coal-fired boilers. Ideally, the project aim is to effectively control air toxic emissions through the use of conventional flue gas cleanup equipment such as electrostatic precipitators (ESPs), fabric filters (baghouse), and wet flue gas desulfurization. Development work to date has concentrated on the capture of mercury, other trace metals [antimony, arsenic, barium, cadmium, chromium, cobalt, lead, manganese, nickel, and selenium], fine particulate and hydrogen chloride. Some general comments that can be made about the control of air toxics while burning a high-sulfur bituminous coal are as follows: (1) particulate control devices such as ESP`s and baghouses do a good job of removing non-volatile trace metals; (2) mercury goes through particulate control devices almost entirely uncontrolled; (3) wet scrubbing can effectively remove hydrogen chloride; and (4) wet scrubbers show good potential for the removal of mercury when operated under certain conditions, however additional work is needed to understand the relationship between the wet scrubber`s operating conditions and mercury capture.

  18. Suppression of fine ash formation in pulverized coal flames. Quarterly technical progress report No. 11, April 1, 1995--June 30, 1995

    SciTech Connect (OSTI)

    Kramlich, J.C.; Chenevert, B.; Park, Jungsung

    1995-08-02T23:59:59.000Z

    Previous work has shown that pulverized bituminous coals that were treated by coal cleaning (via froth flotation) or aerodynamic sizing exhibited altered aerosol emission characteristics. Specifically, the emissions of aerosol for the cleaned and sized coals increased by as much as one order of magnitude. The goals of the present program are to: (1) perform measurements on carefully characterized coals to identify the means by which the coal treatment increases aerosol yields; (2) investigate means by which coal cleaning can be done in a way that will not increase aerosol yields; and (3) identify whether this mechanism can be used to reduce aerosol yields from systems burning straight coal. The current experimental series focuses on the use of artificial char to study sodium vaporization and aerosol formation associated with dispersed sodium and mineral inclusions. Artificial char has the advantage over natural coal in that the composition can be precisely controlled, such that the influences of specific mineral composition and content can be investigated. The study showed: the addition of calcite had no effect of the aerosol yield; increased amounts of pyrite did not lead to increased residual ash formation; in spite of the increase in mineral content, the yield of aerosol on the backup filter did not correlate with the amount of added minerals; and the general trend was for reduced aerosol yields as the amount of bentonite increased which suggested that the bentonite was effective at complexing sodium and reducing its overall vaporization.

  19. Suppression of fine ash formation in pulverized coal flames. Quarterly technical progress report No. 4, July 1, 1993--September 30, 1993

    SciTech Connect (OSTI)

    Kramlich, J.C.; Hoffman, D.A.; Butcher, E.K.

    1993-10-29T23:59:59.000Z

    Laboratory work and studies of full-scale coal-fired boilers have identified two general mechanisms for ash production. The vast majority of the ash is formed from mineral matter that coalesces as the char burns, yielding particles that are normally larger than 0.5 {mu}m. The second major mechanism is the generation of a submicron aerosol through a vaporization/condensation mechanism. Previous work has shown that pulverized bituminous coals that were treated by coal cleaning (via froth flotation) or aerodynamic sizing exhibited altered aerosol emission characteristics. Specifically, the emissions of aerosol for the cleaned and sized coals increased by as much as one order of magnitude. The goals of the present progress are to: (1) perform measurements on carefully characterized coals to identify the means by which the coal treatment increases aerosol yields; (2) investigate means by which coal cleaning can be done in a way that will not increase aerosol yields; (3) identify whether this mechanism can be used to reduce aerosol yields from systems burning straight coal. This paper discusses model description and model formulation, and reports on the progress of furnace design and construction, and coal selection.

  20. PULSE COMBUSTOR DESIGN QUALIFICATION TEST AND CLEAN COAL FEEDSTOCK TEST - VOLUME I AND VOLUME II

    SciTech Connect (OSTI)

    Unknown

    2002-02-08T23:59:59.000Z

    For this Cooperative Agreement, the pulse heater module is the technology envelope for an indirectly heated steam reformer. The field of use of the steam reformer pursuant to this Cooperative Agreement with DOE is for the processing of sub-bituminous coals and lignite. The main focus is the mild gasification of such coals for the generation of both fuel gas and char--for the steel industry is the main focus. An alternate market application for the substitution of metallurgical coke is also presented. This project was devoted to qualification of a 253-tube pulse heater module. This module was designed, fabricated, installed, instrumented and tested in a fluidized bed test facility. Several test campaigns were conducted. This larger heater is a 3.5 times scale-up of the previous pulse heaters that had 72 tubes each. The smaller heater has been part of previous pilot field testing of the steam reformer at New Bern, North Carolina. The project also included collection and reduction of mild gasification process data from operation of the process development unit (PDU). The operation of the PDU was aimed at conditions required to produce char (and gas) for the Northshore Steel Operations. Northshore Steel supplied the coal for the process unit tests.

  1. SYSTEM ANALYSIS OF NUCLEAR-ASSISTED SYNGAS PRODUCTION FROM COAL

    SciTech Connect (OSTI)

    E. A. Harvego; M. G. McKellar; J. E. O'Brien

    2008-09-01T23:59:59.000Z

    A system analysis has been performed to assess the efficiency and carbon utilization of a nuclear-assisted coal gasification process. The nuclear reactor is a high-temperature helium-cooled reactor that is used primarily to provide power for hydrogen production via high-temperature electrolysis. The supplemental hydrogen is mixed with the outlet stream from an oxygen-blown coal gasifier to produce a hydrogen-rich gas mixture, allowing most of the carbon dioxide to be converted into carbon monoxide, with enough excess hydrogen to produce a syngas product stream with a hydrogen/carbon monoxide molar ratio of about 2:1. Oxygen for the gasifier is also provided by the high-temperature electrolysis process. Results of the analysis predict 90.5% carbon utilization with a syngas production efficiency (defined as the ratio of the heating value of the produced syngas to the sum of the heating value of the coal plus the high-temperature reactor heat input) of 66.1% at a gasifier temperature of 1866 K for the high-moisture-content lignite coal considered. Usage of lower moisture coals such as bituminous can yield carbon utilization approaching 100% and 70% syngas production efficiency.

  2. Coal and nuclear power: Illinois' energy future

    SciTech Connect (OSTI)

    Not Available

    1982-01-01T23:59:59.000Z

    This conference was sponsored by the Energy Resources Center, University of Illinois at Chicago; the US Department of Energy; the Illinois Energy Resources Commission; and the Illinois Department of Energy and Natural Resources. The theme for the conference, Coal and Nuclear Power: Illinois' Energy Future, was based on two major observations: (1) Illinois has the largest reserves of bituminous coal of any state and is surpassed in total reserves only by North Dakota, and Montana; and (2) Illinois has made a heavy commitment to the use of nuclear power as a source of electrical power generation. Currently, nuclear power represents 30% of the electrical energy produced in the State. The primary objective of the 1982 conference was to review these two energy sources in view of the current energy policy of the Reagan Administration, and to examine the impact these policies have on the Midwest energy scene. The conference dealt with issues unique to Illinois as well as those facing the entire nation. A separate abstract was prepared for each of the 30 individual presentations.

  3. Update on use of mine pool water for power generation.

    SciTech Connect (OSTI)

    Veil, J. A.; Puder, M. G.; Environmental Science Division

    2006-09-30T23:59:59.000Z

    In 2004, nearly 90 percent of the country's electricity was generated at power plants using steam-based systems (EIA 2005). Electricity generation at steam electric plants requires a cooling system to condense the steam. With the exception of a few plants using air-cooled condensers, most U.S. steam electric power plants use water for cooling. Water usage occurs through once-through cooling or as make-up water in a closed-cycle system (generally involving one or more cooling towers). According to a U.S. Geological Survey report, the steam electric power industry withdrew about 136 billion gallons per day of fresh water in 2000 (USGS 2005). This is almost the identical volume withdrawn for irrigation purposes. In addition to fresh water withdrawals, the steam electric power industry withdrew about 60 billion gallons per day of saline water. Many parts of the United States are facing fresh water shortages. Even areas that traditionally have had adequate water supplies are reaching capacity limits. New or expanded steam electric power plants frequently need to turn to non-traditional alternate sources of water for cooling. This report examines one type of alternate water source-groundwater collected in underground pools associated with coal mines (referred to as mine pool water in this report). In 2003, the U.S. Department of Energy's (DOE's) National Energy Technology Laboratory (NETL) funded Argonne National Laboratory (Argonne) to evaluate the feasibility of using mine pool water in Pennsylvania and West Virginia. That report (Veil et al. 2003) identified six small power plants in northeastern Pennsylvania (the Anthracite region) that had been using mine pool water for over a decade. It also reported on a pilot study underway at Exelon's Limerick Generating Station in southeastern Pennsylvania that involved release of water from a mine located about 70 miles upstream from the plant. The water flowed down the Schuylkill River and augmented the natural flow so that the Limerick plant could withdraw a larger volume of river water. The report also included a description of several other proposed facilities that were planning to use mine pool water. In early 2006, NETL directed Argonne to revisit the sites that had previously been using mine pool water and update the information offered in the previous report. This report describes the status of mine pool water use as of summer 2006. Information was collected by telephone interviews, electronic mail, literature review, and site visits.

  4. TASK 3.4--IMPACTS OF COFIRING BIOMASS WITH FOSSIL FUELS

    SciTech Connect (OSTI)

    Christopher J. Zygarlicke; Donald P. McCollor; Kurt E. Eylands; Melanie D. Hetland; Mark A. Musich; Charlene R. Crocker; Jonas Dahl; Stacie Laducer

    2001-08-01T23:59:59.000Z

    With a major worldwide effort now ongoing to reduce greenhouse gas emissions, cofiring of renewable biomass fuels at conventional coal-fired utilities is seen as one of the lower-cost options to achieve such reductions. The Energy & Environmental Research Center has undertaken a fundamental study to address the viability of cofiring biomass with coal in a pulverized coal (pc)-fired boiler for power production. Wheat straw, alfalfa stems, and hybrid poplar were selected as candidate biomass materials for blending at a 20 wt% level with an Illinois bituminous coal and an Absaloka subbituminous coal. The biomass materials were found to be easily processed by shredding and pulverizing to a size suitable for cofiring with pc in a bench-scale downfired furnace. A literature investigation was undertaken on mineral uptake and storage by plants considered for biomass cofiring in order to understand the modes of occurrence of inorganic elements in plant matter. Sixteen essential elements, C, H, O, N, P, K, Ca, Mg, S, Zn, Cu, Fe, Mn, B, Mo, and Cl, are found throughout plants. The predominant inorganic elements are K and Ca, which are essential to the function of all plant cells and will, therefore, be evenly distributed throughout the nonreproductive, aerial portions of herbaceous biomass. Some inorganic constituents, e.g., N, P, Ca, and Cl, are organically associated and incorporated into the structure of the plant. Cell vacuoles are the repository for excess ions in the plant. Minerals deposited in these ubiquitous organelles are expected to be most easily leached from dry material. Other elements may not have specific functions within the plant, but are nevertheless absorbed and fill a need, such as silica. Other elements, such as Na, are nonessential, but are deposited throughout the plant. Their concentration will depend entirely on extrinsic factors regulating their availability in the soil solution, i.e., moisture and soil content. Similarly, Cl content is determined less by the needs of the plant than by the availability in the soil solution; in addition to occurring naturally, Cl is present in excess as the anion complement in K fertilizer applications. An analysis was performed on existing data for switchgrass samples from ten different farms in the south-central portion of Iowa, with the goal of determining correlations between switchgrass elemental composition and geographical and seasonal changes so as to identify factors that influence the elemental composition of biomass. The most important factors in determining levels of various chemical compounds were found to be seasonal and geographical differences related to soil conditions. Combustion testing was performed to obtain deposits typical of boiler fouling and slagging conditions as well as fly ash. Analysis methods using computer-controlled scanning electron microscopy and chemical fractionation were applied to determine the composition and association of inorganic materials in the biomass samples. Modified sample preparation techniques and mineral quantification procedures using cluster analysis were developed to characterize the inorganic material in these samples. Each of the biomass types exhibited different inorganic associations in the fuel as well as in the deposits and fly ash. Morphological analyses of the wheat straw show elongated 10-30-{micro}m amorphous silica particles or phytoliths in the wheat straw structure. Alkali such as potassium, calcium, and sodium is organically bound and dispersed in the organic structure of the biomass materials. Combustion test results showed that the blends fed quite evenly, with good burnout. Significant slag deposit formation was observed for the 100% wheat straw, compared to bituminous and subbituminous coals burned under similar conditions. Although growing rapidly, the fouling deposits of the biomass and coal-biomass blends were significantly weaker than those of the coals. Fouling was only slightly worse for the 100% wheat straw fuel compared to the coals. The wheat straw ash was found to show the greatest similar

  5. Design Concepts for Co-Production of Power, Fuels & Chemicals Via Coal/Biomass Mixtures

    SciTech Connect (OSTI)

    Rao, A. D.; Chen, Q.; Samuelsen, G. S.

    2012-09-30T23:59:59.000Z

    The overall goal of the program is to develop design concepts, incorporating advanced technologies in areas such as oxygen production, feed systems, gas cleanup, component separations and gas turbines, for integrated and economically viable coal and biomass fed gasification facilities equipped with carbon capture and storage for the following scenarios: (i) coproduction of power along with hydrogen, (ii) coproduction of power along with fuels, (iii) coproduction of power along with petrochemicals, and (iv) coproduction of power along with agricultural chemicals. To achieve this goal, specifically the following objectives are met in this proposed project: (i) identify advanced technology options and innovative preliminary design concepts that synergistically integrate plant subsections, (ii) develop steady state system simulations to predict plant efficiency and environmental signature, (iii) develop plant cost estimates by capacity factoring major subsystems or by major equipment items where required, and then capital, operating and maintenance cost estimates, and (iv) perform techno- economic analyses for the above described coproduction facilities. Thermal efficiencies for the electricity only cases with 90% carbon capture are 38.26% and 36.76% (HHV basis) with the bituminous and the lignite feedstocks respectively. For the coproduction cases (where 50% of the energy exported is in the form of electricity), the electrical efficiency, as expected, is highest for the hydrogen coproduction cases while lowest for the higher alcohols (ethanol) coproduction cases. The electrical efficiencies for Fischer-Tropsch coproduction cases are slightly higher than those for the methanol coproduction cases but it should be noted that the methanol (as well as the higher alcohol) coproduction cases produce the finished coproduct while the Fischer-Tropsch coproduction cases produce a coproduct that requires further processing in a refinery. The cross comparison of the thermal performance between the various coproduct cases is further complicated by the fact that the carbon footprint is not the same when carbon leaving with the coproduct are accounted for. The economic analysis and demand for a particular coproduct in the market place is a more meaningful comparison of the various coproduction scenarios. The first year cost of electricity calculated for the bituminous coal is $102.9/MWh while that for the lignite is $108.1/MWh. The calculated cost of hydrogen ranged from $1.42/kg to $2.77/kg depending on the feedstock, which is lower than the DOE announced hydrogen cost goal of $3.00/kg in July 14, 2005. Methanol cost ranged from $345/MT to $617/MT, while the market price is around $450/MT. For Fischer-Tropsch liquids, the calculated cost ranged from $65/bbl to $112/bbl, which is comparable to the current market price of crude oil at around $100/bbl. It should be noted, however, that F-T liquids contain no sulfur and nitrogen compounds. The calculated cost of alcohol ranged from $4.37/gal to $5.43/gal, while it ranged from $2.20/gal to $3.70/gal in a DOE funded study conducted by Louisiana State University. The Louisiana State University study consisted of a significantly larger plant than our study and benefited from economies of scale. When the plant size in our study is scaled up to similar size as in the Louisiana State University study, cost of alcohol is then reduced to a range of $3.24/gal to $4.28/gal, which is comparable. Urea cost ranged from $307/MT to $428/MT, while the market price is around $480/MT.

  6. Subtask 7.4 - Power River Basin Subbituminous Coal-Biomass Cogasification Testing in a Transport Reactor

    SciTech Connect (OSTI)

    Michael Swanson; Daniel Laudal

    2009-03-01T23:59:59.000Z

    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 Kellogg Brown and Root transport reactor located at the Southern Company Services Wilsonville, Alabama, site. Over 3600 hours of operation on 17 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- 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 90% 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 oxygen/fuel ratios. During this series of tests, a previously tested baseline Powder River Basin (PRB) subbituminous coal from the Peabody Energy North Antelope Rochelle Mine near Gillette, Wyoming was mixed with 20 wt% biomass. Two types of biomass were used - wood waste and switchgrass. Gas and particulate sampling at several locations in the riser provided information on coal devolatilization and cracking chemistry as a function of residence time, transport gas, and mode of operation. The goal of these tests was to compare the operating data and sample chemistry of the coal-biomass mixture to the PRB coal, with a focus on Fischer-Tropsch coal-to-liquid production in oxygen-blown mode. Data are to be provided to DOE to determine kinetic rates of devolatilization and tar cracking.

  7. Novel Sorbent-Based Process for High Temperature Trace Metal Removal

    SciTech Connect (OSTI)

    Gokhan Alptekin

    2008-09-30T23:59:59.000Z

    The objective of this project was to demonstrate the efficacy of a novel sorbent can effectively remove trace metal contaminants (Hg, As, Se and Cd) from actual coal-derived synthesis gas streams at high temperature (above the dew point of the gas). The performance of TDA's sorbent has been evaluated in several field demonstrations using synthesis gas generated by laboratory and pilot-scale coal gasifiers in a state-of-the-art test skid that houses the absorbent and all auxiliary equipment for monitoring and data logging of critical operating parameters. The test skid was originally designed to treat 10,000 SCFH gas at 250 psig and 350 C, however, because of the limited gas handling capabilities of the test sites, the capacity was downsized to 500 SCFH gas flow. As part of the test program, we carried out four demonstrations at two different sites using the synthesis gas generated by the gasification of various lignites and a bituminous coal. Two of these tests were conducted at the Power Systems Demonstration Facility (PSDF) in Wilsonville, Alabama; a Falkirk (North Dakota) lignite and a high sodium lignite (the PSDF operator Southern Company did not disclose the source of this lignite) were used as the feedstock. We also carried out two other demonstrations in collaboration with the University of North Dakota Energy Environmental Research Center (UNDEERC) using synthesis gas slipstreams generated by the gasification of Sufco (Utah) bituminous coal and Oak Hills (Texas) lignite. In the PSDF tests, we showed successful operation of the test system at the conditions of interest and showed the efficacy of sorbent in removing the mercury from synthesis gas. In Test Campaign No.1, TDA sorbent reduced Hg concentration of the synthesis gas to less than 5 {micro}g/m{sup 3} and achieved over 99% Hg removal efficiency for the entire test duration. Unfortunately, due to the relatively low concentration of the trace metals in the lignite feed and as a result of the intermittent operation of the PSDF gasifier (due to the difficulties in the handling of the low quality lignite), only a small fraction of the sorbent capacity was utilized (we measured a mercury capacity of 3.27 mg/kg, which is only a fraction of the 680 mg/kg Hg capacity measured for the same sorbent used at our bench-scale evaluations at TDA). Post reaction examination of the sorbent by chemical analysis also indicated some removal As and Se (we did not detect any significant amounts of Cd in the synthesis gas or over the sorbent). The tests at UNDEERC was more successful and showed clearly that the TDA sorbent can effectively remove Hg and other trace metals (As and Se) at high temperature. The on-line gas measurements carried out by TDA and UNDEERC separately showed that TDA sorbent can achieve greater than 95% Hg removal efficiency at 260 C ({approx}200g sorbent treated more than 15,000 SCF synthesis gas). Chemical analysis conducted following the tests also showed modest amounts of As and Se accumulation in the sorbent bed (the test durations were still short to show higher capacities to these contaminants). We also evaluated the stability of the sorbent and the fate of mercury (the most volatile and unstable of the trace metal compounds). The Synthetic Ground Water Leaching Procedure Test carried out by an independent environmental laboratory showed that the mercury will remain on the sorbent once the sorbent is disposed. Based on a preliminary engineering and cost analysis, TDA estimated the cost of mercury removal from coal-derived synthesis gas as $2,995/lb (this analysis assumes that this cost also includes the cost of removal of all other trace metal contaminants). The projected cost will result in a small increase (less than 1%) in the cost of energy.

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

    SciTech Connect (OSTI)

    Michael Swanson; Daniel Laudal

    2008-03-31T23:59:59.000Z

    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.

  9. Next Generation Metallic Iron Nodule Technology in Electric Arc Steelmaking - Phase II

    SciTech Connect (OSTI)

    Donald R. Fosnacht; Iwao Iwasaki; Richard F. Kiesel; David J. Englund; David W. Hendrickson; Rodney L. Bleifuss

    2010-12-22T23:59:59.000Z

    The current trend in the steel industry is a gradual decline in conventional steelmaking from taconite pellets in blast furnaces, and an increasing number of alternative processes using metallic scrap iron, pig iron and metallized iron ore products. Currently, iron ores from Minnesota and Michigan are pelletized and shipped to the lower Great Lakes ports as blast furnace feed. The existing transportation system and infrastructure is geared to handling these bulk materials. In order to expand the opportunities for the existing iron ore mines beyond their blast furnace customer base, a new material is needed to satisfy the needs of the emerging steel industry while utilizing the existing infrastructure and materials handling. A recent commercial installation employing Kobe Steel’s ITmk3 process, was installed in Northeastern Minnesota. The basic process uses a moving hearth furnace to directly reduce iron oxides to metallic iron from a mixture of iron ore, coals and additives. The resulting products can be shipped using the existing infrastructure for use in various steelmaking processes. The technology reportedly saves energy by 30% over the current integrated steelmaking process and reduces emissions by more than 40%. A similar large-scale pilot plant campaign is also currently in progress using JFE Steel’s Hi-QIP process in Japan. The objective of this proposal is to build upon and improve the technology demonstrated by Kobe Steel and JFE, by further reducing cost, improving quality and creating added incentive for commercial development. This project expands previous research conducted at the University of Minnesota Duluth’s Natural Resources Research Institute and that reported by Kobe and JFE Steel. Three major issues have been identified and are addressed in this project for producing high-quality nodular reduced iron (NRI) at low cost: (1) reduce the processing temperature, (2) control the furnace gas atmosphere over the NRI, and (3) effectively use sub-bituminous coal as a reductant. From over 4000 laboratory tube and box furnace tests, it was established that the correct combination of additives, fluxes, and reductant while controlling the concentration of CO and CO2 in the furnace atmosphere (a) lowers the operating temperature, (b) decreases the use of reductant coal (c) generates less micro nodules of iron, and (d) promotes desulphurization. The laboratory scale work was subsequently verified on 12.2 m (40 ft) long pilot scale furnace. High quality NRI could be produced on a routine basis using the pilot furnace facility with energy provided from oxy-gas or oxy-coal burner technologies. Specific strategies were developed to allow the use of sub-bituminous coals both as a hearth material and as part of the reaction mixture. Computational Fluid Dynamics (CFD) modeling was used to study the overall carbothermic reduction and smelting process. The movement of the furnace gas on a pilot hearth furnace and larger simulated furnaces and various means of controlling the gas atmosphere were evaluated. Various atmosphere control methods were identified and tested during the course of the investigation. Based on the results, the appropriate modifications to the furnace were made and tested at the pilot scale. A series of reduction and smelting tests were conducted to verify the utility of the processing conditions. During this phase, the overall energy use characteristics, raw materials, alternative fuels, and the overall economics predicted for full scale implementation were analyzed. The results indicate that it should be possible to lower reaction temperatures while simultaneously producing low sulfur, high carbon NRI if the right mix chemistry and atmosphere are employed. Recommendations for moving the technology to the next stage of commercialization are presented.

  10. The Mochovce final treatment center for liquid radioactive waste introduced to active trial operation

    SciTech Connect (OSTI)

    Krajc, T.; Stubna, M.; Kravarik, K.; Zatkulak, M. [VUJE Trnava, Inc. (Slovakia); Slezak, M.; Remias, V. [Javys - Jadrova a vyradovacia spolocnost, a.s. - Nuclear and Decommissioning Company, plc., Tomasikova 22, 821 02 Bratislava (Slovakia)

    2007-07-01T23:59:59.000Z

    The Final Treatment Centre (FTC) for Mochovce Nuclear Power Plant (NPP) have been designed for treatment and final conditioning of radioactive liquid and wet waste produced by named NPP equipped with Russian VVER-440 type of reactors. Treated wastes comprise radioactive concentrates, spent resin and sludge. VUJE Inc. as an experienced company in field of treatment of radioactive waste in Slovakia has been chosen as main contractor for technological part of FTC. During the realisation of project the future operator of Centre required the contractor to solve the treatment of wastes produced in the process of NPP A-1 decommissioning. On the basis of this requirement the project was modified in order to enable manipulations with waste products from A-1 NPP transported to Centre in steel drums. The initial project was prepared in 2003. The design and manufacture of main components were performed in 2004 and 2005. FTC civil works started in August 2004. Initial nonradioactive testing of the system parts were carried out from April to September 2006, then the tests of systems started with model concentrates and non-radioactive resins. After the processes evaluation the radioactive test performed from February 2007. A one-year trial operation of facility is planned for completion during 2007 and 2008. The company JAVYS, Inc. is responsible for radioactive waste and spent fuel treatment in the Slovak republic and will operate the FTC during trial operation and after its completion. This Company has also significant experience with operation of Jaslovske Bohunice Treatment Centre. The overall capacity of the FTC is 820 m{sup 3}/year of concentrates and 40 m{sup 3}/year of spent resin and sludge. Bituminization and cementation were provided as main technologies for treatment of these wastes. Treatment of concentrate is performed by bituminization on Thin Film Evaporator with rotating wiping blades. Spent resin and sludge are decanted, dried and mixed with bitumen in blade homogeniser. The bitumen product is discharged into 200 dm{sup 3} steel drums. Drums with bitumen product or drums originated from A-1 NPP are loaded into Fibre Reinforced Concrete containers (FRC) and grouted with cement. Cement grout is prepared from the mixture of cement, additive and radioactive over-concentrate. By formulating the cement grout with evaporator concentrates the maximum radioactivity is fixed in cement matrix and volume of final waste product is minimized. A batch mixer with rotating blades is used to produce the cement grout. The grouted FRC containers are stored in the expedition hall and after 28 days of curing are transported to final disposal. After the start of routine operation, the FTC provides treatment for all liquid and wet LLW produced from the operation of the Mochovce NPP. The final product of the FTC is a FRC loaded with bitumen product in drums and filled with radioactive cement product. This container meets all limits for final disposal in the National Radioactive Waste Repository at Mochovce. This paper introducing the main parts of FTC and describes the technological procedures including the basic technological parameters for both used technologies, their working capacity and the overall waste flow. The evaluation of experience gained in the phases of Centre construction and commissioning and partially trial operation as well is a part of this paper (Evaluation of completion works process and time schedule, the process of individual system parts testing, testing of systems using model media, radioactive testing and trial operation). (authors)

  11. Enhanced Combustion Low NOx Pulverized Coal Burner

    SciTech Connect (OSTI)

    Ray Chamberland; Aku Raino; David Towle

    2006-09-30T23:59:59.000Z

    For more than two decades, ALSTOM Power Inc. (ALSTOM) has developed a range of low cost, in-furnace technologies for NOx emissions control for the domestic U.S. pulverized coal fired boiler market. This includes ALSTOM's internally developed TFS 2000 firing system, and various enhancements to it developed in concert with the U.S. Department of Energy (DOE). As of 2004, more than 200 units representing approximately 75,000 MWe of domestic coal fired capacity have been retrofit with ALSTOM low NOx technology. Best of class emissions range from 0.18 lb/MMBtu for bituminous coals to 0.10 lb/MMBtu for subbituminous coals, with typical levels at 0.24 lb/MMBtu and 0.13 lb/MMBtu, respectively. Despite these gains, NOx emissions limits in the U.S. continue to ratchet down for new and existing (retrofit) boiler equipment. If enacted, proposed Clear Skies legislation will, by 2008, require an average, effective, domestic NOx emissions rate of 0.16 lb/MMBtu, which number will be reduced to 0.13 lb/MMBtu by 2018. Such levels represent a 60% and 67% reduction, respectively, from the effective 2000 level of 0.40 lb/MMBtu. Low cost solutions to meet such regulations, and in particular those that can avoid the need for a costly selective catalytic reduction system (SCR), provide a strong incentive to continue to improve low NOx firing system technology to meet current and anticipated NOx control regulations. In light of these needs, ALSTOM, in cooperation with the DOE, is developing an enhanced combustion, low NOx pulverized coal burner which, when integrated with ALSTOM's state-of-the-art, globally air staged low NOx firing systems, will provide a means to achieve less than 0.15 lb/MMBtu NOx at less than 3/4 the cost of an SCR with low to no impact on balance of plant issues when firing a high volatile bituminous coal. Such coals can be more economic to fire than subbituminous or Powder River Basin (PRB) coals, but are more problematic from a NOx control standpoint as existing firing system technologies do not provide a means to meet current or anticipated regulations absent the use of an SCR. The DOE/ALSTOM program performed large pilot scale combustion testing in ALSTOM's Industrial Scale Burner Facility (ISBF) at its U.S. Power Plant Laboratories facility in Windsor, Connecticut. During this work, the near-field combustion environment was optimized to maximize NOx reduction while minimizing the impact on unburned carbon in ash, slagging and fouling, corrosion, and flame stability/turn-down under globally reducing conditions. Initially, ALSTOM utilized computational fluid dynamic modeling to evaluate a series of burner and/or near field stoichiometry controls in order to screen promising design concepts in advance of the large pilot scale testing. The third and final test, to be executed, will utilize several variants of the best nozzle tip configuration and compare performance with 3 different coals. The fuels to be tested will cover a wide range of coals commonly fired at US utilities. The completion of this work will provide sufficient data to allow ALSTOM to design, construct, and demonstrate a commercial version of an enhanced combustion low NOx pulverized coal burner. A preliminary cost/performance analysis of the developed enhanced combustion low NOx burner applied to ALSTOM's state-of-the-art TFS 2000 firing system was performed to show that the burner enhancements is a cost effective means to reduce NOx.

  12. CO{sub 2} SEQUESTRATION POTENTIAL OF TEXAS LOW-RANK COALS

    SciTech Connect (OSTI)

    Duane A. McVay; Walter B. Ayers Jr; Jerry L. Jensen

    2005-02-01T23:59:59.000Z

    The objectives of this project are to evaluate the feasibility of carbon dioxide (CO{sub 2}) sequestration in Texas low-rank coals and to determine the potential for enhanced coalbed methane (CBM) recovery as an added benefit of sequestration. There were three main objectives for this reporting period, which related to obtaining accurate parameters for reservoir model description and modeling reservoir performance of CO{sub 2} sequestration and enhanced coalbed methane recovery. The first objective was to collect and desorb gas from 10 sidewall core coal samples from an Anadarko Petroleum Corporation well (APCL2 well) at approximately 6,200-ft depth in the Lower Calvert Bluff Formation of the Wilcox Group in east-central Texas. The second objective was to measure sorptive capacities of these Wilcox coal samples for CO{sub 2}, CH{sub 4}, and N{sub 2}. The final objective was to contract a service company to perform pressure transient testing in Wilcox coal beds in a shut-in well, to determine permeability of deep Wilcox coal. Bulk density of the APCL2 well sidewall core samples averaged 1.332 g/cc. The 10 sidewall core samples were placed in 4 sidewall core canisters and desorbed. Total gas content of the coal (including lost gas and projected residual gas) averaged 395 scf/ton on an as-received basis. The average lost gas estimations were approximately 45% of the bulk sample total gas. Projected residual gas was 5% of in-situ gas content. Six gas samples desorbed from the sidewall cores were analyzed to determine gas composition. Average gas composition was approximately 94.3% methane, 3.0% ethane, and 0.7% propane, with traces of heavier hydrocarbon gases. Carbon dioxide averaged 1.7%. Coal from the 4 canisters was mixed to form one composite sample that was used for pure CO{sub 2}, CH{sub 4}, and N{sub 2} isotherm analyses. The composite sample was 4.53% moisture, 37.48% volatile matter, 9.86% ash, and 48.12% fixed carbon. Mean vitrinite reflectance was 0.54%. Coal rank was high-volatile C to B bituminous. Comparison of the desorbed gas content (395 scf/ton, as received) at reservoir pressure (2,697 psi) with the sorption isotherm indicates that Lower Calvert Bluff coal at this well site is oversaturated, but lost gas may have been overestimated. This high gas content suggests that little or no depressurization would be required to initiate methane production. Sorption isotherms results indicate that the sorptive capacity of CO{sub 2} is about 2.5 times that of CH{sub 4} at 1,000 psia. This ratio is similar to that of higher rank bituminous coals from other basins (e.g., Carroll, and Pashin, 2003), and it is very low in comparison to results of other low-rank coals and to the values that we used in our preliminary reservoir modeling. If this value from the APCL2 well is representative, Wilcox coals in this area will sequester less CO{sub 2} on a per ton basis than we had earlier inferred. However, because measured methane contents are higher, enhanced coalbed methane production potential is greater than we earlier inferred. Pressure transient testing for determining coal fracture permeability will be conducted soon by Pinnacle Technologies. The data from these analyses will be used to finalize our coal model for the reservoir simulation phase of the project.

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

    SciTech Connect (OSTI)

    Michael L. Swanson

    2005-08-30T23:59:59.000Z

    The transport reactor development unit (TRDU) was modified to accommodate oxygen-blown operation in support of a Vision 21-type energy plex that could produce power, chemicals, and fuel. These modifications consisted of changing the loop seal design from a J-leg to an L-valve configuration, thereby increasing the mixing zone length and residence time. In addition, the standpipe, dipleg, and L-valve diameters were increased to reduce slugging caused by bubble formation in the lightly fluidized sections of the solid return legs. A seal pot was added to the bottom of the dipleg so that the level of solids in the standpipe could be operated independently of the dipleg return leg. A separate coal feed nozzle was added that could inject the coal upward into the outlet of the mixing zone, thereby precluding any chance of the fresh coal feed back-mixing into the oxidizing zone of the mixing zone; however, difficulties with this coal feed configuration led to a switch back to the original downward configuration. Instrumentation to measure and control the flow of oxygen and steam to the burner and mix zone ports was added to allow the TRDU to be operated under full oxygen-blown conditions. In total, ten test campaigns have been conducted under enriched-air or full oxygen-blown conditions. During these tests, 1515 hours of coal feed with 660 hours of air-blown gasification and 720 hours of enriched-air or oxygen-blown coal gasification were completed under this particular contract. During these tests, approximately 366 hours of operation with Wyodak, 123 hours with Navajo sub-bituminous coal, 143 hours with Illinois No. 6, 106 hours with SUFCo, 110 hours with Prater Creek, 48 hours with Calumet, and 134 hours with a Pittsburgh No. 8 bituminous coal were completed. In addition, 331 hours of operation on low-rank coals such as North Dakota lignite, Australian brown coal, and a 90:10 wt% mixture of lignite and wood waste were completed. Also included in these test campaigns was 50 hours of gasification on a petroleum coke from the Hunt Oil Refinery and an additional 73 hours of operation on a high-ash coal from India. Data from these tests indicate that while acceptable fuel gas heating value was achieved with these fuels, the transport gasifier performs better on the lower-rank feedstocks because of their higher char reactivity. Comparable carbon conversions have been achieved at similar oxygen/coal ratios for both air-blown and oxygen-blown operation for each fuel; however, carbon conversion was lower for the less reactive feedstocks. While separation of fines from the feed coals is not needed with this technology, some testing has suggested that feedstocks with higher levels of fines have resulted in reduced carbon conversion, presumably due to the inability of the finer carbon particles to be captured by the cyclones. These data show that these low-rank feedstocks provided similar fuel gas heating values; however, even among the high-reactivity low-rank coals, the carbon conversion did appear to be lower for the fuels (brown coal in particular) that contained a significant amount of fines. The fuel gas under oxygen-blown operation has been higher in hydrogen and carbon dioxide concentration since the higher steam injection rate promotes the water-gas shift reaction to produce more CO{sub 2} and H{sub 2} at the expense of the CO and water vapor. However, the high water and CO{sub 2} partial pressures have also significantly reduced the reaction of (Abstract truncated)

  14. Geological evaluation of the proposed Rocky Mountain 1 underground coal gasification test site, Hanna, Wyoming

    SciTech Connect (OSTI)

    Oliver, R.L.

    1987-02-01T23:59:59.000Z

    To characterize the proposed Rocky Mountain 1 underground coal gasification test site near Hanna, Wyoming, 30 drill and/or core holes were completed and downhole geophysically logged during the summer of 1986. Core testing was conducted to identify coal quality and predict behavior during gasification. Data were then interpreted to provide information on process parameters and restoration to be used by process and environmental engineers. The coal seam at the Rocky Mountain 1 site dips to the northeast at 7/sup 0/ and shows only minor folding of strata. A fault with 30 feet of stratigraphic displacement is located approximately 300 feet northeast of the northern boundary of the proposed burn area. From core and outcrop observations, tectonic fracturing is predicted to be minor, although local areas of fracturing may exist. Overburden stratigraphy consists of interbedded sandstone, siltstone, and shale with minor coal. The Hanna No. 1 coal (target of the experiments) is approximately 30 feet thick. It contains an upper bench approximately 3 to 4 feet thick of lower quality (higher ash, lower Btu), a central bench about 20 feet thick of higher quality (lower ash, higher Btu), and a lower bench approximately 3 to 4 feet thick also of lower quality. The benches are separated by shaley zones approximately 1 to 2 feet thick, which are correlative across the site. Another shaley zone exists near the base of the central bench. The coal varies vertically and somewhat laterally across the site but averages at a high volatile C bituminous rank. Average-as-received proximate analysis values for the coal are 8.8 wt % moisture, 27.3 wt % ash, 32.0 wt % volatile matter, 31.9 wt % fixed carbon, and approximately 8600 Btu/lb heating value. Average-as-received sulfur content is 0.7 wt %. Site characteristics are very amenable to underground coal gasification, and no hindrances to the test due to geologic conditions are expected. 9 refs., 21 figs., 6 tabs.

  15. Coal-transformation chemistry. Fourth quarterly progress report

    SciTech Connect (OSTI)

    Stock, Leon M.; Blain, D. A.; Handy, C. I.; Heimann, P.; Huang, C. B.; King, H. -H.; Landschulz, W.; Willis, R. S.

    1980-01-01T23:59:59.000Z

    Pyrene, perylene, anthracene, 9,10-diphenylanthracene, naphthalene and biphenyl have been employed as electron transfer agents in the reduction of Illinois No. 6 coal with potassium in tetrahydrofuran. These electron transfer agents are about equally effective for the reduction of this coal at short reaction times (3 hours). We conclude that the anions of biphenyl and naphthalene achieve a greater degree of electron transfer to the coal molecules and that the use of these anions enhances the fragmentation reactions of the coal. Illinois No. 6 bituminous coal and Colorado subbituminous coal were reacted with potassium dissolved in a mixture of monoglyme and triglyme at -50/sup 0/C. The reduction reaction proceeded via solvated electrons rather than by an electron transfer reaction. The coals were then alkylated with methyl iodide and their solubilities in tetrahydrofuran were determined. The Illinois coal reductively alkylated via solvated electrons was considerably less soluble in tetrahydrofuran than the same coal reductively alkylated with potassium and naphthalene in tetrahydrofuran. A sample of Illinois No. 6 coal which had been reductively butylated with n-butyl-1-/sup 13/C iodide was hydrolyzed. Carbon nmr spectroscopy of the hydrolyzed coal revealed that the resonances previously assigned either to the presence of n-butyl carboxylates or to n-butyl tertiary ethers were removed. This observation provides definite evidence that only carboxylates were present in the original alkylated product. Selective alkylation of the acidic hydroxyl groups in Illinois No. 6 coal was carried out using tetrabutylammonium hydroxide as a phase transfer catalyst and iodomethane or 1-iodobutane as alkylating agent as described by Liotta. The tetrahydrofuran solubility of the product was significantly improved in a reaction where reductively butylated coal was subsequently coal was subsequently methylated using Liotta's procedure.

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

    SciTech Connect (OSTI)

    Eric Liese

    2010-01-01T23:59:59.000Z

    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

  17. Recovery of Water from Boiler Flue Gas Using Condensing Heat Exchangers

    SciTech Connect (OSTI)

    Levy, Edward; Bilirgen, Harun; DuPont, John

    2011-03-31T23:59:59.000Z

    Most of the water used in a thermoelectric power plant is used for cooling, and DOE has been focusing on possible techniques to reduce the amount of fresh water needed for cooling. DOE has also been placing emphasis on recovery of usable water from sources not generally considered, such as mine water, water produced from oil and gas extraction, and water contained in boiler flue gas. This report deals with development of condensing heat exchanger technology for recovering moisture from flue gas from coal-fired power plants. The report describes: • An expanded data base on water and acid condensation characteristics of condensing heat exchangers in coal-fired units. This data base was generated by performing slip stream tests at a power plant with high sulfur bituminous coal and a wet FGD scrubber and at a power plant firing highmoisture, low rank coals. • Data on typical concentrations of HCl, HNO{sub 3} and H{sub 2}SO{sub 4} in low temperature condensed flue gas moisture, and mercury capture efficiencies as functions of process conditions in power plant field tests. • Theoretical predictions for sulfuric acid concentrations on tube surfaces at temperatures above the water vapor dewpoint temperature and below the sulfuric acid dew point temperature. • Data on corrosion rates of candidate heat exchanger tube materials for the different regions of the heat exchanger system as functions of acid concentration and temperature. • Data on effectiveness of acid traps in reducing sulfuric acid concentrations in a heat exchanger tube bundle. • Condensed flue gas water treatment needs and costs. • Condensing heat exchanger designs and installed capital costs for full-scale applications, both for installation immediately downstream of an ESP or baghouse and for installation downstream of a wet SO{sub 2} scrubber. • Results of cost-benefit studies of condensing heat exchangers.

  18. Recovery of Water from Boiler Flue Gas Using Condensing Heat Exchangers

    SciTech Connect (OSTI)

    Edward Levy; Harun Bilirgen; John DuPoint

    2011-03-31T23:59:59.000Z

    Most of the water used in a thermoelectric power plant is used for cooling, and DOE has been focusing on possible techniques to reduce the amount of fresh water needed for cooling. DOE has also been placing emphasis on recovery of usable water from sources not generally considered, such as mine water, water produced from oil and gas extraction, and water contained in boiler flue gas. This report deals with development of condensing heat exchanger technology for recovering moisture from flue gas from coal-fired power plants. The report describes: (1) An expanded data base on water and acid condensation characteristics of condensing heat exchangers in coal-fired units. This data base was generated by performing slip stream tests at a power plant with high sulfur bituminous coal and a wet FGD scrubber and at a power plant firing high-moisture, low rank coals. (2) Data on typical concentrations of HCl, HNO{sub 3} and H{sub 2}SO{sub 4} in low temperature condensed flue gas moisture, and mercury capture efficiencies as functions of process conditions in power plant field tests. (3) Theoretical predictions for sulfuric acid concentrations on tube surfaces at temperatures above the water vapor dewpoint temperature and below the sulfuric acid dew point temperature. (4) Data on corrosion rates of candidate heat exchanger tube materials for the different regions of the heat exchanger system as functions of acid concentration and temperature. (5) Data on effectiveness of acid traps in reducing sulfuric acid concentrations in a heat exchanger tube bundle. (6) Condensed flue gas water treatment needs and costs. (7) Condensing heat exchanger designs and installed capital costs for full-scale applications, both for installation immediately downstream of an ESP or baghouse and for installation downstream of a wet SO{sub 2} scrubber. (8) Results of cost-benefit studies of condensing heat exchangers.

  19. FULL-SCALE TESTING OF ENHANCED MERCURY CONTROL TECHNOLOGIES FOR WET FGD SYSTEMS

    SciTech Connect (OSTI)

    D.K. McDonald; G.T. Amrhein; G.A. Kudlac; D. Madden Yurchison

    2003-05-07T23:59:59.000Z

    Wet flue gas desulfurization (wet FGD) systems are currently installed on about 25% of the coal-fired utility generating capacity in the U.S., representing about 15% of the number of coal-fired units. Depending on the effect of operating parameters such as mercury content of the coal, form of mercury (elemental or oxidized) in the flue gas, scrubber spray tower configuration, liquid-to-gas ratio, and slurry chemistry, FGD systems can provide cost-effective, near-term mercury emissions control options with a proven history of commercial operation. For boilers already equipped with FGD systems, the incremental cost of any vapor phase mercury removal achieved is minimal. To be widely accepted and implemented, technical approaches that improve mercury removal performance for wet FGD systems should also have low incremental costs and have little or no impact on operation and SO{sub 2} removal performance. The ultimate goal of the Full-scale Testing of Enhanced Mercury Control for Wet FGD Systems Program was to commercialize methods for the control of mercury in coal-fired electric utility systems equipped with wet flue gas desulfurization (wet FGD). The program was funded by the U.S. Department of Energy's National Energy Technology Laboratory, the Ohio Coal Development Office within the Ohio Department of Development, and Babcock & Wilcox. Host sites and associated support were provided by Michigan South Central Power Agency (MSCPA) and Cinergy. Field-testing was completed at two commercial coal-fired utilities with wet FGD systems: (1) MSCPA's 55 MW{sub e} Endicott Station and (2) Cinergy's 1300 MW{sub e} Zimmer Station. Testing was conducted at these two locations because of the large differences in size and wet scrubber chemistry. Endicott employs a limestone, forced oxidation (LSFO) wet FGD system, whereas Zimmer uses Thiosorbic{reg_sign} Lime (magnesium enhanced lime) and ex situ oxidation. Both locations burn Ohio bituminous coal.

  20. Coal combustion by wet oxidation

    SciTech Connect (OSTI)

    Bettinger, J.A.; Lamparter, R.A.; McDowell, D.C.

    1980-11-15T23:59:59.000Z

    The combustion of coal by wet oxidation was studied by the Center for Waste Management Programs, of Michigan Technological University. In wet oxidation a combustible material, such as coal, is reacted with oxygen in the presence of liquid water. The reaction is typically carried out in the range of 204/sup 0/C (400/sup 0/F) to 353/sup 0/C (650/sup 0/F) with sufficient pressure to maintain the water present in the liquid state, and provide the partial pressure of oxygen in the gas phase necessary to carry out the reaction. Experimental studies to explore the key reaction parameters of temperature, time, oxidant, catalyst, coal type, and mesh size were conducted by running batch tests in a one-gallon stirred autoclave. The factors exhibiting the greatest effect on the extent of reaction were temperature and residence time. The effect of temperature was studied from 204/sup 0/C (400/sup 0/F) to 260/sup 0/C (500/sup 0/F) with a residence time from 600 to 3600 seconds. From this data, the reaction activation energy of 2.7 x 10/sup 4/ calories per mole was determined for a high-volatile-A-Bituminous type coal. The reaction rate constant may be determined at any temperature from the activation energy using the Arrhenius equation. Additional data were generated on the effect of mesh size and different coal types. A sample of peat was also tested. Two catalysts were evaluated, and their effects on reaction rate presented in the report. In addition to the high temperature combustion, low temperature desulfurization is discussed. Desulfurization can improve low grade coal to be used in conventional combustion methods. It was found that 90% of the sulfur can be removed from the coal by wet oxidation with the carbon untouched. Further desulfurization studies are indicated.

  1. Iron optimization for Fenton-driven oxidation of MTBE-spent granular activated carbon

    SciTech Connect (OSTI)

    Scott G. Huling; Patrick K. Jones; Tony R. Lee [U.S. Environmental Protection Agency, Ada, OK (United States). Office of Research and Development, National Risk Management Research Laboratory

    2007-06-01T23:59:59.000Z

    Fenton-driven chemical oxidation of methyl tert-butyl ether (MTBE)-spent granular activated carbon (GAC) was accomplished through the addition of iron (Fe) and hydrogen peroxide (H{sub 2}O{sub 2}) (15.9 g/L; pH 3). The GAC used was URV, a bituminous-coal based carbon. The Fe concentration in GAC was incrementally varied (1020-25 660 mg/kg) by the addition of increasing concentrations of Fe solution (FeSO4{center_dot}7H{sub 2}O). MTBE degradation in Fe-amended GAC increased by an order of magnitude over Fe-unamended GAC and H{sub 2}O{sub 2} reaction was predominantly (99%) attributed to GAC-bound Fe within the porous structure of the GAC. Imaging and microanalysis of GAC particles indicated limited penetration of Fe into GAC. The optimal Fe concentration was 6710 mg/kg (1020 mg/kg background; 5690 mg/kg amended Fe) and resulted in the greatest MTBE removal and maximum Fe loading oxidation efficiency (MTBE oxidized (g)/Fe loaded to GAC(mg/Kg)). At lower Fe concentrations, the H{sub 2}O{sub 2} reaction was Fe limited. At higher Fe concentrations, the H{sub 2}O{sub 2} reaction was not entirely Fe limited, and reductions in GAC surface area, GAC pore volume, MTBE adsorption, and Fe loading oxidation efficiency were measured. Results are consistent with nonuniform distribution of Fe, pore blockage in H{sub 2}O{sub 2} transport, unavailable Fe, and limitations in H{sub 2}O{sub 2} diffusive transport, and emphasize the importance of optimal Fe loading. 22 refs., 6 figs., 2 tabs.

  2. 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

    2014-02-01T23:59:59.000Z

    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.

  3. Coal rank trends in eastern Kentucky

    SciTech Connect (OSTI)

    Hower, J.C.; Trinkle, E.J.

    1984-12-01T23:59:59.000Z

    Examination of coal rank (by vitrinite maximum reflectance) for eastern Kentucky coals has revealed several regional trends. Coal rank varies from high volatile C (0.5% R/sub max/) to medium volatile bituminous (1.1% R/sub max/), and generally increases to the southeast. One east-west-trending rank high and at least four north-south-trending rank highs interrupt the regional increase. The east-west-trending rank high is associated with the Kentucky River faults in northeastern Kentucky. It is the only rank high clearly associated with a fault zone. The four north-south-trending rank highs are parallel with portions of major tectonic features such as the Eastern Kentucky syncline. Overall, though, the association of north-south-trending rank highs with tectonic expression is not as marked as that with the anomaly associated with the Kentucky River faults. It is possible that the rank trends are related to basement features with subdued surface expression. Rank generally increases with depth, and regional trends observed in one coal are also seen in overlying and underlying coals. The cause of the regional southeastward increase in rank is likely to be the combined influence of greater depth of burial and proximity to late Paleozoic orogenic activity. The anomalous trends could be due to increased depth of burial, but are more likely to have resulted from tectonic activity along faults and basement discontinuities. The thermal disturbances necessary to increase the coal rank need not have been great, perhaps on the order of 10-20/sup 0/C (18-36/sup 0/F) above the metamorphic temperatures of the lower rank coals.

  4. GUIDE TO CALCULATING TRANSPORT EFFICIENCY OF AEROSOLS IN OCCUPATIONAL AIR SAMPLING SYSTEMS

    SciTech Connect (OSTI)

    Hogue, M.; Hadlock, D.; Thompson, M.; Farfan, E.

    2013-11-12T23:59:59.000Z

    This report will present hand calculations for transport efficiency based on aspiration efficiency and particle deposition losses. Because the hand calculations become long and tedious, especially for lognormal distributions of aerosols, an R script (R 2011) will be provided for each element examined. Calculations are provided for the most common elements in a remote air sampling system, including a thin-walled probe in ambient air, straight tubing, bends and a sample housing. One popular alternative approach would be to put such calculations in a spreadsheet, a thorough version of which is shared by Paul Baron via the Aerocalc spreadsheet (Baron 2012). To provide greater transparency and to avoid common spreadsheet vulnerabilities to errors (Burns 2012), this report uses R. The particle size is based on the concept of activity median aerodynamic diameter (AMAD). The AMAD is a particle size in an aerosol where fifty percent of the activity in the aerosol is associated with particles of aerodynamic diameter greater than the AMAD. This concept allows for the simplification of transport efficiency calculations where all particles are treated as spheres with the density of water (1 g?cm-3). In reality, particle densities depend on the actual material involved. Particle geometries can be very complicated. Dynamic shape factors are provided by Hinds (Hinds 1999). Some example factors are: 1.00 for a sphere, 1.08 for a cube, 1.68 for a long cylinder (10 times as long as it is wide), 1.05 to 1.11 for bituminous coal, 1.57 for sand and 1.88 for talc. Revision 1 is made to correct an error in the original version of this report. The particle distributions are based on activity weighting of particles rather than based on the number of particles of each size. Therefore, the mass correction made in the original version is removed from the text and the calculations. Results affected by the change are updated.

  5. KRW oxygen-blown gasification combined cycle: Carbon dioxide recovery, transport, and disposal

    SciTech Connect (OSTI)

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

    1996-08-01T23:59:59.000Z

    This project emphasizes CO{sub 2}-capture technologies combined with integrated gasification combined-cycle (IGCC) power systems. Complementary evaluations address CO{sub 2} transportation, CO{sub 2} use, and options for the long-term sequestration of unused CO{sub 2}. The intent is to provide the CO{sub 2} budget, or an equivalent CO{sub 2} budget, associated with each of the individual energy-cycle steps, in addition to process design capital and operating costs. The base case is a 458-MW (gross generation) IGCC system that uses an oxygen-blown Kellogg-Rust-Westinghouse agglomerating fluidized-bed gasifier, Illinois No. 6 bituminous coal feed, and low-pressure glycol sulfur removal followed by Claus/SCOT treatment to produce a saleable product. Mining, feed preparation, and conversion result in a net electric power production for the entire energy cycle of 411 MW, with a CO{sub 2} release rate of 0.801 kg/k Whe. For comparison, in two cases, the gasifier output was taken through water-gas shift and then to low-pressure glycol H{sub 2}S recovery, followed by either low-pressure glycol or membrane CO{sub 2} recovery and then by a combustion turbine being fed a high-hydrogen-content fuel. Two additional cases employed chilled methanol for H{sub 2}S recovery and a fuel cell as the topping cycle with no shift stages. From the IGCC plant, a 500-km pipeline took the CO{sub 2} to geological sequestering. In a comparison of air-blown and oxygen-blown CO{sub 2}-release base cases, the cost of electricity for the air-blown IGCC was 56.86 mills/kWh, and the cost of oxygen-blown IGCC was 58.29 mills/kWh.

  6. Speciation of arsenic in pyrite by micro-X-ray absorption fine- structure spectroscopy (XAFS)

    SciTech Connect (OSTI)

    Paktunc, D. (CCM)

    2008-09-30T23:59:59.000Z

    Pyrite (FeS2) often contains variable levels of arsenic, regardless of the environment of formation. Arsenian pyrite has been reported in coals, sediments and ore deposits. Arsenian pyrite having As concentrations of up to 10 wt % in sedimentary rocks (Kolker et al. 1997), about 10 wt% in gold deposits (Fleet et al. 1993), 12 wt % in a refractory gold ore (Paktunc et al. 2006) and 20 wt % in a Carlin-type gold deposit in Nevada (Reich et al. 2005) have been reported. Arsenian pyrite is the carrier of gold in hydrothermal Carlin-type gold deposits, and gold concentrations of up to 0.9 wt % have been reported (Reich et al. 2005; Paktunc et al. 2006). In general, high Au concentrations correlate with As-rich zones in pyrite (Paktunc et al. 2006). Pyrite often ends up in mining and metallurgical wastes as an unwanted mineral and consititutes one of the primary sources of As in the wastes. Arsenic can be readily released to the environment due to rapid oxidative dissolution of host pyrite under atmospheric conditions. Pyrite is also the primary source of arsenic in emissions and dust resulting from combustion of bituminous coals. Despite the importance of arsenian pyrite as a primary source of anthropogenic arsenic in the environment and its economic significance as the primary carrier of gold in Carlin-type gold deposits, our understanding of the nature of arsenic in pyrite is limited. There are few papers dealing with the mode of occurrence of arsenic by bulk XAFS in a limited number of pyrite-bearing samples. The present study documents the analysis of pyrite particles displaying different morphologies and a range of arsenic and gold concentrations to determine the nature and speciation of arsenic.

  7. Coal resources of Kyrgyzstan

    SciTech Connect (OSTI)

    Landis, E.R.; Bostick, N.H.; Gluskoter, H.J.; Johnson, E.A. [Geological Survey, Denver, CO (United States); Harrison, C.D. [CQ Inc., Homer City, PA (United States); Huber, D.W.

    1995-12-31T23:59:59.000Z

    The rugged, mountainous country of Kyrgyzstan contains about one-half of the known coal resources of central Asia (a geographic and economic region that also includes Uzbekistan, Tadjikistan and Turkmenistan). Coal of Jurassic age is present in eight regions in Kyrgyzstan in at least 64 different named localities. Significant coal occurrences of about the same age are present in the central Asian countries of Kazakhstan, China, and Russia. Separation of the coal-bearing rocks into individual deposits results more than earth movements before and during formation of the present-day mountains and basins of the country than from deposition in separate basins.Separation was further abetted by deep erosion and removal of the coal-bearing rocks from many areas, followed by covering of the remaining coal-bearing rocks by sands and gravels of Cenozoic age. The total resources of coal in Kyrgyzstan have been reported as about 30 billion tons. In some of the reported localities, the coal resources are known and adequately explored. In other parts of the republic, the coal resources are inadequately understood or largely unexplored. The resource and reserve inventory of Kyrgyzstan is at best incomplete; for some purposes, such as short-term local and long-range national planning, it may be inadequate. Less than 8% of the total estimated resources are categorized as recoverable reserves, and the amount that is economically recoverable is unknown. The coal is largely of subbituminous and high-volatile C bituminous rank, most has low and medium ash and sulfur contents, and coals of higher rank (some with coking qualities) are present in one region. It is recommended that appropriate analyses and tests be made during planning for utilization.

  8. Biodesulfurization techniques: Application of selected microorganisms for organic sulfur removal from coals. Final report

    SciTech Connect (OSTI)

    Elmore, B.B.

    1993-08-01T23:59:59.000Z

    As an alternative to post-combustion desulfurization of coal and pre-combustion desulfurization using physicochemical techniques, the microbial desulfurization of coal may be accomplished through the use of microbial cultures that, in an application of various microbial species, may remove both the pyritic and organic fractions of sulfur found in coal. Organisms have been isolated that readily depyritize coal but often at prohibitively low rates of desulfurization. Microbes have also been isolated that may potentially remove the organic-sulfur fraction present in coal (showing promise when acting on organic sulfur model compounds such as dibenzothiophene). The isolation and study of microorganisms demonstrating a potential for removing organic sulfur from coal has been undertaken in this project. Additionally, the organisms and mechanisms by which coal is microbially depyritized has been investigated. Three cultures were isolated that grew on dibenzothiophene (DBT), a model organic-sulfur compound, as the sole sulfur source. These cultures (UMX3, UMX9, and IGTS8) also grew on coal samples as the sole sulfur source. Numerous techniques for pretreating and ``cotreating`` coal for depyritization were also evaluated for the ability to improve the rate or extent of microbial depyritization. These include prewashing the coal with various solvents and adding surfactants to the culture broth. Using a bituminous coal containing 0.61% (w/w) pyrite washed with organic solvents at low slurry concentrations (2% w/v), the extent of depyritization was increased approximately 25% in two weeks as compared to controls. At slurry concentrations of 20% w/v, a tetrachloroethylene treatment of the coal followed by depyritization with Thiobacillus ferrooxidans increased both the rate and extent of depyritization by approximately 10%.

  9. Catalysts and process developments for two-stage liquefaction. Final technical report, October 1, 1989--September 30, 1992

    SciTech Connect (OSTI)

    Cronauer, D.C.; Swanson, A.J.; Sajkowski, D.J.

    1992-12-31T23:59:59.000Z

    Research in this project centered upon developing and evaluating catalysts and process improvements for coal liquefaction in the two-stage, close-coupled catalytic process. The major results are summarized here and they are described in more detail under each Task. In tasks for coal pretreatment and beneficiation, it was shown for coal handling that drying of both lignite or subbituminous coals using warm air, vacuum oven or exposing to air for long time was detrimental to subsequent liquefaction. Both laboratory and bench-scale beneficiations indicated that in order to achieve increased liquefaction yield for Illinois No. 6 bituminous coal, size separation with in sink-float technique should be used. For subbituminous coal, the best beneficiation was aqueous SO{sub 2} treatment, which reduced mineral matter. In the case of lignite, the fines should be rejected prior to aqueous SO{sub 2} treatment and sink-float gravity separation. In liquefying coals with supported catalysts in both first and second stages, coal conversion was highest (93%) with Illinois No. 6 coal, which also had the highest total liquid yield of 80%, however, the product contained unacceptably high level of resid (30%). Both low rank coals gave lower conversion (85--87%) and liquid yields (57--59%), but lighter products (no resid). The analysis of spent first stage catalysts indicated significant sodium and calcium deposits causing severe deactivation. The second stage catalysts were in better condition showing high surface areas and low coke and metal deposits. The use of dispersed catalyst in the first stage would combat the severe deactivation.

  10. Advanced Flue Gas Desulfurization (AFGD) demonstration project: Volume 2, Project performance and economics. Final technical report

    SciTech Connect (OSTI)

    NONE

    1996-04-30T23:59:59.000Z

    The project objective is to demonstrate removal of 90--95% or more of the SO{sub 2} at approximately one-half the cost of conventional scrubbing technology; and to demonstrate significant reduction of space requirements. In this project, Pure Air has built a single SO{sub 2} absorber for a 528-MWe power plant. The absorber performs three functions in a single vessel: prequencher, absorber, and oxidation of sludge to gypsum. Additionally, the absorber is of a co- current design, in which the flue gas and scrubbing slurry move in the same direction and at a relatively high velocity compared to conventional scrubbers. These features all combine to yield a state- of-the-art SO{sub 2} absorber that is more compact and less expensive than conventional scrubbers. The project incorporated a number of technical features including the injection of pulverized limestone directly into the absorber, a device called an air rotary sparger located within the base of the absorber, and a novel wastewater evaporation system. The air rotary sparger combines the functions of agitation and air distribution into one piece of equipment to facilitate the oxidation of calcium sulfite to gypsum. Additionally, wastewater treatment is being demonstrated to minimize water disposal problems inherent in many high-chloride coals. Bituminous coals primarily from the Indiana, Illinois coal basin containing 2--4.5% sulfur were tested during the demonstration. The Advanced Flue Gas Desulfurization (AFGD) process has demonstrated removal of 95% or more of the SO{sub 2} while providing a commercial gypsum by-product in lieu of solid waste. A portion of the commercial gypsum is being agglomerated into a product known as PowerChip{reg_sign} gypsum which exhibits improved physical properties, easier flowability and more user friendly handling characteristics to enhance its transportation and marketability to gypsum end-users.

  11. Optimization of Trona/Limestone Injection for SO2 Control in Coal-Fired Boilers

    SciTech Connect (OSTI)

    None

    2005-09-01T23:59:59.000Z

    Mobotec USA develops and markets air pollution control systems for utility boilers and other combustion systems. They have a particular interest in technologies that can reduce NOx, SOx, and mercury emissions from coal-fired boilers, and have been investigating the injection of sorbents such as limestone and trona into a boiler to reduce SOx and Hg emissions. WRI proposed to use the Combustion Test Facility (CTF) to enable Mobotec to conduct a thorough evaluation of limestone and trona injection for SO{sub 2} control. The overall goal of the project was to characterize the SO{sub 2} reductions resulting from the injection of limestone and trona into the CTF when fired with a high-sulfur eastern bituminous coal used in one of Mobotec's Midwest installations. Results revealed that when limestone was injected at Ca:S molar ratios of 1.5 to 3.0, the resulting SO{sub 2} reductions were 35-55%. It is believed that further reductions can be attained with improved mixing of the sorbent with the combustion gases. When limestone was added to the coal, at Ca:S molar ratios of 0.5 to 1.5, the SO{sub 2} reductions were 13-21%. The lower reductions were attributed to dead-burning of the sorbent in the high temperature flame zone. In cases where limestone was both injected into the furnace and added to the coal, the total SO{sub 2} reductions for a given Ca:S molar ratio were similar to the reductions for furnace injection only. The injection of trona into the mid-furnace zone, for Na:S molar ratios of 1.4 to 2.4, resulted in SO{sub 2} reductions of 29-43%. Limestone injection did not produce any slag deposits on an ash deposition probe while trona injection resulted in noticeable slag deposition.

  12. Abundances of sulfur, chlorine, and trace elements in Illinois Basin coals, USA

    SciTech Connect (OSTI)

    Chou, C.L. [Illinois State Geological Survey, Champaign, IL (United States)

    1997-12-31T23:59:59.000Z

    Abundances of sulfur, chlorine and 52 trace elements in 220 channel and drill-core samples of high volatile bituminous coals (Pennsylvanian age) from the Illinois Basin, USA, are evaluated for the purpose of better understanding geologic processes affecting trace element variation in the coal seams. Mean elemental abundances in Illinois Basin coals are listed in a table. Most Illinois Basin coals are high-sulfur (> 3% total sulfur). Peat was influenced by seawater during early diagenesis. However, low-medium sulfur coal (<3% total sulfur) occurs in restricted areas along the Walshville Channel, which is a contemporaneous river in the peat swamp. A comparison of trace element abundances between high-sulfur and low-medium sulfur coals showed that only seven elements (boron, sulfur, iron, molybdenum, mercury, thallium, and uranium) are clearly more abundant in high-sulfur coal than in low-medium sulfur coal. Apparently, boron, sulfur, molybdenum, and uranium in high-sulfur coals were derived from seawater that inundated the peat swamp and terminated peat accumulation. Iron, mercury, and thallium had a terrestrial source and were incorporated in pyrite during diagenesis. Their enrichment in high-sulfur coal is related to pyrite formation in a reducing environment. The chlorine content in Illinois Basin coals, including channel and drill core samples, varies from 0.01% to 0.8% (on a dry basis). Coal samples from surface mines (< 50 meter depth) are usually low in chlorine content (<0.1%). Samples from underground mines (> 50 meter depth) have a chlorine content ranging between 0.1% to 0.5%. Variation of chlorine content in each of the two coal seams shows that chlorine content increases with depth because the chloride in coal is in equilibrium with the chloride in the groundwater, which is also depth dependent. A low chlorine content in shallow regions of a coal seam is a result of leaching by fresh groundwater.

  13. Toms Creek IGCC Demonstration Project

    SciTech Connect (OSTI)

    Virr, M.J.

    1992-01-01T23:59:59.000Z

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

  14. Toms Creek IGCC Demonstration Project

    SciTech Connect (OSTI)

    Virr, M.J.

    1992-11-01T23:59:59.000Z

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

  15. Speciation of Selenium, Arsenic, and Zinc in Class C Fly Ash

    SciTech Connect (OSTI)

    Luo, Yun; Giammar, Daniel E.; Huhmann, Brittany L.; Catalano, Jeffrey G. (WU)

    2011-11-17T23:59:59.000Z

    A major environmental concern associated with coal fly ash is the mobilization of trace elements that may contaminate water. To better evaluate proper use of fly ash, determine appropriate disposal methods, and monitor postdisposal conditions, it is important to understand the speciation of trace elements in fly ash and their possible environmental impact. The speciation of selenium, arsenic, and zinc was determined in five representative Class C fly ash samples from combustion of sub-bituminous Powder River Basin coal using synchrotron-based X-ray absorption spectroscopy to provide an improved understanding of the mechanisms of trace element association with the fly ash. Selenium in all fly ash samples occurs predominantly as Se(IV), with the exception of one sample, in which there was a minor amount of Se(0). Se(0) is likely associated with the high content of unburned coal in the sample. Arsenic exists in the fly ash as a single phase most consistent with calcium pyroarsenate. In contrast, zinc occurs as two distinct species in the silicate glass matrix of the fly ash. This work demonstrates that residual carbon in fly ash may reduce potential Se mobility in the environment by retaining it as less soluble elemental Se instead of Se(IV). Further, this work suggests that As and Zn in Class C fly ash will display substantially different release and mobilization behaviors in aquatic environments. While As release will primarily depend upon the dissolution and hydrolysis of calcium pyroarsenate, Zn release will be controlled by the dissolution of alkaline aluminosilicate glass in the ash.

  16. Pinon pine project. Annual report, January 1995--December 1995

    SciTech Connect (OSTI)

    NONE

    1996-04-01T23:59:59.000Z

    This annual report has been prepared to present the status of the Pinon Pine Project, a nominal 107 MWe (gross) coal-fired integrated gasification combined-cycle (IGCC) power plant addition to Sierra Pacific Power Company`s (SPPCo) system. This project will also serve as a demonstration project cost-shared by the U.S. Department of Energy (DOE) and SPPCo under DOE`s Clean Coal Technology (CCT) Program. The goal of the CCT Program is to demonstrate advanced coal utilization technologies that are energy efficient, reliable and able to achieve substantial reductions in emissions as compared with existing coal technologies. The Pinon Pine Project will demonstrate an IGCC system utilizing the Kellogg-Rust-Westinghouse (KRW) fluidized-bed gasification process operating in an air-blown mode with in-bed desulfurization and hot gas clean-up with a western bituminous coal as the design fuel. Testing will also be performed on a high-sulfur eastern coal. The Pinon Pine Project will be constructed and operated at SPPCo`s Tracy Power Station, an existing power generation facility located on a rural 724-acre plot approximately 17 miles east of Reno, NV. This new unit will be designated as Tracy Unit No. 4. SPPCo, the project participant, has contracted with the Foster Wheeler USA Corporation (FW USA) for the overall project management, engineering, procurement and construction of the project. FW USA in turn has subcontracted with The M.W. Kellogg Company (MWK) for the engineering and procurement of key components for the Gasifier Island.

  17. Characteristics of fly ashes from full-scale coal-fired power plants and their relationship to mercury adsorption

    SciTech Connect (OSTI)

    Yongqi Lu; Massoud Rostam-Abadi; Ramsay Chang; Carl Richardson; Jennifer Paradis [Illinois State Geological Survey, Champaign, IL (United States)

    2007-08-15T23:59:59.000Z

    Nine fly ash samples were collected from the particulate collection devices of four full-scale pulverized coal utility boilers burning eastern bituminous coals and three cyclone utility boilers burning either Powder River Basin coals or PRB blends. As-received fly ash samples were mechanically sieved to obtain six size fractions. Unburned carbon content, mercury content, and Brunauer-Emmett-Teller surface areas of as-received fly ashes and their size fractions were measured. In addition, UBC particles were examined by scanning electron microscopy, high-resolution transmission microscopy, and thermogravimetry to obtain information on their surface morphology, structure, and oxidation reactivity. It was found that the UBC particles contained amorphous carbon, ribbon-shaped graphitic carbon, and highly ordered graphite structures. The mercury contents of the UBCs in raw ash samples were comparable to those of the UBC-enriched samples, indicating that mercury was mainly adsorbed on the UBC in fly ash. The UBC content decreased with a decreasing particle size range for all nine ashes. The mercury content of the UBCs in each size fraction, however, generally increased with a decreasing particle size for the nine ashes. The mercury contents and surface areas of the UBCs in the PRB-CYC ashes were about 8 and 3 times higher than UBCs in the EB-PC ashes, respectively. It appeared that both the particle size and surface area of UBC could contribute to mercury capture. The particle size of the UBC in PRB-CYC ash and thus the external mass transfer was found to be the major factor impacting the mercury adsorption. Both the particle size and surface reactivity of the UBC in EB-PC ash, which generally had a lower carbon oxidation reactivity than the PRB-PC ashes, appeared to be important for the mercury adsorption. 26 refs., 16 figs., 2 tabs.

  18. Viability of underground coal gasification in the 'deep coals' of the Powder River Basin, Wyoming

    SciTech Connect (OSTI)

    NONE

    2007-06-15T23:59:59.000Z

    The objective of this work is to evaluate the PRB coal geology, hydrology, infrastructure, environmental and permitting requirements and to analyze the possible UCG projects which could be developed in the PRB. Project economics on the possible UCG configurations are presented to evaluate the viability of UCG. There are an estimated 510 billion tons of sub-bituminous coal in the Powder River Basin (PRB) of Wyoming. These coals are found in extremely thick seams that are up to 200 feet thick. The total deep coal resource in the PRB has a contained energy content in excess of twenty times the total world energy consumption in 2002. However, only approximately five percent of the coal resource is at depths less than 500 feet and of adequate thickness to be extracted by open pit mining. The balance is at depths between 500 and 2,000 feet below the surface. These are the PRB 'deep coals' evaluated for UCG in this report. The coal deposits in the Powder River Basin of Wyoming are thick, laterally continuous, and nearly flat lying. These deposits are ideal for development by Underground Coal Gasification. The thick deep coal seams of the PRB can be harvested using UCG and be protective of groundwater, air resources, and with minimum subsidence. Protection of these environmental values requires correct site selection, site characterization, impact definition, and impact mitigation. The operating 'lessons learned' of previous UCG operations, especially the 'Clean Cavity' concepts developed at Rocky Mountain 1, should be incorporated into the future UCG operations. UCG can be conducted in the PRB with acceptable environmental consequences. The report gives the recommended development components for UCG commercialization. 97 refs., 31 figs., 57 tabs., 1 app.

  19. Enhancement of mercury capture by the simultaneous addition of hydrogen bromide (HBr) and fly ashes in a slipstream facility

    SciTech Connect (OSTI)

    Yan Cao; Quan-Hai Wang; Jun Li; Jen-Chieh Cheng; Chia-Chun Chan; Marten Cohron; Wei-Ping Pan [Western Kentucky University, Bowling Green, KY (United States). Institute for Combustion Science and Environmental Technology

    2009-04-15T23:59:59.000Z

    Low halogen content in tested Powder River Basin (PRB) coals and low loss of ignition content (LOI) in PRB-derived fly ash were likely responsible for higher elemental mercury content (averaging about 75%) in the flue gas and also lower mercury capture efficiency by electrostatic precipitator (ESP) and wet-FGD. To develop a cost-effective approach to mercury capture in a full-scale coal-fired utility boiler burning PRB coal, experiments were conducted adding hydrogen bromide (HBr) or simultaneously adding HBr and selected fly ashes in a slipstream reactor (0.152 x 0.152 m) under real flue gas conditions. The residence time of the flue gas inside the reactor was about 1.4 s. The average temperature of the slipstream reactor was controlled at about 155{sup o}C. Tests were organized into two phases. In Phase 1, only HBr was added to the slipstream reactor, and in Phase 2, HBr and selected fly ash were added simultaneously. HBr injection was effective (>90%) for mercury oxidation at a low temperature (155{sup o}C) with an HBr addition concentration of about 4 ppm in the flue gas. Additionally, injected HBr enhanced mercury capture by PRB fly ash in the low-temperature range. The mercury capture efficiency, at testing conditions of the slipstream reactor, reached about 50% at an HBr injection concentration of 4 ppm in the flue gas. Compared to only the addition of HBr, simultaneously adding bituminous-derived fly ash in a minimum amount (30 lb/MMacf), together with HBr injection at 4 ppm, could increase mercury capture efficiency by 30%. Injection of lignite-derived fly ash at 30 lb/MMacf could achieve even higher mercury removal efficiency (an additional 35% mercury capture efficiency compared to HBR addition alone). 25 refs., 5 figs., 1 tab.

  20. A field study on the trace metal behavior in atmospheric circulating fluidized-bed coal combustion

    SciTech Connect (OSTI)

    Lind, T.; Kauppinen, E.I.; Jokiniemi, J.K.; Maenhaut, W.

    1994-12-31T23:59:59.000Z

    Trace element behavior in atmospheric circulating fluidized-bed combustion (CFBC) of Venezuelan bituminous coal was studied by determining particle size distributions in the CFBC flue gas. The size distributions of calcium, iron, aluminium, and 21 trace elements, Sc, V, Cr, Mn, Co, Ni, Zn, Ga, As, Se, Sr, Cd, Sb, Cs, Ba, La, Ce, Sm, Lu, Pb, and Th, in the size range 0.01--70{micro}m, were determined by collecting aerosols with a low-pressure impactor-cyclone sampling train from the flue gases of an 80-MW(th) CFBC boiler upstream of the electrostatic precipitator. The collected samples were analyzed gravimetrically and with instrumental neutron activation analysis (INAA), particle-induced X-ray emission analysis (PIXE), and inductively coupled plasma mass spectrometry (ICP-MS). The number size distributions of the aerosols were determined with a differential electrical mobility method in the size range 0.01--0.8 {micro}m. In the ultrafine particle mode, i.e., D{sub p} < 0.1 {micro}m, the CFBC number concentrations varied strongly during the experiments, being one to two orders of magnitude lower than those observed in pulverized coal combustion. For all of the elements studied, 75% or more were found in particles larger than 5{micro}m. None of the studied elements showed significant vaporization and subsequent chemical surface reaction or condensation in the CFBC. The Sr, Se, V, Zn, Ga, Cs, Ba, La, Sm, Lu, and Th size distributions resembled those of aluminium, suggesting their occurrence in aluminosilicate-rich particles in the fly ash. The association of the trace elements with aluminium in the fly ash particles may result from reactions of the trace elements with the aluminosilicate mineral particles inside the burning coal particles, or their initial occurrence in association with these minerals.

  1. Pulsed atmospheric fluidized bed combustion. Final report

    SciTech Connect (OSTI)

    Not Available

    1989-11-01T23:59:59.000Z

    In order to verify the technical feasibility of the MTCI Pulsed Atmospheric Fluidized Bed Combustor technology, a laboratory-scale system was designed, built and tested. Important aspects of the operational and performance parameters of the system were established experimentally. A considerable amount of the effort was invested in the initial task of constructing an AFBC that would represent a reasonable baseline against which the performance of the PAFBC could be compared. A summary comparison of the performance and emissions data from the MTCI 2 ft {times} 2 ft facility (AFBC and PAFBC modes) with those from conventional BFBC (taller freeboard and recycle operation) and circulating fluidized bed combustion (CFBC) units is given in Table ES-1. The comparison is for typical high-volatile bituminous coals and sorbents of average reactivity. The values indicated for BFBC and CFBC were based on published information. The AFBC unit that was designed to act as a baseline for the comparison was indeed representative of the larger units even at the smaller scale for which it was designed. The PAFBC mode exhibited superior performance in relation to the AFBC mode. The higher combustion efficiency translates into reduced coal consumption and lower system operating cost; the improvement in sulfur capture implies less sorbent requirement and waste generation and in turn lower operating cost; lower NO{sub x} and CO emissions mean ease of site permitting; and greater steam-generation rate translates into less heat exchange surface area and reduced capital cost. Also, the PAFBC performance generally surpasses those of conventional BFBC, is comparable to CFBC in combustion and NO{sub x} emissions, and is better than CFBC in sulfur capture and CO emissions even at the scaled-down size used for the experimental feasibility tests.

  2. The fuels program for the Nucla AFBC plant

    SciTech Connect (OSTI)

    Fellin, M.A. [Tri-State Generation and Transmission Association, Inc., Montrose, CO (United States); Mahr, D. [Energy Associates, Towaco, NJ (United States)

    1996-12-31T23:59:59.000Z

    The Nucla Station originally consisted of three 1959 vintage, 36 (3 x 12) MWe, stoker-fired boilers. The plant was built under the Rural Electrification Administration program to service the scenic, western slope of Colorado. In 1988, the stokers were replaced by a new, dual combustor, 110 MWe AFBC boiler in EPRI`s fluidized bed demonstration program. A new 74 MWe topping steam turbine/generator, with extraction to the existing turbines, was installed at that time. The Nucla Plant was a key project in EPRI`s program to demonstrate the commercialization of AFBC technology. This program has been the subject of numerous reports and papers on fluidized bed combustion. The fuel used by the Nucla Station was a relatively good quality, bituminous coal. Nucla`s coal was trucked more than 100 miles to the plant from a mine in Colorado. In addition, some high sulfur coal was test burned in the plant. This coal was trucked to the plant from a mine located near Kayenta, Arizona. The primary purpose of the demonstration program was to scale-up the size of the combustor and examine parameters that affect fluidization, heat transfer, erosion, and other boiler related issues. Sulfur capture and the ability to utilize lower grade fuels was previously demonstrated in other, smaller scale programs. To utilize project funds efficiently, the 1988 AFBC retrofit was dedicated to adding the 110 MWe combustor and related equipment. The plant was revamped specifically for test purposes. To conserve funds, silo storage of coal for the AFBC unit was limited to an 8-hour supply. Existing plant auxiliaries, that could adequately perform during the demonstration, were not upgraded. These included the coal handling system.

  3. Pulsed atmospheric fluidized bed combustion

    SciTech Connect (OSTI)

    Not Available

    1989-11-01T23:59:59.000Z

    In order to verify the technical feasibility of the MTCI Pulsed Atmospheric Fluidized Bed Combustor technology, a laboratory-scale system was designed, built and tested. Important aspects of the operational and performance parameters of the system were established experimentally. A considerable amount of the effort was invested in the initial task of constructing an AFBC that would represent a reasonable baseline against which the performance of the PAFBC could be compared. A summary comparison of the performance and emissions data from the MTCI 2 ft {times} 2 ft facility (AFBC and PAFBC modes) with those from conventional BFBC (taller freeboard and recycle operation) and circulating fluidized bed combustion (CFBC) units is given in Table ES-1. The comparison is for typical high-volatile bituminous coals and sorbents of average reactivity. The values indicated for BFBC and CFBC were based on published information. The AFBC unit that was designed to act as a baseline for the comparison was indeed representative of the larger units even at the smaller scale for which it was designed. The PAFBC mode exhibited superior performance in relation to the AFBC mode. The higher combustion efficiency translates into reduced coal consumption and lower system operating cost; the improvement in sulfur capture implies less sorbent requirement and waste generation and in turn lower operating cost; lower NO{sub x} and CO emissions mean ease of site permitting; and greater steam-generation rate translates into less heat exchange surface area and reduced capital cost. Also, the PAFBC performance generally surpasses those of conventional BFBC, is comparable to CFBC in combustion and NO{sub x} emissions, and is better than CFBC in sulfur capture and CO emissions even at the scaled-down size used for the experimental feasibility tests.

  4. Assessment of atmospheric fluidized-bed combustion recycle systems. Final report

    SciTech Connect (OSTI)

    Rogali, R.; Wysocki, J.; Kursman, S.

    1981-10-01T23:59:59.000Z

    This report presents a technical and economic evaluation of AFBC power plants with recycle systems, and a comparison of these plants with AFBC power plants with carbon burnup beds (CBB) and with pulverized coal-fired (PCF) power plants with flue gas desulfurization (FGD) systems. The analysis considers 1000 MWe plants burning both eastern and western coals. The capital and operating cost estimates are based on boiler designs developed by Babcock and Wilcox, Inc., and on sorbent requirements estimated by Burns and Roe, Inc. The economic analyses are based on a plant located in the East Central region of the United States with a 30-year life and a 70 percent capacity factor. The eastern coal-fired plants are designed to burn Illinois bituminous coal with a higher heating value of 10,100 Btu/lb and a sulfur content of 4%. The required calcium to sulfur mole ratios for the eastern plants are 3.8:1 and 2.5:1 for the AFBC/CBB and AFBC/recycle plants, respectively. The western coal-fired plants are designed to burn Wyoming subbituminous coal with a higher heating value of 8,020 Btu/lb and a sulfur content of 0.48%. The required calcium to sulfur mole ratios for the western plants are 0.7:1 and 0.4:1 for the AFBC/CBB and AFBC/recycle plants, respectively. These Ca/S mole ratios allow for 30 percent utilization of the alkaline coal ash to reduce sorbent requirements to the fluidized bed combustor. The analyses indicate that the AFBC/recycle plants have an economic advantage over the AFBC/CBB plants and over the PCF/FGD plants for both eastern and western coal.

  5. Preliminary assessment of alternative atmospheric fluidized-bed-combustion power-plant systems. Final report

    SciTech Connect (OSTI)

    Bianchini, J.; Rogali, R.; Wysocki, J.; Bradley, W.

    1982-02-01T23:59:59.000Z

    This report presents a technical and economic evaluation of alternative atmospheric fluidized-bed combustion (AFBC) power plant systems with nominal capacities of 1000 MWe. Both eastern and western coal-fired power plants are evaluated for the following systems: baseline AFBC power plants with limestone beds; AFBC power plants with inert beds and wet FGC systems; AFBC power plant with inert beds and a dry FGD system (western coal only); AFBC power plants with limestone beds and limestone precalcination; AFBC power plants with limestone beds and agglomeration and recycle of spent solids; AFBC power plant with limestone beds and sorbent regeneration (eastern coal only); and reference pulverized coal-fired (PCF) power plants with wet FGC systems. The eastern coal-fired plants burn Illinois bituminous coal with a higher heating value of 10,1000 Btu/lb and a sulfur content of 4%. The western coal-fired plants burn Wyoming subbituminous coal with a higher heating value of 8020 Btu/lb and a sulfur content of 0.48%. The capital and operating cost estimates are based on boiler designs developed by Babcock and Wilcox, Inc., and on sorbent requirements estimated by Westinghouse R and D Center. Sorbent requirements for the baseline AFBC power plants are based on a calcium to sulfur mole ratio of 5:1 for the eastern coal-fired plant and 0.7:1 for the western coal-fired plant. The Ca/S mole ratio for the western coal plant allows for 30 percent utilization of the alkaline coal ash to reduce sorbent requirements to the fluidized bed combustor. The economic analyses are based on a plant located in the East Central region of the United States with a 30-year life and a 70 percent capacity factor.

  6. Low-rank coal study : national needs for resource development. Volume 2. Resource characterization

    SciTech Connect (OSTI)

    Not Available

    1980-11-01T23:59:59.000Z

    Comprehensive data are presented on the quantity, quality, and distribution of low-rank coal (subbituminous and lignite) deposits in the United States. The major lignite-bearing areas are the Fort Union Region and the Gulf Lignite Region, with the predominant strippable reserves being in the states of North Dakota, Montana, and Texas. The largest subbituminous coal deposits are in the Powder River Region of Montana and Wyoming, The San Juan Basin of New Mexico, and in Northern Alaska. For each of the low-rank coal-bearing regions, descriptions are provided of the geology; strippable reserves; active and planned mines; classification of identified resources by depth, seam thickness, sulfur content, and ash content; overburden characteristics; aquifers; and coal properties and characteristics. Low-rank coals are distinguished from bituminous coals by unique chemical and physical properties that affect their behavior in extraction, utilization, or conversion processes. The most characteristic properties of the organic fraction of low-rank coals are the high inherent moisture and oxygen contents, and the correspondingly low heating value. Mineral matter (ash) contents and compositions of all coals are highly variable; however, low-rank coals tend to have a higher proportion of the alkali components CaO, MgO, and Na/sub 2/O. About 90% of the reserve base of US low-rank coal has less than one percent sulfur. Water resources in the major low-rank coal-bearing regions tend to have highly seasonal availabilities. Some areas appear to have ample water resources to support major new coal projects; in other areas such as Texas, water supplies may be constraining factor on development.

  7. Trace element distribution and mercury speciation in a pilot-scale coal combustor burning Blacksville coal

    SciTech Connect (OSTI)

    Hargis, R.A.; Pennline, H.W. [Dept. of Energy, Pittsburgh, PA (United States). Federal Energy Technical Center

    1997-12-31T23:59:59.000Z

    A series of tests have been conducted on a nominal 500-pound-per-hour, pilot-scale combustion unit to characterize trace element emissions and mercury speciation. The coal fired during the testing was a Blacksville {number_sign}2, medium-sulfur coal, similar to that used by other researchers investigating mercury speciation. A description of the pilot unit operating conditions during the testing is provided. A summary of the gas/solid distribution of trace elements at various locations within the system, material balances, and baghouse removal efficiencies is also supplied. EPA Method 29 was used to determine trace element and speciated mercury concentrations before and after the baghouse. A comparison of these results with past trace element results from this unit and with the findings of other researchers who have used Blacksville coal is also presented. The pilot-scale combustion unit has been characterized in terms of trace element distribution during two tests while burning a medium-sulfur bituminous Blacksville coal. EPA sampling methodology at the inlet to the baghouse and at the stack was used. Results indicate that most of the elements are removed across the baghouse with the exception of mercury and selenium. Both of these elements were found predominantly in the vapor phase. The average mercury speciation revealed that the vapor-phase mercury was primarily in the oxidized form, which is consistent with the findings of other research with Blacksville coal. Material recoveries for most of the elements were very good. The average recovery for mercury further validates that this pilot unit will be a viable system for mercury sampling and control methods.

  8. Plastic wastes as modifiers of the thermoplasticity of coal

    SciTech Connect (OSTI)

    M.A. Diez; C. Barriocanal; R. Alvarez [Instituto Nacional del Carbon (INCAR), Oviedo (Spain)

    2005-12-01T23:59:59.000Z

    Plastic waste recycling represents a major challenge in environmental protection with different routes now available for dealing with mechanical, chemical, and energy recycling. New concepts in plastic waste recycling have emerged so that now such wastes can be used to replace fossil fuels, either as an energy source or as a secondary raw material. Our objective is to explore the modification of the thermoplastic properties of coal in order to assess the possibility of adding plastic waste to coal for the production of metallurgical coke. Two bituminous coals of different rank and thermoplastic properties were used as a base component of blends with plastic wastes such as high-density polyethylene (HDPE), low-density polyethylene (LDPE), polypropylene (PP), polystyrene (PS), poly(ethylene terephthalate) (PET), and acrilonitrile-butadiene-styrene copolymer (ABS). In all cases, the addition of plastic waste led to a reduction in Gieseler maximum fluidity, the extent of the reduction depending on the fluidity of the base coal, and the amount, the molecular structure, and the thermal behavior of the polymer. As a consequence, the amount of volatile matter released by the plastic waste before, during, and after the maximum fluidity of the coal and the hydrogen-donor and hydrogen-acceptor capacities of the polymer were concluded to be key factors in influencing the extent of the reduction in fluidity and the development of anisotropic carbons. The incorporation of the plastic to the carbon matrix was clearly established in semicokes produced from blends of a high-fluid coal and the plastic tested by SEM examination. 42 refs., 10 figs., 7 tabs.

  9. Radioactive Waste Conditioning, Immobilisation, And Encapsulation Processes And Technologies: Overview And Advances (Chapter 7)

    SciTech Connect (OSTI)

    Jantzen, Carol M. [Savannah River National Lab., Aiken SC (United States); Lee, William E. [Imperial College, London (United Kingdom). Dept. of Materials; Ojovan, Michael I. [Univ. of Sheffield (United Kingdom). Dept. of Materials Science and Engineering

    2012-10-19T23:59:59.000Z

    The main immobilization technologies that are available commercially and have been demonstrated to be viable are cementation, bituminization, and vitrification. Vitrification is currently the most widely used technology for the treatment of high level radioactive wastes (HLW) throughout the world. Most of the nations that have generated HLW are immobilizing in either alkali borosilicate glass or alkali aluminophosphate glass. The exact compositions of nuclear waste glasses are tailored for easy preparation and melting, avoidance of glass-in-glass phase separation, avoidance of uncontrolled crystallization, and acceptable chemical durability, e.g., leach resistance. Glass has also been used to stabilize a variety of low level wastes (LLW) and mixed (radioactive and hazardous) low level wastes (MLLW) from other sources such as fuel rod cladding/decladding processes, chemical separations, radioactive sources, radioactive mill tailings, contaminated soils, medical research applications, and other commercial processes. The sources of radioactive waste generation are captured in other chapters in this book regarding the individual practices in various countries (legacy wastes, currently generated wastes, and future waste generation). Future waste generation is primarily driven by interest in sources of clean energy and this has led to an increased interest in advanced nuclear power production. The development of advanced wasteforms is a necessary component of the new nuclear power plant (NPP) flowsheets. Therefore, advanced nuclear wasteforms are being designed for robust disposal strategies. A brief summary is given of existing and advanced wasteforms: glass, glass-ceramics, glass composite materials (GCM’s), and crystalline ceramic (mineral) wasteforms that chemically incorporate radionuclides and hazardous species atomically in their structure. Cementitious, geopolymer, bitumen, and other encapsulant wasteforms and composites that atomically bond and encapsulate wastes are also discussed. The various processing technologies are cross-referenced to the various types of wasteforms since often a particular type of wasteform can be made by a variety of different processing technologies.

  10. Co-pyrolysis of low rank coals and biomass: Product distributions

    SciTech Connect (OSTI)

    Soncini, Ryan M.; Means, Nicholas C.; Weiland, Nathan T.

    2013-10-01T23:59:59.000Z

    Pyrolysis and gasification of combined low rank coal and biomass feeds are the subject of much study in an effort to mitigate the production of green house gases from integrated gasification combined cycle (IGCC) systems. While co-feeding has the potential to reduce the net carbon footprint of commercial gasification operations, the effects of co-feeding on kinetics and product distributions requires study to ensure the success of this strategy. Southern yellow pine was pyrolyzed in a semi-batch type drop tube reactor with either Powder River Basin sub-bituminous coal or Mississippi lignite at several temperatures and feed ratios. Product gas composition of expected primary constituents (CO, CO{sub 2}, CH{sub 4}, H{sub 2}, H{sub 2}O, and C{sub 2}H{sub 4}) was determined by in-situ mass spectrometry while minor gaseous constituents were determined using a GC-MS. Product distributions are fit to linear functions of temperature, and quadratic functions of biomass fraction, for use in computational co-pyrolysis simulations. The results are shown to yield significant nonlinearities, particularly at higher temperatures and for lower ranked coals. The co-pyrolysis product distributions evolve more tar, and less char, CH{sub 4}, and C{sub 2}H{sub 4}, than an additive pyrolysis process would suggest. For lignite co-pyrolysis, CO and H{sub 2} production are also reduced. The data suggests that evolution of hydrogen from rapid pyrolysis of biomass prevents the crosslinking of fragmented aromatic structures during coal pyrolysis to produce tar, rather than secondary char and light gases. Finally, it is shown that, for the two coal types tested, co-pyrolysis synergies are more significant as coal rank decreases, likely because the initial structure in these coals contains larger pores and smaller clusters of aromatic structures which are more readily retained as tar in rapid co-pyrolysis.

  11. Full Scale Field Trial of the Low Temperature Mercury Capture Process

    SciTech Connect (OSTI)

    James Locke; Richard Winschel

    2011-09-30T23:59:59.000Z

    CONSOL Energy Inc., with partial funding from the Department of Energy (DOE) National Energy Technology Laboratory, designed a full-scale installation for a field trial of the Low-Temperature Mercury Control (LTMC) process, which has the ability to reduce mercury emissions from coal-fired power plants by over 90 percent, by cooling flue gas temperatures to approximately 230 °F and absorbing the mercury on the native carbon in the fly ash, as was recently demonstrated by CONSOL R&D on a slip-stream pilot plant at the Allegheny Energy Mitchell Station with partial support by DOE. LTMC has the potential to remove over 90 percent of the flue gas mercury at a cost at least an order of magnitude lower (on a $/lb mercury removed basis) than activated carbon injection. The technology is suitable for retrofitting to existing and new plants, and, although it is best suited to bituminous coal-fired plants, it may have some applicability to the full range of coal types. Installation plans were altered and moved from the original project host site, PPL Martins Creek plant, to a second host site at Allegheny Energyâ??s R. Paul Smith plant, before installation actually occurred at the Jamestown (New York) Board of Public Utilities (BPU) Samuel A. Carlson (Carlson) Municipal Generating Station Unit 12, where the LTMC system was operated on a limited basis. At Carlson, over 60% mercury removal was demonstrated by cooling the flue gas to 220-230 °F at the ESP inlet via humidification. The host unit ESP operation was unaffected by the humidification and performed satisfactorily at low temperature conditions.

  12. Development of an advanced, continuous mild gasification process for the production of co-products

    SciTech Connect (OSTI)

    Knight, R.A.; Gissy, J.; Kline, S.; Onischak, M.; Babu, S.P. (Institute of Gas Technology, Chicago, IL (USA)); Duthie, R.G. (Bechtel National, Inc., San Francisco, CA (USA))

    1990-04-01T23:59:59.000Z

    A project team consisting of the Institute of Gas Technology, Peabody Holding Company, Inc., and Bechtel National, Inc., is developing a mild gasification process that uses a fluidized/entrained-bed reactor. This reactor is designed to process caking bituminous coals over a wide range of particle sizes without oxidative pretreatment, and also without the use of oxygen or air as reactants. The co-product streams, consisting of char, fuel gas, water, and condensables, would be separated by conventional means such as cyclone, staged condensers, and recycle-oil scrubbers. An isothermal process research unit (PRU) has been built at IGT, consisting of an 8-inch-I.D., 8-foot-long fluidized-bed section and a 4-inch-I.D., 13-foot-long entrained flow section, externally heated by electrical heaters. This quarter, eleven mild gasification tests were conducted in the PRU. Illinois No. 6 coal was used in nine of the tests and a West Virginia metallurgical grade of coal was used in the last two tests. The tests conducted in the PRU this quarter were operated with feed rates about three times higher than those used in the last quarter. Results show the effect of process temperature on the shields of char, oils/tars, and gases. Various compositional effects on the oils/tars were also discovered. Char upgrading studies were completed for the char co-product options of smokeless fuel and adsorbent char. A total condensate collection system was designed for the PRU system. 18 figs., 22 tabs.

  13. Drunkard`s wash project: Coalbed methane production from Ferron coals in east-central Utah

    SciTech Connect (OSTI)

    Lemarre, R.A. [Texaco Exploration and Production, Inc., Denver, CO (United States); Burns, T.D. [River Gas Corporation, Northport, AL (United States)

    1996-12-31T23:59:59.000Z

    The Drunkard`s Wash Project produces dry, coalbed methane gas from coals within the Ferron Sandstone Member of the Mancos Shale. The project covers 120,000 acres on the western flank of the San Rafael Uplift in east-central Utah. Gas was first produced into the sales line in January 1993. The field is being developed on 160 acre spacing with 73 wells currently producing 32.2 MMCFD for an average of 437 MCFD/well. Thirty three of those wells have been producing for 32 months and now average 637 MCFD/well. Most of the wells show a classic coalbed methane negative decline curve with increasing gas rates as the reservoir pressure declines due to production of water. Daily water production is 14,500 BPD, for an average of 199 BWPD/well. Total coal thickness ranges from 7 ft. to 48 ft., with an average of 24 ft. The coals occur in 3 to 6 seams at depths of 1350 to 2450 ft. The coal rank is high volatile A&B bituminous. We can not yet see a correlation between total coal thickness and current production. All wells are cased and hydraulically stimulated and most require pumping units to handle the large volumes of water. However, 22 wells do not require pumps and flow unassisted to the surface. The structure consists of monoclinal westward dip. A thin tonstein layer in the bottom coal seam serves as an excellent datum for mapping. Enhanced production is encountered along a southwest-plunging nose that probably formed additional fracture permeability within the coals. Northeast-trending reverse faults with small displacement appear to compartmentalize the reservoir. The Ferron coals were deposited in a river-dominated deltaic system that prograded to the east and southeast during Turonian-Coniacian (Upper Cretaceous) time. The Ferron Sandstone Member represents an eastward-thinning elastic wedge that was deposited during regression of the Western Interior Cretaceous seaway.

  14. Measurement and Modeling of Sorption-Induced Strain and Permeability Changes in Coal

    SciTech Connect (OSTI)

    Eric P. Robertson

    2005-10-01T23:59:59.000Z

    Strain caused by the adsorption of gases was measured in samples of subbituminous coal from the Powder River basin of Wyoming, U.S.A., and high-volatile bituminous coal from the Uinta-Piceance basin of Utah, U.S.A. using a newly developed strain measurement apparatus. The apparatus can be used to measure strain on multiple small coal samples based on the optical detection of the longitudinal strain. The swelling and shrinkage (strain) in the coal samples resulting from the adsorption of carbon dioxide, nitrogen, methane, helium, and a mixture of gases was measured. Sorption-induced strain processes were shown to be reversible and easily modeled with a Langmuir-type equation. Extended Langmuir theory was applied to satisfactorily model strain caused by the adsorption of gas mixtures using the pure gas Langmuir strain constants. The amount of time required to obtain accurate strain data was greatly reduced compared to other strain measurement methods. Sorption-induced changes in permeability were also measured as a function of pres-sure. Cleat compressibility was found to be variable, not constant. Calculated variable cleat-compressibility constants were found to correlate well with previously published data for other coals. During permeability tests, sorption-induced matrix shrinkage was clearly demonstrated by higher permeability values at lower pore pressures while holding overburden pressure constant. Measured permeability data were modeled using three dif-ferent permeability models from the open literature that take into account sorption-induced matrix strain. All three models poorly matched the measured permeability data because they overestimated the impact of measured sorption-induced strain on permeabil-ity. However, by applying an experimentally derived expression to the measured strain data that accounts for the confining overburden pressure, pore pressure, coal type, and gas type, the permeability models were significantly improved.

  15. Carbon Dioxide Transport and Sorption Behavior in Confined Coal Cores for Enhanced Coalbed Methane and CO2 Sequestration

    SciTech Connect (OSTI)

    Jikich, S.A.; McLendon, T.R.; Seshadri, K.S.; Irdi, G.A.; Smith, D.H.

    2007-11-01T23:59:59.000Z

    Measurements of sorption isotherms and transport properties of CO2 in coal cores are important for designing enhanced coalbed methane/CO2 sequestration field projects. Sorption isotherms measured in the lab can provide the upper limit on the amount of CO2 that might be sorbed in these projects. Because sequestration sites will most likely be in unmineable coals, many of the coals will be deep and under considerable lithostatic and hydrostatic pressures. These lithostatic pressures may significantly reduce the sorption capacities and/or transport rates. Consequently, we have studied apparent sorption and diffusion in a coal core under confining pressure. A core from the important bituminous coal Pittsburgh #8 was kept under a constant, three-dimensional external stress; the sample was scanned by X-ray computer tomography (CT) before, then while it sorbed, CO2. Increases in sample density due to sorption were calculated from the CT images. Moreover, density distributions for small volume elements inside the core were calculated and analyzed. Qualitatively, the computerized tomography showed that gas sorption advanced at different rates in different regions of the core, and that diffusion and sorption progressed slowly. The amounts of CO2 sorbed were plotted vs. position (at fixed times) and vs. time (for various locations in the sample). The resulting sorption isotherms were compared to isotherms obtained from powdered coal from the same Pittsburgh #8 extended sample. The results showed that for this single coal at specified times, the apparent sorption isotherms were dependent on position of the volume element in the core and the distance from the CO2 source. Also, the calculated isotherms showed that less CO2 was sorbed than by a powdered (and unconfined) sample of the coal. Changes in density distributions during the experiment were also observed. After desorption, the density distribution of calculated volume elements differed from the initial distribution, suggesting hysteresis and a possible rearrangement of coal structure due to CO2 sorption.

  16. Emissions of polychlorinated dibenzo-p-dioxins and dibenzofurans from various industrial sources

    SciTech Connect (OSTI)

    Long-Full Lin; Wen-Jhy Lee; Guo-Ping Chang-Chien [National Cheng Kung University, Tainan (Taiwan). Department of Environmental Engineering, and Sustainable Environment Research Center

    2006-12-15T23:59:59.000Z

    This study characterized the emissions of polychlorinated dibenzo-p-dioxins (PCDDs) and polychlorinated dibenzofurans (PCDFs) from the stack flue gases of 17 industrial sources, which were classified into 10 categories. The results show that the mean PCDD/PCDF concentration of secondary zinc smelter (Zn-S) and secondary copper smelter (Cu-S) is 2.44 ng international toxic equivalent (I-TEQ)/Nm{sup 3} (N represents normal conditions at 0{sup o}C, 760 mmHg), which was found to be significantly greater than that of industrial waste incinerators (mean concentration = 0.15 ng I-TEQ/Nm{sup 3}). These results imply that the controlling of secondary metallurgical melting processes is more important than industrial waste incineration for the reduction of PCDD/PCDF emissions. The mean emission factors of cement production, Zn-S and Cu-S, are 0.052, 1.99, and 1.73 {mu}g I-TEQ/t product, respectively. The cement plant uses bituminous coal as fuel. For industrial waste incineration, the mean emission factors of waste rubber, waste liquor, waste sludge, industrial waste solid (IWI)-1, IWI-2, IWI-3, and IWI-4 are 0.752, 0.435, 0.760, 6.64, 1.67, 2.38, and 0.094 {mu}g I-TEQ/t feed, respectively. Most of the PCDD/PCDF emission factors established in this study are less than those reported in previous studies, which could be because of the more stringent regulations for PCDD/PCDF emissions in recent years. 20 refs., 1 fig., 7 tabs.

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

    SciTech Connect (OSTI)

    Not Available

    1994-07-01T23:59:59.000Z

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

  18. Effect of CO2 gasification reaction on oxycombustion of pulverized coal char.

    SciTech Connect (OSTI)

    Molina, Alejandro (Universidad Nacional de Colombia, Medellin, Colombia); Hecht, Ethan S.; Shaddix, Christopher R.; Haynes, Brian S. (University of Sydney, New South Wales, Australia)

    2010-07-01T23:59:59.000Z

    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.

  19. 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

    2007-12-15T23:59:59.000Z

    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.

  20. 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

    2009-04-15T23:59:59.000Z

    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.

  1. A novel concept for high conversion of coal to liquids. Final report, 1 September 1988--31 August 1992

    SciTech Connect (OSTI)

    Wiser, W.H.; Shabtai, J.

    1994-04-01T23:59:59.000Z

    A batch microreactor was designed and fabricated as a means of investigating maximum yields of liquids obtainable in very short reaction times of the order of a few seconds, and the maximum ratios of liquids/hydrocarbon (HC) gases obtainable under those conditions. A Wyodak sub-bituminous coal, crushed and sieved to {minus}200 mesh particle size, was used in the experiments, with a temperature of 500{degrees}C and a pressure of 1500 psi. The fine coal particles were fed dry to the reactor and heated to reaction temperature in times of one to two seconds. At a time of 3 seconds at reaction temperature, in a single pass a liquid yield of 60% by weight of the coal was obtained, accompanied by a ratio of liquids/(HC) gases of 30/1. When the unreacted solids were recycled to the reactor, and the results combined with those of the first pass, a liquid yield of 82% by weight of the coal was achieved, accompanied by a ratio of liquids/HC gases of 30/1. This ratio represents only about 3 wt percent HC gases, much lower that is produced in current advanced technologies, and represents a large saving in hydrogen consumption. A simulated distillation technique was applied to the liquids. The liquid product contained 86% by weight (of the liquids) total distillables (boiling point below 538{degrees}C), including 70% by weight of low-boiling fractions in the gasoline, kerosene and gas oil range (boiling point up to 325{degrees}C). The liquid product exhibited a H/C ratio of 1.5, which is considerably higher than observed in current advanced technologies for the primary liquids. Several catalysts were investigated. Iron catalysts, specifically ferric chloride hexahydrate and ferric sulfate pentahydrate, each produced these high conversions and high ratios of liquids/HC gases.

  2. The use of NMR techniques for the analysis of water in coal and the effect of different coal drying techniques on the structure and reactivity of coal. Final report

    SciTech Connect (OSTI)

    Netzel, D.A.; Miknis, F.P.; Wallace, J.C. Jr.; Butcher, C.H.; Mitzel, J.M.; Turner, T.F.; Hurtubise, R.J.

    1995-02-01T23:59:59.000Z

    Western Research Institute has conducted a study of different methods of coal drying as pretreatment steps before liquefaction. The objectives of this study were to develop a combined chemical dehydration/nuclear magnetic resonance (NMR) method for measuring the moisture content of coal, to measure the changes in coal structure that occur during drying, and to determine the effects of different drying methods on liquefaction reactivity of coals. Different methods of drying were investigated to determine whether coal drying can be accomplished without reducing the reactivity of coals toward liquefaction. Drying methods included thermal, microwave, and chemical dehydration. Coals of rank lignite to high volatile bituminous were studied. Coals that were dried or partially dried thermally and with microwaves had lower liquefaction conversions than coals containing equilibrium moisture contents. However, chemically dried coals had conversions equal to or greater than the premoisturized coals. The conversion behavior is consistent with changes in the physical structure and cross linking reactions because of drying. Thermal and microwave drying appear to cause a collapse in the pore structure, thus preventing donor solvents such as tetralin from contacting reactive sites inside the coals. Chemical dehydration does not appear to collapse the pore structure. These results are supported by the solvent swelling measurements in which the swelling ratios of thermally dried and microwave-dried coals were lower than those of premoisturized coals, indicating a greater degree of cross linking in the dried coals. The swelling ratios of the chemically dried coals were greater than those of the premoisturized coals because the pore structure remaining unchanged or increased when water was removed. These results are consistent with the NMR results, which did not show significant changes in coal chemical structure.

  3. Investigation of coal structure. Final report

    SciTech Connect (OSTI)

    Nishioka, Masaharu

    1994-03-01T23:59:59.000Z

    A better understanding of coal structure is the first step toward more effective utilization of the most abundant hydrocarbon resource. Detailed characterization of coal structure is very difficult, even with today`s highly developed analytical techniques. This is primarily due to the amorphous nature of these high-molecular-weight mixtures. Coal has a polymeric character and has been popularly represented as a three-dimensional cross-linked network. There is, however, little or no information which positively verifies this model. The principal objective of this research was to further investigate the physical structure of coal and to determine the extent to which coal molecules may be covalently cross-linked and/or physically associated. Two common characterization methods, swellability and extractability, were used. A technique modifying the conventional swelling procedure was established to better determine network or associated model conformation. A new method for evaluating coal swelling involving laser scattering has also been developed. The charge-transfer interaction is relatively strong in high-volatile bituminous coal. Soaking in the presence of electron donors and acceptors proved effective for solubilizing the coal, but temperatures in excess of 200 C were required. More than 70 wt% of the coal was readily extracted with pyridine after soaking. Associative/dissociative equilibria of coal molecules were observed during soaking. From these results, the associated model has gained credibility over the network model as the representative structure of coal. Significant portions of coal molecules are unquestionably physically associated, but the overall extent is not known at this time.

  4. Macromolecular structure analysis and effective liquefaction pretreatment. Final report

    SciTech Connect (OSTI)

    Suuberg, E.M.; Yun, Y.; Lilly, W.D.; Leung, K.; Gates, T.; Otake, Y.; Deevi, S.C.

    1994-07-01T23:59:59.000Z

    This project was concerned with characterizing the changes in coal macromolecular structure, that are of significance for liquefaction pretreatments of coal. The macromolecular structure of the insoluble portion of coal is difficult to characterize. Techniques that do so indirectly (based upon, for example, NMR and FTIR characterizations of atomic linkages) are not particularly sensitive for this purpose. Techniques that characterize the elastic structure (such as solvent swelling) are much more sensitive to subtle changes in the network structure. It is for this reason that we focused upon these techniques. The overall objective involved identifying pretreatments that reduce the crosslinking (physical or chemical) of the network structure, and thus lead to materials that can be handled to a greater extent by traditional liquid-phase processing techniques. These techniques tend to be inherently more efficient at producing desirable products. This report is divided into seven chapters. Chapter II summarizes the main experimental approaches used throughout the project, and summarizes the main findings on the Argonne Premium coal samples. Chapter III considers synergistic effects of solvent pairs. It is divided into two subsections. The first is concerned with mixtures of CS{sub 2} with electron donor solvents. The second subsection is concerned with aromatic hydrocarbon - alcohol or hydrocarbon - alcohol mixtures, as might be of interest for preliquefaction delivery of catalysts into bituminous coals. Chapter IV deals with questions of how oxidation might influence the results that are obtained. Chapter V briefly details what conclusions may be drawn concerning the elastic behavior of coals, and the effects of thermal treatments on this behavior. Chapter VI is concerned with theories to describe the action of solvents that are capable of dissociating non-covalent crosslinks. Finally, Chapter VII discusses the practical implications of the study.

  5. Investigation of coal structure. Quarterly report No. 7, October 1, 1993--December 31, 1993

    SciTech Connect (OSTI)

    Not Available

    1994-01-01T23:59:59.000Z

    The objective of this project is to investigate the physical structure of coal illustrated. Coal structure should be well understood to guarantee effective utilization. A better understanding of this physical structure is the first step for effective development of coal utilization processes. Solvent swelling and extraction are the two main investigative probes in this project. No single solvent tested to date can disrupt all of the relatively strong secondary interactions in coal. Various relatively strong secondary interactions must be solvated step by step using appropriate procedures. If physical association is considerable, coal should be readily extracted. Physical association will be evaluated by coal swelling using conventional and new methods. To investigate the effects of low coal concentration and continuous mixing, a new method will be developed. The focus of the work was directed toward a specific bituminous coal low in sulfur and iron. Blind Canyon (DECS-16) coal obtained from the Penn State Coal Bank has been used in this project. Contract activities for this period are: (1) The swelling kinetics were evaluated by conventional procedures using glass tubes. Diffusion of solvent into the coal was small, and solvation of intra- and intermolecular interactions was the rate determining step for swelling. (2) A newly established technique using laser scattering has been used to evaluate interparticle aggregation and swelling. It was observed that particles from certain fractions of specific coals were selectively aggregated in particular solvents. (3) Pyridine extractability after soaking in phenol at 200--250{degrees}C was studied. Approximately 70 wt % of Blind Canyon (DECS-16) coal was extracted under the optimum condition. A significant amount of phenol, however, was physically retained. (4) The associated molecular structure of coal proposed has been supported by associative equilibria during soaking in poor and good solvents.

  6. RESEARCH & DEVELOPMENT TO PREPARE AND CHARACTERIZE ROBUST COAL/BIOMASS MIXTURES FOR DIRECT CO-FEEDING INTO GASIFICATION SYSTEMS

    SciTech Connect (OSTI)

    Felix, Larry; Farthing, William; Hoekman, S. Kent

    2014-12-31T23:59:59.000Z

    This project was initiated on October 1, 2010 and utilizes equipment and research supported by the Department of Energy, National Energy Technology Laboratory, under Award Number DE- FE0005349. It is also based upon previous work supported by the Department of Energy, National Energy Technology Laboratory, under Award Numbers DOE-DE-FG36-01GOl1082, DE-FG36-02G012011 or DE-EE0000272. The overall goal of the work performed was to demonstrate and assess the economic viability of fast hydrothermal carbonization (HTC) for transforming lignocellulosic biomass into a densified, friable fuel to gasify like coal that can be easily blended with ground coal and coal fines and then be formed into robust, weather-resistant pellets and briquettes. The specific objectives of the project include: • Demonstration of the continuous production of a uniform densified and formed feedstock from loblolly pine (a lignocellulosic, short rotation woody crop) in a hydrothermal carbonization (HTC) process development unit (PDU). • Demonstration that finely divided bituminous coal and HTC loblolly pine can be blended to form 90/10 and 70/30 weight-percent mixtures of coal and HTC biomass for further processing by pelletization and briquetting equipment to form robust weather resistant pellets and/or briquettes suitable for transportation and long term storage. • Characterization of the coal-biomass pellets and briquettes to quantify their physical properties (e.g. flow properties, homogeneity, moisture content, particle size and shape), bulk physical properties (e.g. compressibility, heat transfer and friability) and assess their suitability for use as fuels for commercially-available coal gasifiers. • Perform economic analyses using Aspen-based process simulations to determine the costs for deploying and operating HTC processing facilities for the production of robust coal/biomass fuels suitable for fueling commercially-available coal-fired gasifiers. This Final Project Scientific/Technical Report discusses and documents the project work required to meet each of these objectives.

  7. NEW SOLID FUELS FROM COAL AND BIOMASS WASTE

    SciTech Connect (OSTI)

    Hamid Farzan

    2001-09-24T23:59:59.000Z

    Under DOE sponsorship, McDermott Technology, Inc. (MTI), Babcock and Wilcox Company (B and W), and Minergy Corporation developed and evaluated a sludge derived fuel (SDF) made from sewage sludge. Our approach is to dry and agglomerate the sludge, combine it with a fluxing agent, if necessary, and co-fire the resulting fuel with coal in a cyclone boiler to recover the energy and to vitrify mineral matter into a non-leachable product. This product can then be used in the construction industry. A literature search showed that there is significant variability of the sludge fuel properties from a given wastewater plant (seasonal and/or day-to-day changes) or from different wastewater plants. A large sewage sludge sample (30 tons) from a municipal wastewater treatment facility was collected, dried, pelletized and successfully co-fired with coal in a cyclone-equipped pilot. Several sludge particle size distributions were tested. Finer sludge particle size distributions, similar to the standard B and W size distribution for sub-bituminous coal, showed the best combustion and slagging performance. Up to 74.6% and 78.9% sludge was successfully co-fired with pulverized coal and with natural gas, respectively. An economic evaluation on a 25-MW power plant showed the viability of co-firing the optimum SDF in a power generation application. The return on equity was 22 to 31%, adequate to attract investors and allow a full-scale project to proceed. Additional market research and engineering will be required to verify the economic assumptions. Areas to focus on are: plant detail design and detail capital cost estimates, market research into possible project locations, sludge availability at the proposed project locations, market research into electric energy sales and renewable energy sales opportunities at the proposed project location. As a result of this program, wastes that are currently not being used and considered an environmental problem will be processed into a renewable fuel. These fuels will be converted to energy while reducing CO{sub 2} emissions from power generating boilers and mitigating global warming concerns. This report describes the sludge analysis, solid fuel preparation and production, combustion performance, environmental emissions and required equipment.

  8. Development of a Hydrogasification Process for Co-Production of Substitute Natural Gas (SNG) and Electric Power from Western Coals

    SciTech Connect (OSTI)

    Sun, Xiaolei; Rink, Nancy

    2011-04-30T23:59:59.000Z

    This report presents the results of the research and development conducted on an Advanced Hydrogasification Process (AHP) conceived and developed by Arizona Public Service Company (APS) under U.S. Department of Energy (DOE) contract: DE-FC26-06NT42759 for Substitute Natural Gas (SNG) production from western coal. A double-wall (i.e., a hydrogasification contained within a pressure shell) down-flow hydrogasification reactor was designed, engineered, constructed, commissioned and operated by APS, Phoenix, AZ. The reactor is ASME-certified under Section VIII with a rating of 1150 pounds per square inch gage (psig) maximum allowable working pressure at 1950 degrees Fahrenheit ({degrees}F). The reaction zone had a 1.75 inch inner diameter and 13 feet length. The initial testing of a sub-bituminous coal demonstrated ~ 50% carbon conversion and ~10% methane yield in the product gas under 1625{degrees}F, 1000 psig pressure, with a 11 seconds (s) residence time, and 0.4 hydrogen-to-coal mass ratio. Liquid by-products mainly contained Benzene, Toluene, Xylene (BTX) and tar. Char collected from the bottom of the reactor had 9000-British thermal units per pound (Btu/lb) heating value. A three-dimensional (3D) computational fluid dynamic model simulation of the hydrodynamics around the reactor head was utilized to design the nozzles for injecting the hydrogen into the gasifier to optimize gas-solid mixing to achieve improved carbon conversion. The report also presents the evaluation of using algae for carbon dioxide (CO{sub 2}) management and biofuel production. Nannochloropsis, Selenastrum and Scenedesmus were determined to be the best algae strains for the project purpose and were studied in an outdoor system which included a 6-meter (6M) radius cultivator with a total surface area of 113 square meters (m{sup 2}) and a total culture volume between 10,000 to 15,000 liters (L); a CO{sub 2} on-demand feeding system; an on-line data collection system for temperature, pH, Photosynthetically Activate Radiation (PAR) and dissolved oxygen (DO); and a ~2 gallons per minute (gpm) algae culture dewatering system. Among the three algae strains, Scenedesmus showed the most tolerance to temperature and irradiance conditions in Phoenix and the best self-settling characteristics. Experimental findings and operational strategies determined through these tests guided the operation of the algae cultivation system for the scale-up study. Effect of power plant flue gas, especially heavy metals, on algae growth and biomass adsorption were evaluated as well.

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

    SciTech Connect (OSTI)

    Constance Senior

    2004-12-31T23:59:59.000Z

    The objectives of this program were to measure the oxidation of mercury in flue gas across SCR catalyst in a coal-fired power plant burning low rank fuels using a slipstream reactor containing multiple commercial catalysts in parallel and to develop a greater understanding of mercury oxidation across SCR catalysts in the form of a simple model. The Electric Power Research Institute (EPRI) and Argillon GmbH provided co-funding for this program. REI used a multicatalyst slipstream reactor to determine oxidation of mercury across five commercial SCR catalysts at a power plant that burned a blend of 87% subbituminous coal and 13% bituminous coal. The chlorine content of the blend was 100 to 240 {micro}g/g on a dry basis. Mercury measurements were carried out when the catalysts were relatively new, corresponding to about 300 hours of operation and again after 2,200 hours of operation. NO{sub x}, O{sub 2} and gaseous mercury speciation at the inlet and at the outlet of each catalyst chamber were measured. In general, the catalysts all appeared capable of achieving about 90% NO{sub x} reduction at a space velocity of 3,000 hr{sup -1} when new, which is typical of full-scale installations; after 2,200 hours exposure to flue gas, some of the catalysts appeared to lose NO{sub x} activity. For the fresh commercial catalysts, oxidation of mercury was in the range of 25% to 65% at typical full-scale space velocities. A blank monolith showed no oxidation of mercury under any conditions. All catalysts showed higher mercury oxidation without ammonia, consistent with full-scale measurements. After exposure to flue gas for 2,200 hours, some of the catalysts showed reduced levels of mercury oxidation relative to the initial levels of oxidation. A model of Hg oxidation across SCRs was formulated based on full-scale data. The model took into account the effects of temperature, space velocity, catalyst type and HCl concentration in the flue gas.

  10. FIELD TEST PROGRAM FOR LONG-TERM OPERATION OF A COHPAC SYSTEM FOR REMOVING MERCURY FROM COAL-FIRED FLUE GAS

    SciTech Connect (OSTI)

    Jean Bustard; Charles Lindsey; Paul Brignac; Travis Starns; Sharon Sjostrom; Trent Taylor; Cindy Larson

    2004-01-29T23:59:59.000Z

    With the Nation's coal-burning utilities facing the possibility of tighter controls on mercury pollutants, the U.S. Department of Energy is funding projects that could offer power plant operators better ways to reduce these emissions at much lower costs. Sorbent injection technology represents one of the simplest and most mature approaches to controlling mercury emissions from coal-fired boilers. It involves injecting a solid material such as powdered activated carbon into the flue gas. The gas-phase mercury in the flue gas contacts the sorbent and attaches to its surface. The sorbent with the mercury attached is then collected by the existing particle control device along with the other solid material, primarily fly ash. During 2001, ADA Environmental Solutions (ADA-ES) conducted a full-scale demonstration of sorbent-based mercury control technology at the Alabama Power E.C. Gaston Station (Wilsonville, AL). This unit burns a low-sulfur bituminous coal and uses a hot-side electrostatic precipitator (ESP) in combination with a Compact Hybrid Particulate Collector (COHPAC{trademark}) baghouse to collect fly ash. The majority of the fly ash is collected in the ESP with the residual being collected in the COHPAC{trademark} baghouse. Activated carbon was injected between the ESP and COHPAC{trademark} units to collect the mercury. Short-term mercury removal levels in excess of 90% were achieved using the COHPAC{trademark} unit. The test also showed that activated carbon was effective in removing both forms of mercury--elemental and oxidized. However, a great deal of additional testing is required to further characterize the capabilities and limitations of this technology relative to use with baghouse systems such as COHPAC{trademark}. It is important to determine performance over an extended period of time to fully assess all operational parameters. The project described in this report focuses on fully demonstrating sorbent injection technology at a coal-fired power generating plant that is equipped with a COHPAC{trademark} system. The overall objective is to evaluate the long-term effects of sorbent injection on mercury capture and COHPAC{trademark} performance. The work is being done on one-half of the gas stream at Alabama Power Company's Plant Gaston Unit 3 (nominally 135 MW). Data from the testing will be used to determine: (1) If sorbent injection into a high air-to-cloth ratio baghouse is a viable, long-term approach for mercury control; and (2) Design criteria and costs for new baghouse/sorbent injection systems that will use a similar, polishing baghouse (TOXECON{trademark}) approach.

  11. FIELD TEST PROGRAM TO DEVELOP COMPREHENSIVE DESIGN, OPERATING AND COST DATA FOR MERCURY CONTROL SYSTEMS ON NON-SCRUBBED COAL-FIRED BOILERS

    SciTech Connect (OSTI)

    C. Jean Bustard

    2001-07-06T23:59:59.000Z

    With the Nation's coal-burning utilities facing the possibility of tighter controls on mercury pollutants, the U.S. Department of Energy is funding projects that could offer power plant operators better ways to reduce these emissions at much lower costs. Mercury is known to have toxic effects on the nervous system of humans and wildlife. Although it exists only in trace amounts in coal, mercury is released when coal burns and can accumulate on land and in water. In water, bacteria transform the metal into methylmercury, the most hazardous form of the metal. Methylmercury can collect in fish and marine mammals in concentrations hundreds of thousands times higher than the levels in surrounding waters. One of the goals of DOE is to develop technologies by 2005 that will be capable of cutting mercury emissions 50 to 70 percent at well under one-half of today's costs. ADA Environmental Solutions (ADA-ES) is managing a project to test mercury control technologies at full scale at four different power plants from 2000--2003. The ADA-ES project is focused on those power plants that are not equipped with wet flue gas desulfurization systems. ADA-ES will develop a portable system that will be moved to four different utility power plants for field testing. Each of the plants is equipped with either electrostatic precipitators or fabric filters to remove solid particles from the plant's flue gas. ADA-ES's technology will inject a dry sorbent, such as fly ash or activated carbon, that removes the mercury and makes it more susceptible to capture by the particulate control devices. A fine water mist may be sprayed into the flue gas to cool its temperature to the range where the dry sorbent is most effective. PG and E National Energy Group is providing two test sites that fire bituminous coals and are both equipped with electrostatic precipitators and carbon/ash separation systems. Wisconsin Electric Power Company is providing a third test site that burns Powder River Basin coal and has an electrostatic precipitator for particulate control. Alabama Power Company will host a fourth test at its Plant Gaston, which is equipped with a hot-side electrostatic precipitator and a downstream fabric filter.

  12. Advanced In-Furnace NOx Control for Wall and Cyclone-Fired Boilers

    SciTech Connect (OSTI)

    Hamid Sarv

    2009-02-28T23:59:59.000Z

    A NO{sub x} minimization strategy for coal-burning wall-fired and cyclone boilers was developed that included deep air staging, innovative oxygen use, reburning, and advanced combustion control enhancements. Computational fluid dynamics modeling was applied to refine and select the best arrangements. Pilot-scale tests were conducted by firing an eastern high-volatile bituminous Pittsburgh No.8 coal at 5 million Btu/hr in a facility that was set up with two-level overfire air (OFA) ports. In the wall-fired mode, pulverized coal was burned in a geometrically scaled down version of the B and W DRB-4Z{reg_sign} low-NO{sub x} burner. At a fixed overall excess air level of 17%, NO{sub x} emissions with single-level OFA ports were around 0.32 lb/million Btu at 0.80 burner stoichiometry. Two-level OFA operation lowered the NO{sub x} levels to 0.25 lb/million Btu. Oxygen enrichment in the staged burner reduced the NO{sub x} values to 0.21 lb/million Btu. Oxygen enrichment plus reburning and 2-level OFA operation further curbed the NO{sub x} emissions to 0.19 lb/million Btu or by 41% from conventional air-staged operation with single-level OFA ports. In the cyclone firing arrangement, oxygen enrichment of the cyclone combustor enabled high-temperature and deeply staged operation while maintaining good slag tapping. Firing the Pittsburgh No.8 coal in the optimum arrangement generated 112 ppmv NO{sub x} (0.15 lb/million Btu) and 59 ppmv CO. The optimum emissions results represent 88% NO{sub x} reduction from the uncontrolled operation. Levelized costs for additional NO{sub x} removal by various in-furnace control methods in reference wall-fired or cyclone-fired units already equipped with single-level OFA ports were estimated and compared with figures for SCR systems achieving 0.1 lb NO{sub x}/10{sup 6} Btu. Two-level OFA ports could offer the most economical approach for moderate NO{sub x} control, especially for smaller units. O{sub 2} enrichment in combination with 2-level OFA was not cost effective for wall-firing. For cyclone units, NO{sub x} removal by two-level OFA plus O{sub 2} enrichment but without coal reburning was economically attractive.

  13. FIELD TEST PROGRAM TO DEVELOP COMPREHENSIVE DESIGN, OPERATING, AND COST DATA FOR MERCURY CONTROL SYSTEMS

    SciTech Connect (OSTI)

    Michael D. Durham

    2003-05-01T23:59:59.000Z

    With the Nation's coal-burning utilities facing the possibility of tighter controls on mercury pollutants, the U.S. Department of Energy is funding projects that could offer power plant operators better ways to reduce these emissions at much lower costs. Mercury is known to have toxic effects on the nervous system of humans and wildlife. Although it exists only in trace amounts in coal, mercury is released when coal burns and can accumulate on land and in water. In water, bacteria transform the metal into methylmercury, the most hazardous form of the metal. Methylmercury can collect in fish and marine mammals in concentrations hundreds of thousands times higher than the levels in surrounding waters. One of the goals of DOE is to develop technologies by 2005 that will be capable of cutting mercury emissions 50 to 70 percent at well under one-half of today's costs. ADA Environmental Solutions (ADA-ES) is managing a project to test mercury control technologies at full scale at four different power plants from 2000--2003. The ADA-ES project is focused on those power plants that are not equipped with wet flue gas desulfurization systems. ADA-ES has developed a portable system that will be tested at four different utility power plants. Each of the plants is equipped with either electrostatic precipitators or fabric filters to remove solid particles from the plant's flue gas. ADA-ES's technology will inject a dry sorbent, such as activated carbon, which removes the mercury and makes it more susceptible to capture by the particulate control devices. A fine water mist may be sprayed into the flue gas to cool its temperature to the range where the dry sorbent is most effective. PG&E National Energy Group is providing two test sites that fire bituminous coals and both are equipped with electrostatic precipitators and carbon/ash separation systems. Wisconsin Electric Power Company is providing a third test site that burns Powder River Basin (PRB) coal and has an electrostatic precipitator for particulate control. Alabama Power Company will host a fourth test at its Plant Gaston, which is equipped with a hot-side electrostatic precipitator and a downstream fabric filter.

  14. Montana Integrated Carbon to Liquids (ICTL) Demonstration Program

    SciTech Connect (OSTI)

    Fiato, Rocco; Sharma, Ramesh; Allen, Mark; Peyton, Brent; Macur, Richard; Cameron, Jemima

    2013-09-30T23:59:59.000Z

    Integrated carbon?to?liquids technology (ICTL) incorporates three basic processes for the conversion of a wide range of feedstocks to distillate liquid fuels: (1) Direct Microcatalytic Coal Liquefaction (MCL) is coupled with biomass liquefaction via (2) Catalytic Hydrodeoxygenation and Isomerization (CHI) of fatty acid methyl esters (FAME) or trigylceride fatty acids (TGFA) to produce liquid fuels, with process derived (3) CO{sub 2} Capture and Utilization (CCU) via algae production and use in BioFertilizer for added terrestrial sequestration of CO{sub 2}, or as a feedstock for MCL and/or CHI. This novel approach enables synthetic fuels production while simultaneously meeting EISA 2007 Section 526 targets, minimizing land use and water consumption, and providing cost competitive fuels at current day petroleum prices. ICTL was demonstrated with Montana Crow sub?bituminous coal in MCL pilot scale operations at the Energy and Environmental Research Center at the University of North Dakota (EERC), with related pilot scale CHI studies conducted at the University of Pittsburgh Applied Research Center (PARC). Coal?Biomass to Liquid (CBTL) Fuel samples were evaluated at the US Air Force Research Labs (AFRL) in Dayton and greenhouse tests of algae based BioFertilizer conducted at Montana State University (MSU). Econometric modeling studies were also conducted on the use of algae based BioFertilizer in a wheat?camelina crop rotation cycle. We find that the combined operation is not only able to help boost crop yields, but also to provide added crop yields and associated profits from TGFA (from crop production) for use an ICTL plant feedstock. This program demonstrated the overall viability of ICTL in pilot scale operations. Related work on the Life Cycle Assessment (LCA) of a Montana project indicated that CCU could be employed very effectively to reduce the overall carbon footprint of the MCL/CHI process. Plans are currently being made to conduct larger?scale process demonstration studies of the CHI process in combination with CCU to generate synthetic jet and diesel fuels from algae and algae fertilized crops. Site assessment and project prefeasibility studies are planned with a major EPC firm to determine the overall viability of ICTL technology commercialization with Crow coal resources in south central Montana.

  15. Advanced Fine Particulate Characterization Methods

    SciTech Connect (OSTI)

    Steven Benson; Lingbu Kong; Alexander Azenkeng; Jason Laumb; Robert Jensen; Edwin Olson; Jill MacKenzie; A.M. Rokanuzzaman

    2007-01-31T23:59:59.000Z

    The characterization and control of emissions from combustion sources are of significant importance in improving local and regional air quality. Such emissions include fine particulate matter, organic carbon compounds, and NO{sub x} and SO{sub 2} gases, along with mercury and other toxic metals. This project involved four activities including Further Development of Analytical Techniques for PM{sub 10} and PM{sub 2.5} Characterization and Source Apportionment and Management, Organic Carbonaceous Particulate and Metal Speciation for Source Apportionment Studies, Quantum Modeling, and High-Potassium Carbon Production with Biomass-Coal Blending. The key accomplishments included the development of improved automated methods to characterize the inorganic and organic components particulate matter. The methods involved the use of scanning electron microscopy and x-ray microanalysis for the inorganic fraction and a combination of extractive methods combined with near-edge x-ray absorption fine structure to characterize the organic fraction. These methods have direction application for source apportionment studies of PM because they provide detailed inorganic analysis along with total organic and elemental carbon (OC/EC) quantification. Quantum modeling using density functional theory (DFT) calculations was used to further elucidate a recently developed mechanistic model for mercury speciation in coal combustion systems and interactions on activated carbon. Reaction energies, enthalpies, free energies and binding energies of Hg species to the prototype molecules were derived from the data obtained in these calculations. Bimolecular rate constants for the various elementary steps in the mechanism have been estimated using the hard-sphere collision theory approximation, and the results seem to indicate that extremely fast kinetics could be involved in these surface reactions. Activated carbon was produced from a blend of lignite coal from the Center Mine in North Dakota and sunflower hulls for the biomass material to be carbonized. The ability to remove mercury from a bituminous coal's derived flue gas was low. Removals of only 15% were attained while injecting 6 lb/Macf of activated carbon upstream of an electrostatic precipitator. Poisoning of sites on the activated carbon by SO{sub 2} and SO{sub 3} contributed to the poor mercury capture performance.

  16. Enhancing the use of coals by gas reburning-sorbent injection. Volume 3, Gas reburning-sorbent injection at Edwards Unit 1, Central Illinois Light Company

    SciTech Connect (OSTI)

    NONE

    1994-10-01T23:59:59.000Z

    Design work has been completed for a Gas Reburning-Sorbent Injection (GR-SI) system to reduce emissions of NO{sub x}, and SO{sub 2} from a wall fired unit. A GR-SI system was designed for Central Illinois Light Company`s Edwards Station Unit 1, located in Bartonville, Illinois. The unit is rated at 117 MW(e) (net) and is front wall fired with a pulverized bituminous coal blend. The goal of the project was to reduce emissions of NO{sub x} by 60%, from the ``as found`` baseline of 0.98 lb/MBtu (420 mg/MJ), and to reduce emissions of S0{sub 2} by 50%. Since the unit currently fires a blend of high sulfur Illinois coal and low sulfur Kentucky coal to meet an S0{sub 2} limit Of 1.8 lb/MBtu (770 mg/MJ), the goal at this site was amended to meeting this limit while increasing the fraction of high sulfur coal to 57% from the current 15% level. GR-SI requires injection of natural gas into the furnace at the level of the top burner row, creating a fuel-rich zone in which NO{sub x} formed in the coal zone is reduced to N{sub 2}. The design natural gas input corresponds to 18% of the total heat input. Burnout (overfire) air is injected at a higher elevation to burn out fuel combustible matter at a normal excess air level of 18%. Recycled flue gas is used to increase the reburning fuel jet momentum, resulting in enhanced mixing. Recycled flue gas is also used to cool the top row of burners which would not be in service during GR operation. Dry hydrated lime sorbent is injected into the upper furnace to react with S0{sub 2}, forming solid CaSO{sub 4} and CaSO{sub 3}, which are collected by the ESP. The SI system design was optimized with respect to gas temperature, injection air flow rate, and sorbent dispersion. Sorbent injection air flow is equal to 3% of the combustion air. The design includes modifications of the ESP, sootblowing, and ash handling systems.

  17. Amended Silicated for Mercury Control

    SciTech Connect (OSTI)

    James Butz; Thomas Broderick; Craig Turchi

    2006-12-31T23:59:59.000Z

    Amended Silicates{trademark}, a powdered, noncarbon mercury-control sorbent, was tested at Duke Energy's Miami Fort Station, Unit 6 during the first quarter of 2006. Unit 6 is a 175-MW boiler with a cold-side electrostatic precipitator (ESP). The plant burns run-of-the-river eastern bituminous coal with typical ash contents ranging from 8-15% and sulfur contents from 1.6-2.6% on an as-received basis. The performance of the Amended Silicates sorbent was compared with that for powdered activated carbon (PAC). The trial began with a period of baseline monitoring during which no sorbent was injected. Sampling during this and subsequent periods indicated mercury capture by the native fly ash was less than 10%. After the baseline period, Amended Silicates sorbent was injected at several different ratios, followed by a 30-day trial at a fixed injection ratio of 5-6 lb/MMACF. After this period, PAC was injected to provide a comparison. Approximately 40% mercury control was achieved for both the Amended Silicates sorbent and PAC at injection ratios of 5-6 lbs/MMACF. Higher injection ratios did not achieve significantly increased removal. Similar removal efficiencies have been reported for PAC injection trials at other plants with cold-side ESPs, most notably for plants using medium to high sulfur coal. Sorbent injection did not detrimentally impact plant operations and testing confirmed that the use of Amended Silicates sorbent does not degrade fly ash quality (unlike PAC). The cost for mercury control using either PAC or Amended Silicates sorbent was estimated to be equivalent if fly ash sales are not a consideration. However, if the plant did sell fly ash, the effective cost for mercury control could more than double if those sales were no longer possible, due to lost by-product sales and additional cost for waste disposal. Accordingly, the use of Amended Silicates sorbent could reduce the overall cost of mercury control by 50% or more versus PAC for locations where fly ash is sold as a by-product.

  18. Coal slurry pipeline based midwest fuel hub

    SciTech Connect (OSTI)

    Huettenhain, H. [Bechtel Technology & Consulting San Francisco, CA (United States)

    1998-12-31T23:59:59.000Z

    Low sulfur Powder River Basin (PRB) coal is a sought after fuel to comply with the year 2000 emission regulation for utility boilers. PRB coal is presently not competitive East of the Mississippi mainly because of railroad switching requirements and boiler designs not compatible with the PRB fuel characteristics. The use of the Lakes for transportation is an exception. The Lakes shipping lanes however, are only open part of the year. It is proposed to construct a coal slurry pipeline from the center of Wyoming coalfields to a hub near Detroit with access to low cost waste energy from power generation stations. The coal slurry pipeline will transport up to 25 million tons per year of fine PRB coal which has been removed from the conventionally transported coal, namely coal transported by rail. The rail delivered coal will have less dust. The system fits the DOE Vision 21 concept to mine and utilize coal in highly efficient systems and with the least environmental impact. The PRB coal is of subbituminous rank and not directly compatible with the boilers in Michigan/Indiana/Ohio area, which are designed to burn bituminous coal. Upgrading of the PRB coal using the hydrothermal slurry upgrading process can transform the PRB coal into a higher Btu content fuel by removing a large portion of the inherent moisture. Such upgraded PRB coal has proven an excellent reactive fuel when burned conventionally as PC fuel, or even when burned in slurry form as Coal Water Fuel (CWF). The cost of the process can be recovered when the process is combined with a coal slurry pipeline transport system. The result is an upgraded competitive fuel or fuels, which can be used for co-firing or re-burning applications to reduce SO{sub 2} and NOx emissions of utility boilers. The fuels can be powdered for direct fuel injection into boilers or blast furnaces as well as CWF. Depending on the stability of the upgraded PRB coal, the pipeline product could also be dewatered and prepared for export. This paper describes the concept and preliminary cost information. It also reports on reactions of the industries, which could be involved in the complex system, namely, coal mining companies, railroads, pipeline operators, fuel suppliers, and utilities.

  19. The fate of alkali species in advanced coal conversion systems

    SciTech Connect (OSTI)

    Krishnan, G.N.; Wood, B.J.

    1991-11-01T23:59:59.000Z

    The fate of species during coal combustion and gasification was determined experimentally in a fluidized bed reactor. A molecular-beam sampling mags spectrometer was used to identify and measure the concentration of vapor phase sodium species in the high temperature environment. Concurrent collection and analysis of the ash established the distribution of sodium species between gas-entrained and residual ash fractions. Two coals, Beulah Zap lignite and Illinois No. 6 bituminous, were used under combustion and gasification conditions at atmospheric pressure. Steady-state bed temperatures were in the range 800--950[degree]C. An extensive calibration procedure ensured that the mass spectrometer was capable of detecting sodium-containing vapor species at concentrations as low as 50 ppb. In the temperature range 800[degree] to 950[degree]C, the concentrations of vapor phase sodium species (Na, Na[sub 2]O, NaCl, and Na[sub 2]SO[sub 4]) are less than 0.05 ppm under combustion conditions with excess air. However, under gasification conditions with Beulah Zap lignite, sodium vapor species are present at about 14 ppm at a temperature of 820[degree]. Of this amount, NaCl vapor constitutes about 5 ppm and the rest is very likely NAOH. Sodium in the form of NaCl in coal enhances the vaporization of sodium species during combustion. Vapor phase concentration of both NaCl and Na[sub 2]SO[sub 4] increased when NaCl was added to the Beulah Zap lignite. Ash particles account for nearly 100% of the sodium in the coal during combustion in the investigated temperature range. The fine fly-ash particles (<10 [mu]m) are enriched in sodium, mainly in the form of sodium sulfate. The amount of sodium species in this ash fraction may be as high as 30 wt % of the total sodium. Sodium in the coarse ash particle phase retained in the bed is mainly in amorphous forms.

  20. The fate of alkali species in advanced coal conversion systems. Final report

    SciTech Connect (OSTI)

    Krishnan, G.N.; Wood, B.J.

    1991-11-01T23:59:59.000Z

    The fate of species during coal combustion and gasification was determined experimentally in a fluidized bed reactor. A molecular-beam sampling mags spectrometer was used to identify and measure the concentration of vapor phase sodium species in the high temperature environment. Concurrent collection and analysis of the ash established the distribution of sodium species between gas-entrained and residual ash fractions. Two coals, Beulah Zap lignite and Illinois No. 6 bituminous, were used under combustion and gasification conditions at atmospheric pressure. Steady-state bed temperatures were in the range 800--950{degree}C. An extensive calibration procedure ensured that the mass spectrometer was capable of detecting sodium-containing vapor species at concentrations as low as 50 ppb. In the temperature range 800{degree} to 950{degree}C, the concentrations of vapor phase sodium species (Na, Na{sub 2}O, NaCl, and Na{sub 2}SO{sub 4}) are less than 0.05 ppm under combustion conditions with excess air. However, under gasification conditions with Beulah Zap lignite, sodium vapor species are present at about 14 ppm at a temperature of 820{degree}. Of this amount, NaCl vapor constitutes about 5 ppm and the rest is very likely NAOH. Sodium in the form of NaCl in coal enhances the vaporization of sodium species during combustion. Vapor phase concentration of both NaCl and Na{sub 2}SO{sub 4} increased when NaCl was added to the Beulah Zap lignite. Ash particles account for nearly 100% of the sodium in the coal during combustion in the investigated temperature range. The fine fly-ash particles (<10 {mu}m) are enriched in sodium, mainly in the form of sodium sulfate. The amount of sodium species in this ash fraction may be as high as 30 wt % of the total sodium. Sodium in the coarse ash particle phase retained in the bed is mainly in amorphous forms.

  1. Evaluation of Gas Reburning and Low N0x Burners on a Wall Fired Boiler

    SciTech Connect (OSTI)

    None

    1998-07-01T23:59:59.000Z

    Under the U.S. Department of Energy's Clean Coal Technology Program (Round 3), a project was completed to demonstrate control of boiler NOX emissions and to a lesser degree, due to coal replacement, SO2 emissions. The project involved combining Gas Reburning with Low NOX Burners (GR-LNB) on a coal-fired electric utility boiler to determine if high levels of NO, reduction (70VO) could be achieved. Sponsors of the project included the U.S. Depatiment of Energy, the Gas Research Institute, Public Service Company of Colorado, Colorado Interstate Gas, Electric Power Research Institute, and the Energy and Environmental Research Corporation. The GR-LNB demonstration was petformed on Public Service Company of Colorado's (PSCO) Cherokee Unit #3, located in Denver, Colorado. This unit is a 172 MW~ wall-fired boiler that uses Colorado bituminous, low-sulfur coal. It had a baseline NO, emission level of 0.73 lb/1 OG Btu using conventional burners. Low NOX burners are designed to yield lower NOX emissions than conventional burners. However, the NOX control achieved with this technique is limited to 30-50Y0. Also, with LNBs, CO emissions can increase to above acceptable standards. Gas Reburning (GR) is designed to reduce NO, in the flue gas by staged fuel combustion. This technology involves the introduction of' natural gas into the hot furnace flue gas stream. When combined, GR and LNBs minimize NOX emissions and maintain acceptable levels of CO emissions. A comprehensive test program was completed, operating over a wide range of boiler conditions. Over 4,000 hours of operation were achieved, providing substantial data. Measurements were taken to quantify reductions in NOX emissions, the impact on boiler equipment and operability and factors influencing costs. The GR-LNB technology achieved good NO, emission reductions and the goals of the project were achieved. Although the performance of the low NOX burners (supplied by others) was less than expected, a NOX reduction of 65% was achieved at an average gas heat input of 18%. The performance goal of 70/40 reduction was met on many test runs, but at a higher reburn gas heat input. S02 emissions, based on coal replacement, were reduced by 18%.

  2. FIELD TEST PROGRAM TO DEVELOP COMPREHENSIVE DESIGN, OPERATING AND COST DATA FOR MERCURY CONTROL SYSTEMS ON NON-SCRUBBED COAL-FIRED BOILERS

    SciTech Connect (OSTI)

    C. Jean Bustard

    2001-10-01T23:59:59.000Z

    With the Nation's coal-burning utilities facing the possibility of tighter controls on mercury pollutants, the U.S. Department of Energy is funding projects that could offer power plant operators better ways to reduce these emissions at much lower costs. Mercury is known to have toxic effects on the nervous system of humans and wildlife. Although it exists only in trace amounts in coal, mercury is released when coal burns and can accumulate on land and in water. In water, bacteria transform the metal into methylmercury, the most hazardous form of the metal. Methylmercury can collect in fish and marine mammals in concentrations hundreds of thousands times higher than the levels in surrounding waters. One of the goals of DOE is to develop technologies by 2005 that will be capable of cutting mercury emissions 50 to 70 percent at well under one-half of today's costs. ADA Environmental Solutions (ADA-ES) is managing a project to test mercury control technologies at full scale at four different power plants from 2000--2003. The ADA-ES project is focused on those power plants that are not equipped with wet flue gas desulfurization systems. ADA-ES will develop a portable system that will be moved to four different utility power plants for field testing. Each of the plants is equipped with either electrostatic precipitators or fabric filters to remove solid particles from the plant's flue gas. ADA-ES's technology will inject a dry sorbent, such as fly ash or activated carbon, that removes the mercury and makes it more susceptible to capture by the particulate control devices. A fine water mist may be sprayed into the flue gas to cool its temperature to the range where the dry sorbent is most effective. PG&E National Energy Group is providing two test sites that fire bituminous coals and are both equipped with electrostatic precipitators and carbon/ash separation systems. Wisconsin Electric Power Company is providing a third test site that burns Powder River Basin (PRB) coal and has an electrostatic precipitator for particulate control. Alabama Power Company will host a fourth test at its Plant Gaston, which is equipped with a hot-side electrostatic precipitator and a downstream fabric filter.

  3. DIRECT LIQUEFACTION PROOF OF CONCEPT

    SciTech Connect (OSTI)

    NONE

    1998-09-01T23:59:59.000Z

    The eighth bench scale test of POC program, Run PB-08, was successfully completed from August 8 to August 26, 1997. A total of five operating conditions were tested aiming at evaluating the reactivity of different pyrolysis oils in liquefaction of a Wyoming sub-bituminous coal (Black Thunder coal). For the first time, water soluble promoters were incorporated into the iron-based GelCat to improve the dispersion of the promoter metals in the feed blend. The concentration of the active metals, Mo and Fe, was 100 and 1000 ppm of moisture-free coal, respectively. Black Thunder coal used in this run was the same batch as tested in HTI?s Run POC-02. Similar to Runs PB-01 through 7, this run employed two back mixed slurry reactors, an interstage gas/slurry separator and a direct-coupled hydrotreater. In addition to the hot vapor from the second stage separator, the first stage separator overhead liquid was also fed to the hydrotreater, which was packed with Criterion C-411 hydrotreating catalyst. Pyrolysis oil was produced off-line from a pyrolysis unit acquired from University of Wyoming. Solids rejection was achieved by purging out pressure filter solid. The recycle solvents consisted of O-6 separator bottoms and pressure filter liquid (PFL). The Run PB-08 proceeded very smoothly without any interruptions. Coal conversion consistently above 90W% was achieved. High resid conversion and distillate yield have been obtained from co-processing of coal and 343°C+ (650°F+) pyrolysis oil. Light gas (C1-C3 ) yield was minimized and hydrogen consumption was reduced due to the introduction of pyrolysis oil, compared with conventional coal-derived solvent. Catalytic activity was improved by incorporating a promoter metal into the iron-based GelCat. It seemed that lowering the first stage temperature to 435°C might increase the hydrogenation function of the promoter metal. In comparison with previous coal-waste coprocessing run (PB-06), significant improvements in the process performance were achieved due to catalyst modification and integration of pyrolysis technique into liquefaction.

  4. Emissions from burning tire-derived fuel (TDF): Comparison of batch combustion of tire chips and continuous combustion of tire crumb mixed with coal

    SciTech Connect (OSTI)

    Levendis, Y.A.; Atal, A. [Northeastern Univ., Boston, MA (United States); Carlson, J.B. [Army Natick R, Natick, MA (United States)

    1998-04-01T23:59:59.000Z

    This laboratory study investigated the emissions of waste automobile tire-derived fuel (TDF). This fuel was burned in two different modes, either segmented in small pieces (tire chunks) or in pulverized form (tire crumb). Tire chunks were burned in fixed beds in batch mode in a horizontal furnace. Tire crumb was burned in a continous flow mode, dispersed in air, either alone or mixed with pulverized coal, in a verical furnace. The gas flow was laminar, the gas temperature was 1000{degrees}C in all cases, and the residence times of the combustion products in the furnaces were similar. Chunks of waste tires had dimensions in the range of 3-9 {mu}m, tire crumb was size-classified to be 180-212 {mu}m and the high volatile bituminous coal, used herein, was 63-75. The fuel mass loading in the furnaces was varied. The following emissions were monitored at the exit of the furnaces: CO, CO{sub 2}, NO{sub x} polynuclear aromatic hydrocarbon (PAH) and particulates. Results showed that combustion of TDF in fixed beds resulted in large yields (emissions per mass of fuel burned) of CO, soot and PAHs. Such yields increased with the size of the bed. CO, soot and PAHs yields from batch combustion of fixed beds of coal were lower by more than an order of magnitude than those from fixed beds of TDF. Continuous pulverized fuel combustion of TDF (tire crumb) resulted in dramatically lower yields of CO, soot and PAHs than those from batch combustion, especially when TDF was mixed with pulverized coal. To the contrary, switching the mode of combustion of coal (from fixed beds to pulverized fuel) did not result in large differences in the aforementioned emissions. CO{sub 2}, and, especially, NO{sub x} yields from batch combustion of TDF were lower than those from coal. Emissions of NO{sub x} were somewhat lower from batch combustion than from pulverized fuel combustion of TDF and coal.

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

    SciTech Connect (OSTI)

    Edward Levy

    2012-06-29T23:59:59.000Z

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

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

    SciTech Connect (OSTI)

    Tolman, R.; Parkinson, W.J.

    1999-07-01T23:59:59.000Z

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

  7. Pressurized chemical-looping combustion of coal with an iron ore-based oxygen carrier

    SciTech Connect (OSTI)

    Xiao, Rui; Song, Min; Zhang, Shuai; Shen, Laihong [School of Energy and Environment, Southeast University, Sipailou No. 2, Nanjing 210096 (China); Song, Qilei [School of Energy and Environment, Southeast University, Sipailou No. 2, Nanjing 210096 (China); Department of Chemical Engineering and Biotechnology, University of Cambridge, Pembroke Street, Cambridge CB2 3RA (United Kingdom); Lu, Zuoji [School of Energy and Environment, Southeast University, Sipailou No. 2, Nanjing 210096 (China); GCL Engineering Limited, Zhujiang No. 1, Nanjing 210008 (China)

    2010-06-15T23:59:59.000Z

    Chemical-looping combustion (CLC) is a new combustion technology with inherent separation of CO{sub 2}. Most of the previous investigations on CLC of solid fuels were conducted under atmospheric pressure. A pressurized CLC combined cycle (PCLC-CC) system is proposed as a promising coal combustion technology with potential higher system efficiency, higher fuel conversion, and lower cost for CO{sub 2} sequestration. In this study pressurized CLC of coal with Companhia Valedo Rio Doce (CVRD) iron ore was investigated in a laboratory fixed bed reactor. CVRD iron ore particles were exposed alternately to reduction by 0.4 g of Chinese Xuzhou bituminous coal gasified with 87.2% steam/N{sub 2} mixture and oxidation with 5% O{sub 2} in N{sub 2} at 970 C. The operating pressure was varied between 0.1 MPa and 0.6 MPa. First, control experiments of steam coal gasification over quartz sand were performed. H{sub 2} and CO{sub 2} are the major components of the gasification products, and the operating pressure influences the gas composition. Higher concentrations of CO{sub 2} and lower fractions of CO, CH{sub 4}, and H{sub 2} during the reduction process with CVRD iron ore was achieved under higher pressures. The effects of pressure on the coal gasification rate in the presence of the oxygen carrier were different for pyrolysis and char gasification. The pressurized condition suppresses the initial coal pyrolysis process while it also enhances coal char gasification and reduction with iron ore in steam, and thus improves the overall reaction rate of CLC. The oxidation rates and variation of oxygen carrier conversion are higher at elevated pressures reflecting higher reduction level in the previous reduction period. Scanning electron microscope and energy-dispersive X-ray spectroscopy (SEM-EDX) analyses show that particles become porous after experiments but maintain structure and size after several cycles. Agglomeration was not observed in this study. An EDX analysis demonstrates that there is very little coal ash deposited on the oxygen carrier particles but no appreciable crystalline phases change as verified by X-ray diffraction (XRD) analysis. Overall, the limited pressurized CLC experiments carried out in the present work suggest that PCLC of coal is promising and further investigations are necessary. (author)

  8. Coal Ash Behavior in Reducing Environments (CABRE) III Year 6 - Activity 1.10 - Development of a National Center for Hydrogen

    SciTech Connect (OSTI)

    Stanislowski, Joshua; Azenkeng, Alexander; McCollor, Donald; Galbreath, Kevin; Jensen, Robert; Lahr, Brent

    2012-03-31T23:59:59.000Z

    The Energy & Environmental Research Center (EERC) has been conducting research on gasification for six decades. One of the objectives of this gasification research has been to maximize carbon conversion and the water–gas shift process for optimal hydrogen production and syngas quality. This research focus and experience were a perfect fit for the National Center for Hydrogen Technology ® (NCHT®) Program at the EERC for improving all aspects of coal gasification, which ultimately aids in the production and purification of hydrogen. A consortia project was developed under the NCHT Program to develop an improved predictive model for ash formation and deposition under the project entitled “Coal Ash Behavior in Reducing Environments (CABRE) III: Development of the CABRE III Model.” The computer-based program is now applicable to the modeling of coal and ash behavior in both entrained-flow and fluidized-bed gasification systems to aid in overall gasification efficiency. This model represents a significant improvement over the CABRE II model and runs on a Microsoft Windows PC platform. The major achievements of the CABRE III model are partitioning of inorganic transformations between various phases for specific gas cleanup equipment; slag property predictions, including standard temperature–viscosity curves and slag flow and thickness; deposition rates in gasification cleanup equipment; provision for composition analysis for all input and output streams across all process equipment, including major elements and trace elements of interest; composition analysis of deposit streams for various deposit zones, including direct condensation on equipment surfaces (Zone A), homogeneous particulate deposition (Zone B), and entrained fly ash deposition (Zone C); and physical removal of ash in cyclones based on D50 cut points. Another new feature of the CABRE III model is a user-friendly interface and detailed reports that are easily exportable into Word documents, Excel spreadsheets, or as pdf files. The user interface provides stepwise guides with built-in checks for efficient entry of required input data on fuels of interest to allow a successful execution of the model. The model was developed with data from several fuels selected by the sponsors, including bituminous coal, subbituminous coal, lignite, and petroleum coke (petcoke). The data from these fuels were obtained using small pilot-scale entrained-flow and fluidized-bed gasifiers at the Energy & Environmental Research Center (EERC). The CABRE III model is expected to further advance the knowledge base for the NCHT® Program and, more importantly, allow for prediction of the slagging and fouling characteristics of fuels in reducing environments. The information obtained from this program will potentially also assist in maintaining prolonged gasifier operation free from failure or facilitate troubleshooting to minimize downtime in the event of a problem.

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

    SciTech Connect (OSTI)

    Siefert, Nicholas S.; Shekhawat, Dushyant; Litster, Shawn; Berry, David, A

    2013-08-01T23:59:59.000Z

    We present experimental results of coal gasification with and without the addition of calcium oxide and potassium hydroxide as dual-functioning catalyst–capture agents. Using two different coal types and temperatures between 700 and 900 °C, we studied the effect of these catalyst–capture agents on (1) the syngas composition, (2) CO{sub 2} and H{sub 2}S capture, and (3) the steam–coal gasification kinetic rate. The syngas composition from the gasifier was roughly 20% methane, 70% hydrogen, and 10% other species when a CaO/C molar ratio of 0.5 was added. We demonstrated significantly enhanced steam–coal gasification kinetic rates when adding small amounts of potassium hydroxide to coal when operating a CaO–CaCO{sub 3} chemical looping gasification reactor. For example, the steam–coal gasification kinetic rate increased 250% when dry mixing calcium oxide at a Ca/C molar ratio of 0.5 with a sub-bituminous coal, and the kinetic rate increased 1000% when aqueously mixing calcium oxide at a Ca/C molar ratio of 0.5 along with potassium hydroxide at a K/C molar ratio of 0.06. In addition, we conducted multi-cycle studies in which CaCO{sub 3} was calcined by heating to 900 °C to regenerate the CaO, which was then reused in repeated CaO–CaCO{sub 3} cycles. The increased steam–coal gasification kinetics rates for both CaO and CaO + KOH persisted even when the material was reused in six cycles of gasification and calcination. The ability of CaO to capture carbon dioxide decreased roughly 2–4% per CaO–CaCO{sub 3} cycle. We also discuss an important application of this combined gasifier–calciner to electricity generation and selling the purge stream as a precalcined feedstock to a cement kiln. In this scenario, the amount of purge stream required is fixed not by the degradation in the capture ability but rather by the requirements at the cement kiln on the amount of CaSO{sub 4} and ash in the precalcined feedstock.

  10. Toxic substances from coal combustion -- A comprehensive assessment

    SciTech Connect (OSTI)

    C.L. Senior; T. Panagiotou; F.E. Huggins; G.P. Huffman; N. Yap; J.O.L. Wendt; W. Seames; M.R. Ames; A.F Sarofim; J. Lighty; A. Kolker; R. Finkelman; C.A. Palmer; S.J. Mroczkowsky; J.J. Helble; R. Mamani-Paco

    1999-11-01T23:59:59.000Z

    The Clean Air Act Amendments of 1990 identify a number of hazardous air pollutants (HAPs) as candidates for regulation. Should regulations be imposed on HAP emissions from coal-fired power plants, a sound understanding of the fundamental principles controlling the formation and partitioning of toxic species during coal combustion will be needed. With support from the Federal Energy Technology Center (FETC), the Electric Power Research Institute, and VTT (Finland), Physical Sciences Inc. (PSI) has teamed with researchers from USGS, MIT, the University of Arizona (UA), the University of Kentucky (UK), the University of Connecticut (UC), the University of Utah (UU) and the University of North Dakota Energy and Environmental Research Center (EERC) to develop a broadly applicable emissions model useful to regulators and utility planners. The new Toxics Partitioning Engineering Model (ToPEM) will be applicable to all combustion conditions including new fuels and coal blends, low-NOx combustion systems, and new power generation plants. Development of ToPEM will be based on PSI's existing Engineering Model for Ash Formation (EMAF). This report covers the reporting period from 1 July 1999 to 30 September 1999. During this period the MIT INAA procedures were revised to improve the quality of the analytical results. Two steps have been taken to reduce the analytical errors. A new nitric acid leaching procedure, modified from ASTM procedure D2492, section 7.3.1 for determination of pyritic sulfur, was developed by USGS and validated. To date, analytical results have been returned for all but the last complete round of the four-step leaching procedure. USGS analysts in Denver have halted development of the cold vapor atomic fluorescence technique for mercury analysis procedure in favor of a new direct analyzer for Hg that the USGS is in the process of acquiring. Since early June, emphasis at USGS has been placed on microanalysis of clay minerals in project coals in preparation for use of the Stanford/USGS SHRIMP RG Ion Microprobe during August 1999. The SHRIMP-RG data confirm that Cr is present at concentrations of about 20 to 120 ppm, just below the electron microprobe detection limits (100 to 200 ppm), as suspected from Phase 1 microprobe work and previous studies of clay mineral separates. The University of Utah has started trial runs on the drop tube furnace to ensure that the gas analysis system is working properly and that the flow pattern within the furnace is laminar and direct. A third set of ASTM samples will be prepared at the University of Utah for the Phase 1 and Phase 2 coals. This time the INAA counting time will be optimized for the elements in which the authors are interested, guided by the results from the first two samples. The iodated charcoal which was used by MIT for vapor phase Hg collection was tested to see whether it collected other vapor phase metals. A second set of tests were performed at PSI using the entrained flow reactor (EFR). The University of Arizona's pilot-scale downflow laboratory combustion furnace was used to test the partitioning of toxic metals in the baseline experiments for the Phase 2 North Dakota lignite and the Pittsburgh seam bituminous coal at baghouse inlet sampling conditions. In addition, baseline data were collected on combustion of the Phase 1 Kentucky Elkhorn/Hazard bituminous coal. Emphasis at the University of Kentucky was placed on (1) collection of new Hg XAFS data for various sorbents, and (2) on collection of XAFS and other data for arsenic, sulfur, chromium and selenium in two baseline ash samples from the University of Arizona combustion unit. A preliminary interpretation of the mercury data is given in this report. Revision was made to the matrix for the initial experiments on mercury-ash interactions to be conducted at EERC. The overall goal of this effort is to collect data which will allow one to model the interactions of mercury and fly ash (specifically, adsorption of Hg{sup 0} and Hg{sup +2} and oxidation of Hg{sup 0}) in the air heater and particulate control dev

  11. Long-Term Carbon Injection Field Test for 90% Mercury Removal for a PRB Unit a Spray Dryer and Fabric Filter

    SciTech Connect (OSTI)

    Sjostrom, Sharon; Amrhein, Jerry

    2009-04-30T23:59:59.000Z

    The power industry in the U.S. is faced with meeting regulations to reduce the emissions of mercury compounds from coal-fired plants. Injecting a sorbent such as powdered activated carbon (PAC) into the flue gas represents one of the simplest and most mature approaches to controlling mercury emissions from coal-fired boilers. The purpose of this test program was to evaluate the long-term mercury removal capability, long-term mercury emissions variability, and operating and maintenance (O&M) costs associated with sorbent injection on a configuration being considered for many new plants. Testing was conducted by ADA Environmental Solutions (ADA) at Rocky Mountain Power’s (RMP) Hardin Station through funding provided by DOE/NETL, RMP, and other industry partners. The Hardin Station is a new plant rated at 121 MW gross that was first brought online in April of 2006. Hardin fires a Powder River Basin (PRB) coal and is configured with selective catalytic reduction (SCR) for NOx control, a spray dryer absorber (SDA) for SO2 control, and a fabric filter (FF) for particulate control. Based upon previous testing at PRB sites with SCRs, very little additional mercury oxidation from the SCR was expected at Hardin. In addition, based upon results from DOE/NETL Phase II Round I testing at Holcomb Station and results from similarly configured sites, low native mercury removal was expected across the SDA and FF. The main goal of this project was met—sorbent injection was used to economically and effectively achieve 90% mercury control as measured from the air heater (AH) outlet to the stack for a period of ten months. This goal was achieved with DARCO® Hg-LH, Calgon FLUEPAC®-MC PLUS and ADA Power PAC PREMIUM brominated activated carbons at nominal loadings of 1.5–2.5 lb/MMacf. An economic analysis determined the twenty-year levelized cost to be 0.87 mills/kW-hr, or $15,000/lb Hg removed. No detrimental effects on other equipment or plant operations were observed. The results of this project also filled a data gap for plants firing PRB coal and configured with an SCR, SDA, and FF, as many new plants are being designed today. Another goal of the project was to evaluate, on a short-term basis, the mercury removal associated with coal additives and coal blending with western bituminous coal. The additive test showed that, at this site, the coal additive known as KNX was affective at increasing mercury removal while decreasing sorbent usage. Coal blending was conducted with two different western bituminous coals, and West Elk coal increased native capture from nominally 10% to 50%. Two additional co-benefits were discovered at this site. First, it was found that native capture increased from nominally 10% at full load to 50% at low load. The effect is believed to be due to an increase in mercury oxidation across the SCR caused by a corresponding decrease in ammonia injection when the plant reduces load. Less ammonia means more active oxidation sites in the SCR for the mercury. The second co-benefit was the finding that high ammonia concentrations can have a negative impact on mercury removal by powdered activated carbon. For a period of time, the plant operated with a high excess of ammonia injection necessitated by the plugging of one-third of the SCR. Under these conditions and at high load, the mercury control system could not maintain 90% removal even at the maximum feed rate of 3.5 lb/MMacf (pounds of mercury per million actual cubic feet). The plant was able to demonstrate that mercury removal was directly related to the ammonia injection rate in a series of tests where the ammonia rate was decreased, causing a corresponding increase in mercury removal. Also, after the SCR was refurbished and ammonia injection levels returned to normal, the mercury removal performance also returned to normal. Another goal of the project was to install a commercial-grade activated carbon injection (ACI) system and integrate it with new-generation continuous emissions monitors for mercury (Hg-CEMs) to allow automatic feedback control on outlet me

  12. Development of an Advanced Deshaling Technology to Improve the Energy Efficiency of Coal Handling, Processing, and Utilization Operations

    SciTech Connect (OSTI)

    Rick Honaker; Gerald Luttrell

    2007-09-30T23:59:59.000Z

    The concept of using a dry, density-based separator to achieve efficient, near-face rock removal, commonly referred to as deshaling, was evaluated in several applications across the U.S.. Varying amounts of high-density rock exist in most run-of-mine feed. In the central Appalachian coalfields, a rock content exceeding 50% in the feed to a preparation plant is commonplace due to high amounts of out-of-seam dilution made necessary by extracting coal from thin seams. In the western U.S, an increase in out-of-seam dilution and environmental regulations associated with combustion emissions have resulted in a need to clean low rank coals and dry cleaning may be the only option. A 5 ton/hr mobile deshaling unit incorporating a density-based, air-table technology commercially known as the FGX Separator has been evaluated at mine sites located within the states of Utah, Wyoming, Texas, West Virginia, Virginia, Pennsylvania and Kentucky. The FGX technology utilizes table riffling principles with air as the medium. Air enters through the table and creates a fluidized bed of particles comprised of mostly fine, high density particles. The high density particle bed lifts the low-density coal particles to the top of the bed. The low-density coal moves toward the front of the table due to mass action and the downward slope of the table. The high-density particles settle through the fluidized particle bed and, upon making contact with the table, moves toward the back of the table with the assistance of table vibration. As a result, the low-density coal particles exit the front of the table closest to the feed whereas the high-density, high-ash content particles leave on the side and front of the table located at the farthest from the feed entry. At each test site, the run-of-mine feed was either directly fed to the FGX unit or pre-screened to remove the majority of the -6mm material. The surface moisture of the feed must be maintained below 9%. Pre-screening is required when the surface moisture of the feed coal exceeds the maximum limit. However, the content of -6mm in the feed to the FGX separator should be maintained between 10% and 20% to ensure an adequate fluidized bed. A parametric evaluation was conducted using a 3-level experimental design at each test site to identify the optimum separation performance and parameter values. The test data was used to develop empirical expressions that describe the response variables (i.e., mass yield and product ash content) as a function of the operating parameter values. From this process, it was established that table frequency and longitudinal slope are the most critical factors in controlling both mass yield and clean coal ash while the cross table slope was the least significant. Fan blower frequency is a critical parameter that controls mass yield. Although the splitter positions between product and middling streams and the middling and tailing streams were held constant during the tests, a separate evaluation indicated that performance is sensitive to splitter position within certain lengths of the table and insensitive in others. For a Utah bituminous coal, the FGX separator provided clean coal ash contents that ranged from a low of 8.57% to a high of 12.48% from a feed coal containing around 17% ash. From the 29 tests involved in the statistically designed test program, the average clean coal ash content was 10.76% while the tailings ash content averaged around 72%. One of the best separation performances achieved an ash reduction from 17.36% to 10.67% while recovering 85.9% of the total feed mass, which equated to an ash rejection value of around 47%. The total sulfur content was typically decreased from 1.61% to 1.49%. These performances were quantified by blending the middlings stream with the clean coal product. At a second Utah site, coal sources from three different bituminous coal seams were treated by the FGX deshaling unit. Three parameter values were varied based on the results obtained from Site No. 1 to obtain the optimum results shown in Table E-1. Approximately 9 tests w

  13. PARTICULATE CHARACTERIZATION AND ULTRA LOW-NOx BURNER FOR THE CONTROL OF NO{sub x} AND PM{sub 2.5} FOR COAL FIRED BOILERS

    SciTech Connect (OSTI)

    Ralph Bailey; Hamid Sarv; Jim Warchol; Debi Yurchison

    2001-09-30T23:59:59.000Z

    In response to the serious challenge facing coal-fired electric utilities with regards to curbing their NO{sub x} and fine particulate emissions, Babcock and Wilcox and McDermott Technology, Inc. conducted a project entitled, ''Particulate Characterization and Ultra Low-NO{sub x} Burner for the Control of NO{sub x} and PM{sub 2.5} for Coal Fired Boilers.'' The project included pilot-scale demonstration and characterization of technologies for removal of NO{sub x} and primary PM{sub 2.5} emissions. Burner development and PM{sub 2.5} characterization efforts were based on utilizing innovative concepts in combination with sound scientific and fundamental engineering principles and a state-of-the-art test facility. Approximately 1540 metric tonnes (1700 tons) of high-volatile Ohio bituminous coal were fired. Particulate sampling for PM{sub 2.5} emissions characterization was conducted in conjunction with burner testing. Based on modeling recommendations, a prototype ultra low-NO{sub x} burner was fabricated and tested at 100 million Btu/hr in the Babcock and Wilcox Clean Environment Development Facility. Firing the unstaged burner with a high-volatile bituminous Pittsburgh 8 coal at 100 million Btu/hr and 17% excess air achieved a NO{sub x} goal of 0.20 lb NO{sub 2}/million Btu with a fly ash loss on ignition (LOI) of 3.19% and burner pressure drop of 4.7 in H{sub 2}O for staged combustion. With the burner stoichiometry set at 0.88 and the overall combustion stoichiometry at 1.17, average NO{sub x} and LOI values were 0.14 lb NO{sub 2}/million Btu and 4.64% respectively. The burner was also tested with a high-volatile Mahoning 7 coal. Based on the results of this work, commercial demonstration is being pursued. Size classified fly ash samples representative of commercial low-NO{sub x} and ultra low-NO{sub x} combustion of Pittsburgh 8 coal were collected at the inlet and outlet of an ESP. The mass of size classified fly ash at the ESP outlet was sufficient to evaluate the particle size distribution, but was of insufficient size to permit reliable chemical analysis. The size classified fly ash from the inlet of the ESP was used for detailed chemical analyses. Chemical analyses of the fly ash samples from the ESP outlet using a high volume sampler were performed for comparison to the size classified results at the inlet. For all test conditions the particulate removal efficiency of the ESP exceeded 99.3% and emissions were less than the NSPS limits of {approx}48 mg/dscm. With constant combustion conditions, the removal efficiency of the ESP increased as the ESP voltage and Specific Collection Area (SCA) increased. The associated decrease in particle emissions occurred in size fractions both larger and smaller than 2.5 microns. For constant ESP voltage and SCA, the removal efficiency for the ultra low-NO{sub x} combustion ash (99.4-99.6%) was only slightly less than for the low-NO{sub x} combustion ash (99.7%). The decrease in removal efficiency was accompanied by a decrease in ESP current. The emission of PM{sub 2.5} from the ESP did not change significantly as a result of the change in combustion conditions. Most of the increase in emissions was in the size fraction greater than 2.5 microns, indicating particle re-entrainment. These results may be specific to the coal tested in this program. In general, the concentration of inorganic elements and trace species in the fly ash at the ESP inlet was dependent on the particle size fraction. The smallest particles tended to have higher concentrations of inorganic elements/trace species than larger particles. The concentration of most elements by particle size range was independent of combustion condition and the concentration of soluble ions in the fly ash showed little change with combustion condition when evaluated on a carbon free basis.

  14. Fate of Mercury in Synthetic Gypsum Used for Wallboard Production

    SciTech Connect (OSTI)

    Jessica Marshall Sanderson

    2006-06-01T23:59:59.000Z

    This report presents and discusses results from Task 5 of the study ''Fate of Mercury in Synthetic Gypsum Used for Wallboard Production,'' performed at a full-scale commercial wallboard plant. Synthetic gypsum produced by wet flue gas desulfurization (FGD) systems on coal-fired power plants is commonly used in the manufacture of wallboard. The FGD process is used to control the sulfur dioxide emissions which would result in acid rain if not controlled. This practice has long benefited the environment by recycling the FGD gypsum byproduct, which is becoming available in increasing quantities, decreasing the need to landfill this material, and increasing the sustainable design of the wallboard product. However, new concerns have arisen as recent mercury control strategies developed for power plants involve the capture of mercury in FGD systems. The objective of this study is to determine whether any mercury is released into the atmosphere when the synthetic gypsum material is used as a feedstock for wallboard production. The project is being co-funded by the U.S. DOE National Energy Technology Laboratory (Cooperative Agreement DE-FC26-04NT42080), USG Corporation, and EPRI. USG Corporation is the prime contractor, and URS Group is a subcontractor. The project scope includes five discrete tasks, each conducted at various USG wallboard plants using synthetic gypsum from different FGD systems. The five tasks were to include (1) a baseline test, then variations representing differing power plant (2) emissions control configurations, (3) treatment of fine gypsum particles, (4) coal types, and (5) FGD reagent types. However, Task 5, which was to evaluate gypsum produced from an alternate FGD reagent, could not be conducted as planned. Instead, Task 5 was conducted at conditions similar to a previous task, Task 3, although with gypsum from an alternate FGD system. In this project, process stacks in the wallboard plant have been sampled using the Ontario Hydro method. The stack locations sampled for each task include a dryer for the wet gypsum as it enters the plant and a gypsum calciner. The stack of the dryer for the wet wallboard product was also tested as part of this task, and was tested as part of Tasks 1 and 4. Also at each site, in-stream process samples were collected and analyzed for mercury concentration before and after each significant step in wallboard production. The Ontario Hydro results, process sample mercury concentration data, and process data were used to construct mercury mass balances across the wallboard plants. Task 5 was conducted at a wallboard plant processing synthetic gypsum from a power plant that fires Eastern bituminous coal. The power plant is equipped with a selective catalytic reduction (SCR) system for NOX emissions control, but the SCR was bypassed during the time period the gypsum tested was produced. The power plant has a single-loop, open spray tower, limestone reagent FGD system, with forced oxidation conducted in a reaction tank integral with the FGD absorber. The FGD system has gypsum fines blow down as part of the dewatering step. Gypsum fines blow down is believed to be an important variable that impacts the amount of mercury in the gypsum byproduct and possibly its stability during the wallboard process. The results of the Task 5 stack testing, as measured by the Ontario Hydro method, detected that an average of 51% of the incoming mercury in the FGD gypsum was emitted during wallboard production. These losses were distributed as 2% or less each across the wet gypsum dryer and product wallboard dryer, and about 50% across the gypsum calciner. Emissions were similar to what Task 3 results showed, on both a percentage and a mass basis, for gypsum produced by a power plant firing bituminous coal and also having gypsum fines blow down as part of the FGD dewatering scheme. As was seen in the Task 1 through 4 results, most of the mercury detected in the stack testing on the wet gypsum dryer and kettle calciner was in the form of elemental mercury. In the wallboard dryer kiln, a more signific

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

    SciTech Connect (OSTI)

    Alptekin, Gokhan

    2013-09-30T23:59:59.000Z

    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.

  16. SEQUESTERING CARBON DIOXIDE IN COALBEDS

    SciTech Connect (OSTI)

    K.A.M. Gasem; R.L. Robinson, Jr.; L.R. Radovic

    2001-06-15T23:59:59.000Z

    The authors' long term goal is to develop accurate prediction methods for describing the adsorption behavior of gas mixtures on solid adsorbents over complete ranges of temperature, pressure and adsorbent types. The major objectives of the project are to: (1) measure the adsorption behavior of pure CO{sub 2}, methane, nitrogen and their binary and ternary mixtures on several selected coals having different properties at temperatures and pressures applicable to the particular coal being studied, (2) generalize the adsorption results in terms of appropriate properties of the coals, to facilitate estimation of adsorption behavior for coals other than those studied experimentally, (3) delineate the sensitivity of the competitive adsorption of CO{sub 2}, methane and nitrogen to the specific characteristics of the coal on which they are adsorbed; establish the major differences (if any) in the nature of this competitive adsorption on different coals, and (4) test and/or develop theoretically-based mathematical models to represent accurately the adsorption behavior of mixtures of the type for which measurements are made. The specific accomplishments of this project during this reporting period are summarized below in three broad categories outlining experimentation, model development, and coal characterization. (1) Experimental Work: Our adsorption apparatus was reassembled, and all instruments were tested and calibrated. Having confirmed the viability of the experimental apparatus and procedures used, adsorption isotherms for pure methane, carbon dioxide and nitrogen on wet Fruitland coal were measured at 319.3 K (115 F) and pressures to 12.4 MPa (1800 psia). These measurements showed good agreement with our previous data and yielded an expected uncertainty of about 2%. Preparations are underway to measure adsorption isotherms for pure methane, carbon dioxide and nitrogen on two other coals. (2) Model Development: The experimental data were used to evaluate the predictive capabilities of various adsorption models, including the Langmuir/loading ratio correlation, two-dimensional cubic equations of state, and the local density model. In general, all models performed well for Type I adsorption exhibited by methane, nitrogen, and carbon dioxide up to 8.3 MPa (average deviations within 2%). However, for pressures higher than 8.3 MPa (1200 psia), carbon dioxide produced multilayer adsorption behavior similar to Type IV adsorption. Our results to date indicate that the SLD model may be a suitable choice for modeling multilayer coalbed gas adsorption. However, model improvements are required to (a) account for coal heterogeneity and structure complexity, and (b) provide for more accurate density predictions. (3) Coal Characterization: We have identified several well-characterized coals for use in our adsorption studies. The criteria for coal selection has been guided by the need for coals that (a) span the spectrum of properties encountered in coalbed methane production (such as variation in rank), and (b) originate from coalbed methane recovery sites (e.g., San Juan Basin, Black Warrior Basin, etc.). At Pennsylvania State University, we have completed calibrating our instruments using a well-characterized activated carbon. In addition, we have conducted CO{sub 2} and methane uptakes on four samples, including (a) a widely used commercial activated carbon, BPL from Calgon Carbon Corp.; (b) an Illinois No.6 bituminous coal from the Argonne Premium Coal sample bank; (c) a Fruitland Intermediate coal sample; (d) a dry Fruitland sample. The results are as expected, except for a greater sensitivity to the outgassing temperature. ''Standard'' outgassing conditions (e.g., 383.2 K, overnight), which are often used, may not be appropriate for gas storage in coalbeds. Conditions that are more representative of in-situ coal (approximately 313.2 K) may be much more appropriate. In addition, our results highlight the importance of assessing the degree of approach to adsorption equilibrium.

  17. Evaluation of Gas Reburning and Low N0x Burners on a Wall Fired Boiler

    SciTech Connect (OSTI)

    None

    1998-09-01T23:59:59.000Z

    Under the U.S. Department of Energy's Clean Coal Technology Program (Round 3), a project was completed to demonstrate control of boiler emissions that comprise acid rain precursors, especially NOX. The project involved operating gas reburning technology combined with low NO, burner technology (GR-LNB) on a coal-fired utility boiler. Low NOX burners are designed to create less NOX than conventional burners. However, the NO, control achieved is in the range of 30-60-40, and typically 50%. At the higher NO, reduction levels, CO emissions tend to be higher than acceptable standards. Gas Reburning (GR) is designed to reduce the level of NO. in the flue gas by staged fuel combustion. When combined, GR and LNBs work in harmony to both minimize NOX emissions and maintain an acceptable level of CO emissions. The demonstration was performed at Public Service Company of Colorado's (PSCO) Cherokee Unit 3, located in Denver, Colorado. This unit is a 172 MW. wall-fired boiler that uses Colorado bituminous, low-sulfur coal and had a pre GR-LNB baseline NOX emission of 0.73 lb/1 Oe Btu. The target for the project was a reduction of 70 percent in NOX emissions. Project sponsors included the U.S. Department of Energy, the Gas Research Institute, Public Service Company of Colorado, Colorado Interstate Gas, Electric Power Research Institute, and the Energy and Environmental Research Corporation (EER). EER conducted a comprehensive test demonstration program over a wide range of boiler conditions. Over 4,000 hours of operation were achieved. Intensive measurements were taken to quantify the reductions in NOX emissions, the impact on boiler equipment and operability, and all factors influencing costs. The results showed that GR-LNB technology achieved excellent emission reductions. Although the performance of the low NOX burners (supplied by others) was somewhat less than expected, a NOX reduction of 65% was achieved at an average gas heat input of 180A. The performance goal of 70% reduction was met on many test runs, but at higher gas heat inputs. The impact on boiler equipment was determined to be very minimal. Toward the end of the testing, the flue gas recirculation (used to enhance gas penetration into the furnace) system was removed and new high pressure gas injectors were installed. Further, the low NOX burners were modified and gave better NO. reduction performance. These modifications resulted in a similar NO, reduction performance (64%) at a reduced level of gas heat input (-13Yo). In addition, the OFA injectors were re-designed to provide for better control of CO emissions. Although not a part of this project, the use of natural gas as the primary fuel with gas reburning was also tested. The gas/gas reburning tests demonstrated a reduction in NOX emissions of 43% (0.30 lb/1 OG Btu reduced to 0.17 lb/1 OG Btu) using 7% gas heat input. Economics are a key issue affecting technology development. Application of GR-LNB requires modifications to existing power plant equipment and as a result, the capital and operating costs depend largely on site-specific factors such as: gas availability at the site, gas to coal delivered price differential, sulfur dioxide removal requirements, windbox pressure, existing burner throat diameters, and reburn zone residence time available. Based on the results of this CCT project, EER expects that most GR-LNB installations will achieve at least 60% NOX control when firing 10-15% gas. The capital cost estimate for installing a GR-LNB system on a 300 MW, unit is approximately $25/kW. plus the cost of a gas pipeline (if required). Operating costs are almost entirely related to the differential cost of the natural gas compared to coal.

  18. Evaluation of MerCAP for Power Plant Mercury Control

    SciTech Connect (OSTI)

    Carl Richardson

    2008-09-30T23:59:59.000Z

    This report is submitted to the U.S. Department of Energy National Energy Technology Laboratory (DOE-NETL) as part of Cooperative Agreement DE-FC26-03NT41993, 'Evaluation of EPRI's MerCAP{trademark} Technology for Power Plant Mercury Control'. This project has investigated the mercury removal performance of EPRI's Mercury Capture by Amalgamation Process (MerCAP{trademark}) technology. Test programs were conducted to evaluate gold-based MerCAP{trademark} at Great River Energy's Stanton Station Unit 10 (Site 1), which fired both North Dakota lignite (NDL) and Power River Basin (PRB) coal during the testing period, and at Georgia Power's Plant Yates Unit 1 (Site 2) [Georgia Power is a subsidiary of The Southern Company] which fires a low sulfur Eastern bituminous coal. Additional tests were carried out at Alabama Power's Plant Miller, which fires Powder River Basin Coal, to evaluate a carbon-based MerCAP{trademark} process for removing mercury from flue gas downstream of an electrostatic precipitator [Alabama Power is a subsidiary of The Southern Company]. A full-scale gold-based sorbent array was installed in the clean-air plenum of a single baghouse compartment at GRE's Stanton Station Unit 10, thereby treating 1/10th of the unit's exhaust gas flow. The substrates that were installed were electroplated gold screens oriented parallel to the flue gas flow. The sorbent array was initially installed in late August of 2004, operating continuously until its removal in July 2006, after nearly 23 months. The initial 4 months of operation were conducted while the host unit was burning North Dakota lignite (NDL). In November 2004, the host unit switched fuel to burn Powder River Basin (PRB) subbituminous coal and continued to burn the PRB fuel for the final 19 months of this program. Tests were conducted at Site 1 to evaluate the impacts of flue gas flow rate, sorbent plate spacing, sorbent pre-cleaning and regeneration, and spray dryer operation on MerCAP{trademark} performance. At Site 2, a pilot-scale array was installed in a horizontal reactor chamber designed to treat approximately 2800 acfm of flue gas obtained from downstream of the plant's flue gas desulfurization (FGD) system. The initial MerCAP{trademark} array was installed at Plant Yates in January 2004, operating continuously for several weeks before a catastrophic system failure resulting from a failed flue gas fan. A second MerCAP{trademark} array was installed in July 2006 and operated for one month before being shut down for a reasons pertaining to system performance and host site scheduling. A longer-term continuous-operation test was then conducted during the summer and fall of 2007. Tests were conducted to evaluate the impacts of flue gas flow rate, sorbent space velocity, and sorbent rinsing frequency on mercury removal performance. Detailed characterization of treated sorbent plates was carried out in an attempt to understand the nature of reactions leading to excessive corrosion of the substrate surfaces.

  19. Greenridge Multi-Pollutant Control Project Preliminary Public Design Report

    SciTech Connect (OSTI)

    Daniel P. Connell

    2009-01-12T23:59:59.000Z

    The Greenidge Multi-Pollutant Control Project is being conducted as part of the U.S. Department of Energy's Power Plant Improvement Initiative to demonstrate an innovative combination of air pollution control technologies that can cost-effectively reduce emissions of SO{sub 2}, NO{sub x}, Hg, acid gases (SO{sub 3}, HCl, and HF), and particulate matter from smaller coal-fired electrical generating units (EGUs). The multi-pollutant control system includes a hybrid selective non-catalytic reduction (SNCR)/in-duct selective catalytic reduction (SCR) system to reduce NOx emissions by {ge}60%, followed by a Turbosorp{reg_sign} circulating fluidized bed dry scrubber system to reduce emissions of SO{sub 2}, SO{sub 3}, HCl, and HF by {ge}95%. Mercury removal of {ge}90% is also targeted via the co-benefits afforded by the in-duct SCR, dry scrubber, and baghouse and by injection of activated carbon upstream of the scrubber, as required. The technology is particularly well suited, because of its relatively low capital and maintenance costs and small space requirements, to meet the needs of coal-fired units with capacities of 50-300 MWe. There are about 440 such units in the United States that currently are not equipped with SCR, flue gas desulfurization (FGD), or mercury control systems. These smaller units are a valuable part of the nation's energy infrastructure, constituting about 60 GW of installed capacity. However, with the onset of the Clean Air Interstate Rule, Clean Air Mercury Rule, and various state environmental actions requiring deep reductions in emissions of SO{sub 2}, NO{sub x}, and mercury, the continued operation of these units increasingly depends upon the ability to identify viable air pollution control retrofit options for them. The large capital costs and sizable space requirements associated with conventional technologies such as SCR and wet FGD make these technologies unattractive for many smaller units. The Greenidge Project aims to confirm the commercial readiness of an emissions control system that is specifically designed to meet the environmental compliance requirements of these smaller coal-fired EGUs. The multi-pollutant control system is being installed and tested on the AES Greenidge Unit 4 (Boiler 6) by a team including CONSOL Energy Inc. as prime contractor, AES Greenidge LLC as host site owner, and Babcock Power Environmental Inc. as engineering, procurement, and construction contractor. All funding for the project is being provided by the U.S. Department of Energy, through its National Energy Technology Laboratory, and by AES Greenidge. AES Greenidge Unit 4 is a 107 MW{sub e} (net), 1950s vintage, tangentially-fired, reheat unit that is representative of many of the 440 smaller coal-fired units identified above. Following design and construction, the multi-pollutant control system will be demonstrated over an approximately 20-month period while the unit fires 2-4% sulfur eastern U.S. bituminous coal and co-fires up to 10% biomass. This Preliminary Public Design Report is the first in a series of two reports describing the design of the multi-pollutant control facility that is being demonstrated at AES Greenidge. Its purpose is to consolidate for public use all available nonproprietary design information on the Greenidge Multi-Pollutant Control Project. As such, the report includes a discussion of the process concept, design objectives, design considerations, and uncertainties associated with the multi-pollutant control system and also summarizes the design of major process components and balance of plant considerations for the AES Greenidge Unit 4 installation. The Final Public Design Report, the second report in the series, will update this Preliminary Public Design Report to reflect the final, as-built design of the facility and to incorporate data on capital costs and projected operating costs.

  20. Evaluation of Gas Reburning & Low NOx Burners on a Wall Fired Boiler Performance and Economics Report Gas Reburning-Low NOx Burner System Cherokee Station Unit 3 Public Service Company of Colorado

    SciTech Connect (OSTI)

    None

    1998-07-01T23:59:59.000Z

    Under the U.S. Department of Energy's Clean Coal Technology Program (Round 3), a project was completed to demonstrate control of boiler NOX emissions and to a lesser degree, due to coal replacement, SO2 emissions. The project involved combining Gas Reburning with Low NOX Burners (GR-LNB) on a coal-fired electric utility boiler to determine if high levels of NOX reduction (70%) could be achieved. Sponsors of the project included the U.S. Department of Energy, the Gas Research Institute, Public Service Company of Colorado, Colorado Interstate Gas, Electric Power Research Institute, and the Energy and Environmental Research Corporation. The GR-LNB demonstration was performed on Public Service Company of Colorado's (PSCO) Cherokee Unit #3, located in Denver, Colorado. This unit is a 172 MW~ wall-fired boiler that uses Colorado Bituminous, low-sulfur coal. It had a baseline NOX emission level of 0.73 lb/106 Btu using conventional burners. Low NOX burners are designed to yield lower NOX emissions than conventional burners. However, the NOX control achieved with this technique is limited to 30-50%. Also, with LNBs, CO emissions can increase to above acceptable standards. Gas Reburning (GR) is designed to reduce NOX in the flue gas by staged fuel combustion. This technology involves the introduction of natural gas into the hot furnace flue gas stream. When combined, GR and LNBs minimize NOX emissions and maintain acceptable levels of CO emissions. A comprehensive test program was completed, operating over a wide range of boiler conditions. Over 4,000 hours of operation were achieved, providing substantial data. Measurements were taken to quantify reductions in NOX emissions, the impact on boiler equipment and operability and factors influencing costs. The GR-LNB technology achieved good NOX emission reductions and the goals of the project were achieved. Although the performance of the low NOX burners (supplied by others) was less than expected, a NOX reduction of 65% was achieved at an average gas heat input of 18Y0. The performance goal of 70% reduction was met on many test runs, but at a higher reburn gas heat input. S02 emissions, based on coal replacement, were reduced by 18Y0. The performance goal of 70% reduction was met on many test runs, but at a higher reburn gas heat input. S02 emissions, based on coal replacement, were reduced by 18Y0. Toward the end of the program, a Second Generation gas injection system was installed. Higher injector gas pressures were used that eliminated the need for flue gas recirculation as used in the first generation design. The Second Generation GR resulted in similar NOX reduction performance as that for the First Generation. With an improvement in the LNB performance in combination with the new gas injection system , the reburn gas could be reduced to 12.5% of the total boiler heat input to achieve al 64?40 reduction in NO, emissions. In addition, the OFA injectors were modified to provide for better mixing to lower CO emissions.

  1. FIELD TEST PROGRAM TO DEVELOP COMPREHENSIVE DESIGN, OPERATING AND COST DATA FOR MERCURY CONTROL SYSTEMS ON NON-SCRUBBED COAL-FIRED BOILERS

    SciTech Connect (OSTI)

    Richard Schlager

    2002-08-01T23:59:59.000Z

    With the Nation's coal-burning utilities facing the possibility of tighter controls on mercury pollutants, the U.S. Department of Energy is funding projects that could offer power plant operators better ways to reduce these emissions at much lower costs. Mercury is known to have toxic effects on the nervous system of humans and wildlife. Although it exists only in trace amounts in coal, mercury is released when coal burns and can accumulate on land and in water. In water, bacteria transform the metal into methylmercury, the most hazardous form of the metal. Methylmercury can collect in fish and marine mammals in concentrations hundreds of thousands times higher than the levels in surrounding waters. One of the goals of DOE is to develop technologies by 2005 that will be capable of cutting mercury emissions 50 to 70 percent at well under one-half of today's costs. ADA Environmental Solutions (ADA-ES) is managing a project to test mercury control technologies at full scale at four different power plants from 2000-2003. The ADA-ES project is focused on those power plants that are not equipped with wet flue gas desulfurization systems. ADA-ES will develop a portable system that will be moved to four different utility power plants for field testing. Each of the plants is equipped with either electrostatic precipitators or fabric filters to remove solid particles from the plant's flue gas. ADA-ES's technology will inject a dry sorbent, such as fly ash or activated carbon, that removes the mercury and makes it more susceptible to capture by the particulate control devices. A fine water mist may be sprayed into the flue gas to cool its temperature to the range where the dry sorbent is most effective. PG&E National Energy Group is providing two test sites that fire bituminous coals and both are equipped with electrostatic precipitators and carbon/ash separation systems. Wisconsin Electric Power Company is providing a third test site that burns Powder River Basin (PRB) coal and has an electrostatic precipitator for particulate control. Alabama Power Company will host a fourth test at its Plant Gaston, which is equipped with a hot-side electrostatic precipitator and a downstream fabric filter. During the seventh reporting quarter, progress was made on the project in the following areas: (1) PG&E NEG Brayton Point Station--Sorbent injection equipment was installed at the site during the quarter; Test plans were prepared for the field testing phase of the project; Baseline testing was completed during the quarter and parametric testing was begun; and A paper summarizing the full-scale tests was written and submitted to A&WMA for presentation at the annual meeting in June 2002. (2) Technology Transfer--A number of technical presentations and briefings were made during the quarter. Notable among them are papers published in the A&WMA EM journal and Pollution Engineering. Also, information was provided to the EPA MACT Working Group and a paper was presented at the annual A&WMA meeting.

  2. FIELD TEST PROGRAM TO DEVELOP COMPREHENSIVE DESIGN, OPERATING AND COST DATA FOR MERCURY CONTROL SYSTEMS ON NON-SCRUBBED COAL-FIRED BOILERS

    SciTech Connect (OSTI)

    Richard Schlager; Tom Millar

    2002-10-18T23:59:59.000Z

    With the Nation's coal-burning utilities facing the possibility of tighter controls on mercury pollutants, the U.S. Department of Energy is funding projects that could offer power plant operators better ways to reduce these emissions at much lower costs. Mercury is known to have toxic effects on the nervous system of humans and wildlife. Although it exists only in trace amounts in coal, mercury is released when coal burns and can accumulate on land and in water. In water, bacteria transform the metal into methylmercury, the most hazardous form of the metal. Methylmercury can collect in fish and marine mammals in concentrations hundreds of thousands times higher than the levels in surrounding waters. One of the goals of DOE is to develop technologies by 2005 that will be capable of cutting mercury emissions 50 to 70 percent at well under one-half of today's costs. ADA Environmental Solutions (ADA-ES) is managing a project to test mercury control technologies at full scale at four different power plants from 2000-2003. The ADA-ES project is focused on those power plants that are not equipped with wet flue gas desulfurization systems. ADA-ES has developed a portable system that will be tested at four different utility power plants. Each of the plants is equipped with either electrostatic precipitators or fabric filters to remove solid particles from the plant's flue gas. ADA-ES's technology will inject a dry sorbent, such as activated carbon, which removes the mercury and makes it more susceptible to capture by the particulate control devices. A fine water mist may be sprayed into the flue gas to cool its temperature to the range where the dry sorbent is most effective. PG&E National Energy Group is providing two test sites that fire bituminous coals and both are equipped with electrostatic precipitators and carbon/ash separation systems. Wisconsin Electric Power Company is providing a third test site that burns Powder River Basin (PRB) coal and has an electrostatic precipitator for particulate control. Alabama Power Company will host a fourth test at its Plant Gaston, which is equipped with a hot-side electrostatic precipitator and a downstream fabric filter. During the eighth reporting quarter, progress was made on the project in the following areas: (1) PG&E NEG Salem Harbor Station--Sorbent injection equipment was installed at the site during the quarter; Test plans were prepared for the field-testing phase of the project; and Baseline testing was completed during the quarter. (2) Technology Transfer--A number of technical presentations and briefings were made during the quarter. Notable among them was a paper published in the JAWMA. Also, two papers were presented at the Air Quality III Conference and one at the Pittsburgh Coal Conference.

  3. Thermodynamic modeling of volatile hazardous metal behavior in the Vortec Vitrification System

    SciTech Connect (OSTI)

    Nowok, J.W.; Hurley, J.P.

    2000-07-31T23:59:59.000Z

    The thermochemical equilibrium calculations indicate that at the temperature of a propane--air flame, some volatilization of uranium, plutonium, technetium, and cesium will occur. The expected concentrations of plutonium, technetium, and cesium in the flame will be very low because of the small maximum concentration of these elements in the projected feed materials for the first 30-day test. The quantities volatilized can generally be decreased by operating the flame in a fuel-rich mode, although this will lead to greater carbon monoxide production, which may be more objectionable. The concentrations of chlorine and fluorine, at least at the maximum levels in the projected Vortec feed, are not projected to greatly influence the vaporization rates. Therefore, blending to reduce the concentrations of those elements would most likely not be effective in reducing metal vaporization. Most of the elements vaporized condense by the time the gas cools to 2000 F. These elements would condense either on surfaces near the front of the heat recuperator or on entrained particulates or homogeneously as relatively pure submicron particles. Cesium would be expected to condense at the lower temperatures near the rear of the recuperator, although the expected maximum concentration in the Vortec feed material is extremely low so it should be greatly diluted by other particulates. The elements that condense on other entrained particles will form enriched surface coatings. Particles larger than 10{micro}m or so will be collected in the scrubber. Smaller particles, especially the submicron particles formed from homogeneous nucleation, should be largely collected in the HEPA filter. Deposits formed in the heat recuperator can normally be handled via sootblowing. To reduce handling problems, we suggest that the recuperator be oriented vertically so that the deposits blown off of the heat exchanger fall directly into the molten glass. The large size of the deposits should help to reduce the rate of revaporization, allowing the volatile elements to be removed with the glass. The volatile elements that do not deposit on system surfaces will be concentrated in the smaller particles. Therefore, the HEPA ash will be greatly enriched in these elements. If the HEPA filter is itself sent to a melter, the elements may revaporize and multiply the problems related to metal vaporization significantly. Therefore, the HEPA filters should be disposed of without high-temperature processing. Also, to reduce the formation of these very small particles, it is helpful to include in the feed larger particles to act as condensation nuclei that can then be collected in the scrubber. This can be accomplished by using feed materials with a fraction consisting of particles small enough that they will not be collected in the cyclone in the melter, but large enough that they will easily be collected by the scrubber. This is one advantage that firing bituminous coal has over gas firing; it provides a source of ash particles of the right size range to serve as nucleation sites, but large enough (depending on the coal) so that they can usually be collected efficiently in the scrubber system.

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

    SciTech Connect (OSTI)

    Santosh Gangwal

    2011-06-30T23:59:59.000Z

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

  5. Evaluation of Regenerated Catalyst for Mercury Speciation

    SciTech Connect (OSTI)

    Dennis Laudal

    2007-06-01T23:59:59.000Z

    In March of 2005, U.S. Environmental Protection Agency (EPA) promulgated the Clean Air Mercury Rule (CAMR). Mercury from coal-fired power plants was to be reduced from the current 48 to 38 tons/yr by 2010 and then 15 tons/yr by 2018. It is expected that the first phase reduction of {approx}21% will be achieved by cobenefits that will occur as a result of installing additional selective catalytic reduction (SCR) and flue gas desulfurization (FGD) systems to meet the new Clean Air Interstate Rule (CAIR). Detroit Edison (DTE) is installing SCR at all four units at its Monroe Station and will eventually install wet-FGD systems. As such, the Electric Power Research Institute (EPRI), the U.S. Department of Energy (DOE), and DTE have contracted with the Energy & Environmental Research Center (EERC) to determine the extent of mercury oxidation that occurs at Monroe Station. The EERC originally did mercury speciation sampling at Monroe Station in 2004 and then went back in 2005 to determine if any changes occurred as a result of catalyst aging. During the second test, in addition to measuring the mercury speciation at the inlet and outlet of the SCR, the EERC also completed sampling at a location between the catalyst layers. The results are shown in Table 1. In Table 1, the results show that {approx}40% of the Hg was in oxidized form (Hg{sup 2+}) at the inlet and nearly 100% Hg{sup 2+} at the outlet. The results at the midpoint were between 40% and 100%. As part of their overall strategy to reduce SCR costs, utilities and SCR vendors are attempting to regenerate catalyst layers that have degenerated over time. If these regenerated catalysts are used, the question remains as to the effect this process will have on the ability of these catalysts to oxidize mercury as well as reduce NO{sub x}. The current project is designed to measure the Hg speciation across an SCR using a regenerated catalyst. The results were compared to previous results to determine what, if any, changes occurred. Two series of tests were completed: one early in the ozone season (July 2006) and the second near the end (September 2006). The goal of this project is to determine the effect SCR catalyst regeneration has on Hg speciation and emissions from combustion of a blend of eastern bituminous and Powder River Basin (PRB) coal at DTE's Monroe Station. Specific objectives include the following: (1) Compare the Hg speciation results at the inlet and outlet of the SCR. Determine the change in the concentration of oxidized Hg across the SCR. In addition, determine if the number of catalyst layers has any effect. (2) Compare results from previous testing to determine if there are changes in mercury speciation as a result of catalyst regeneration. (3) Determine the overall speciated Hg emissions (from a separate project funded by DTE).

  6. Partial Oxidation Gas Turbine for Power and Hydrogen Co-Production from Coal-Derived Fuel in Industrial Applications

    SciTech Connect (OSTI)

    Joseph Rabovitser

    2009-06-30T23:59:59.000Z

    The report presents a feasibility study of a new type of gas turbine. A partial oxidation gas turbine (POGT) shows potential for really high efficiency power generation and ultra low emissions. There are two main features that distinguish a POGT from a conventional gas turbine. These are associated with the design arrangement and the thermodynamic processes used in operation. A primary design difference of the POGT is utilization of a non?catalytic partial oxidation reactor (POR) in place of a conventional combustor. Another important distinction is that a much smaller compressor is required, one that typically supplies less than half of the air flow required in a conventional gas turbine. From an operational and thermodynamic point of view a key distinguishing feature is that the working fluid, fuel gas provided by the OR, has a much higher specific heat than lean combustion products and more energy per unit mass of fluid can be extracted by the POGT expander than in the conventional systems. The POGT exhaust stream contains unreacted fuel that can be combusted in different bottoming ycle or used as syngas for hydrogen or other chemicals production. POGT studies include feasibility design for conversion a conventional turbine to POGT duty, and system analyses of POGT based units for production of power solely, and combined production of power and yngas/hydrogen for different applications. Retrofit design study was completed for three engines, SGT 800, SGT 400, and SGT 100, and includes: replacing the combustor with the POR, compressor downsizing for about 50% design flow rate, generator replacement with 60 90% ower output increase, and overall unit integration, and extensive testing. POGT performances for four turbines with power output up to 350 MW in POGT mode were calculated. With a POGT as the topping cycle for power generation systems, the power output from the POGT ould be increased up to 90% compared to conventional engine keeping hot section temperatures, pressures, and volumetric flows practically identical. In POGT mode, the turbine specific power (turbine net power per lb mass flow from expander exhaust) is twice the value of the onventional turbine. POGT based IGCC plant conceptual design was developed and major components have been identified. Fuel flexible fluid bed gasifier, and novel POGT unit are the key components of the 100 MW IGCC plant for co producing electricity, hydrogen and/or yngas. Plant performances were calculated for bituminous coal and oxygen blown versions. Various POGT based, natural gas fueled systems for production of electricity only, coproduction of electricity and hydrogen, and co production of electricity and syngas for gas to liquid and hemical processes were developed and evaluated. Performance calculations for several versions of these systems were conducted. 64.6 % LHV efficiency for fuel to electricity in combined cycle was achieved. Such a high efficiency arise from using of syngas from POGT exhaust s a fuel that can provide required temperature level for superheated steam generation in HRSG, as well as combustion air preheating. Studies of POGT materials and combustion instabilities in POR were conducted and results reported. Preliminary market assessment was performed, and recommendations for POGT systems applications in oil industry were defined. POGT technology is ready to proceed to the engineering prototype stage, which is recommended.

  7. Evaluation of a Combined Cyclone and Gas Filtration System for Particulate Removal in the Gasification Process

    SciTech Connect (OSTI)

    Rizzo, Jeffrey J. [Phillips66 Company, West Terre Haute, IN (United States)

    2010-04-30T23:59:59.000Z

    The Wabash gasification facility, owned and operated by sgSolutions LLC, is one of the largest single train solid fuel gasification facilities in the world capable of transforming 2,000 tons per day of petroleum coke or 2,600 tons per day of bituminous coal into synthetic gas for electrical power generation. The Wabash plant utilizes Phillips66 proprietary E-Gas (TM) Gasification Process to convert solid fuels such as petroleum coke or coal into synthetic gas that is fed to a combined cycle combustion turbine power generation facility. During plant startup in 1995, reliability issues were realized in the gas filtration portion of the gasification process. To address these issues, a slipstream test unit was constructed at the Wabash facility to test various filter designs, materials and process conditions for potential reliability improvement. The char filtration slipstream unit provided a way of testing new materials, maintenance procedures, and process changes without the risk of stopping commercial production in the facility. It also greatly reduced maintenance expenditures associated with full scale testing in the commercial plant. This char filtration slipstream unit was installed with assistance from the United States Department of Energy (built under DOE Contract No. DE-FC26-97FT34158) and began initial testing in November of 1997. It has proven to be extremely beneficial in the advancement of the E-Gas (TM) char removal technology by accurately predicting filter behavior and potential failure mechanisms that would occur in the commercial process. After completing four (4) years of testing various filter types and configurations on numerous gasification feed stocks, a decision was made to investigate the economic and reliability effects of using a particulate removal gas cyclone upstream of the current gas filtration unit. A paper study had indicated that there was a real potential to lower both installed capital and operating costs by implementing a char cyclonefiltration hybrid unit in the E-Gas (TM) gasification process. These reductions would help to keep the E-Gas (TM) technology competitive among other coal-fired power generation technologies. The Wabash combined cyclone and gas filtration slipstream test program was developed to provide design information, equipment specification and process control parameters of a hybrid cyclone and candle filter particulate removal system in the E-Gas (TM) gasification process that would provide the optimum performance and reliability for future commercial use. The test program objectives were as follows: 1. Evaluate the use of various cyclone materials of construction; 2. Establish the optimal cyclone efficiency that provides stable long term gas filter operation; 3. Determine the particle size distribution of the char separated by both the cyclone and candle filters. This will provide insight into cyclone efficiency and potential future plant design; 4. Determine the optimum filter media size requirements for the cyclone-filtration hybrid unit; 5. Determine the appropriate char transfer rates for both the cyclone and filtration portions of the hybrid unit; 6. Develop operating procedures for the cyclone-filtration hybrid unit; and, 7. Compare the installed capital cost of a scaled-up commercial cyclone-filtration hybrid unit to the current gas filtration design without a cyclone unit, such as currently exists at the Wabash facility.

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

    SciTech Connect (OSTI)

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

    2009-06-30T23:59:59.000Z

    This report summarizes Year 1 results of a research program designed to use multi-scale experimental studies and fundamental theoretical models to characterize and predict the impacts of retrofit of existing coal-fired utility boilers for oxy-combustion. Through the course of Year 1 activities, great progress was made toward understanding the issues associated with oxy-combustion retrofit of coal-fired boilers. All four Year 1 milestones and objectives have been, or will be, completed on schedule and within budget. Progress in the four milestone areas may be summarized as follows: • University of Utah has performed size segregated ash composition measurements in the Oxy-Fuel Combustor (OFC). These experiments indicate that oxy-combustion retrofit may impact ash aerosol mineral matter composition. Both flame temperature and flue gas composition have been observed to influence the concentration of calcium, magnesium and iron in the fine particulate. This could in turn impact boiler fouling and slagging. • Sandia National Labs has shown that char oxidation rate is dependent on particle size (for sizes between 60 and 100 microns) by performing fundamental simulations of reacting char particles. These predictions will be verified by making time-resolved optical measurements of char particle temperature, velocity and size in bench-scale experiments before the end of Year 1. • REI and Siemens have completed the design of an oxy-research burner that will be mounted on University of Utah’s pilot-scale furnace, the L1500. This burner will accommodate a wide range of O2, FGR and mixing strategies under conditions relevant for utility boiler operation. Through CFD modeling of the different burner designs, it was determined that the key factor influencing flame stabilization location is particle heat-up rate. The new oxy-research burner and associated equipment is scheduled for delivery before the end of Year 1. • REI has completed a literature survey of slagging and fouling mechanisms in coal-fired power plants to understand key issues influencing these deposition regimes and infer their behavior under oxy-fired conditions. Based on the results of this survey, an algorithm for integrating slagging predictions into CFD models was outlined. This method accounts for ash formation, particle impaction and sticking, deposit growth and physical properties and impact of the deposit on system flow and heat transfer. A model for fouling in the back pass has also been identified which includes vaporization of sodium, deposition of sodium sulfate on fly ash particles and tube surfaces, and deposit growth rate on tubes. In Year 1, REI has also performed a review of the literature describing corrosion in order to understand the behavior of oxidation, sulfidation, chloridation, and carburization mechanisms in air-fired and oxy-combustion systems. REI and Vattenfall have met and exchanged information concerning oxy-coal combustion mechanisms for CFD simulations currently used by Vattenfall. In preparation for Year 2 of this program, two coals (North Antelope PRB, Western bituminous) have been ordered, pulverized and delivered to the University of Utah and Sandia National Labs. Materials for the corrosion experiments have been identified, suppliers located, and a schedule for equipment fabrication and shakedown has been established. Finally, a flue gas recycle system has been designed and is being constructed for the OFC.

  9. Development of Fly Ash Derived Sorbents to Capture CO2 from Flue Gas of Power Plants

    SciTech Connect (OSTI)

    M. Mercedes Maroto-Valer; John M. Andresen; Yinzhi Zhang; Zhe Lu

    2003-12-31T23:59:59.000Z

    This research program focused on the development of fly ash derived sorbents to capture CO{sub 2} from power plant flue gas emissions. The fly ash derived sorbents developed represent an affordable alternative to existing methods using specialized activated carbons and molecular sieves, that tend to be very expensive and hinder the viability of the CO{sub 2} sorption process due to economic constraints. Under Task 1 'Procurement and characterization of a suite of fly ashes', 10 fly ash samples, named FAS-1 to -10, were collected from different combustors with different feedstocks, including bituminous coal, PRB coal and biomass. These samples presented a wide range of LOI value from 0.66-84.0%, and different burn-off profiles. The samples also spanned a wide range of total specific surface area and pore volume. These variations reflect the difference in the feedstock, types of combustors, collection hopper, and the beneficiation technologies the different fly ashes underwent. Under Task 2 'Preparation of fly ash derived sorbents', the fly ash samples were activated by steam. Nitrogen adsorption isotherms were used to characterize the resultant activated samples. The cost-saving one-step activation process applied was successfully used to increase the surface area and pore volume of all the fly ash samples. The activated samples present very different surface areas and pore volumes due to the range in physical and chemical properties of their precursors. Furthermore, one activated fly ash sample, FAS-4, was loaded with amine-containing chemicals (MEA, DEA, AMP, and MDEA). The impregnation significantly decreased the surface area and pore volume of the parent activated fly ash sample. Under Task 3 'Capture of CO{sub 2} by fly ash derived sorbents', sample FAS-10 and its deashed counterpart before and after impregnation of chemical PEI were used for the CO{sub 2} adsorption at different temperatures. The sample FAS-10 exhibited a CO{sub 2} adsorption capacity of 17.5mg/g at 30 C, and decreases to 10.25mg/g at 75 C, while those for de-ashed counterpart are 43.5mg/g and 22.0 mg/g at 30 C and 75 C, respectively. After loading PEI, the CO{sub 2} adsorption capacity increased to 93.6 mg/g at 75 C for de-ashed sample and 62.1 mg/g at 75 C for raw fly ash sample. The activated fly ash, FAS-4, and its chemical loaded counterparts were tested for CO{sub 2} capture capacity. The activated carbon exhibited a CO{sub 2} adsorption capacity of 40.3mg/g at 30 C that decreased to 18.5mg/g at 70 C and 7.7mg/g at 120 C. The CO{sub 2} adsorption capacity profiles changed significantly after impregnation. For the MEA loaded sample the capacity increased to 68.6mg/g at 30 C. The loading of MDEA and DEA initially decreased the CO{sub 2} adsorption capacity at 30 C compared to the parent sample but increased to 40.6 and 37.1mg/g, respectively, when the temperature increased to 70 C. The loading of AMP decrease the CO{sub 2} adsorption capacity compared to the parent sample under all the studied temperatures. Under Task 4 'Comparison of the CO{sub 2} capture by fly ash derived sorbents with commercial sorbents', the CO{sub 2} adsorption capacities of selected activated fly ash carbons were compared to commercial activated carbons. The CO{sub 2} adsorption capacity of fly ash derived activated carbon, FAS-4, and its chemical loaded counterpart presented CO{sub 2} capture capacities close to 7 wt%, which are comparable to, and even better than, the published values of 3-4%.

  10. Greenidge Multi-Pollutant Control Project

    SciTech Connect (OSTI)

    Daniel Connell

    2008-10-18T23:59:59.000Z

    The Greenidge Multi-Pollutant Control Project was conducted as part of the U.S. Department of Energy's Power Plant Improvement Initiative to demonstrate an innovative combination of air pollution control technologies that can cost-effectively reduce emissions of SO{sub 2}, NO{sub x}, Hg, acid gases (SO{sub 3}, HCl, and HF), and particulate matter from smaller coal-fired electric generating units (EGUs). There are about 400 units in the United States with capacities of 50-300 MW that currently are not equipped with selective catalytic reduction (SCR), flue gas desulfurization (FGD), or mercury control systems. Many of these units, which collectively represent more than 55 GW of installed capacity, are difficult to retrofit for deep emission reductions because of space constraints and unfavorable economies of scale, making them increasingly vulnerable to retirement or fuel switching in the face of progressively more stringent environmental regulations. The Greenidge Project sought to confirm the commercial readiness of an emissions control system that is specifically designed to meet the environmental compliance requirements of these smaller coal-fired EGUs by offering a combination of deep emission reductions, low capital costs, small space requirements, applicability to high-sulfur coals, mechanical simplicity, and operational flexibility. The multi-pollutant control system includes a NO{sub x}OUT CASCADE{reg_sign} hybrid selective non-catalytic reduction (SNCR)/in-duct SCR system for NO{sub x} control and a Turbosorp{reg_sign} circulating fluidized bed dry scrubbing system (with a new baghouse) for SO{sub 2}, SO{sub 3}, HCl, HF, and particulate matter control. Mercury removal is provided as a co-benefit of the in-duct SCR, dry scrubber, and baghouse, and by injection of activated carbon upstream of the scrubber, if required. The multi-pollutant control system was installed and tested on the 107-MW{sub e}, 1953-vintage AES Greenidge Unit 4 by a team including CONSOL Energy Inc. as prime contractor, AES Greenidge LLC as host site owner, and Babcock Power Environmental Inc. as engineering, procurement, and construction contractor. About 44% of the funding for the project was provided by the U.S. Department of Energy, through its National Energy Technology Laboratory, and the remaining 56% was provided by AES Greenidge. Project goals included reducing high-load NO{sub x} emissions to {le} 0.10 lb/mmBtu; reducing SO{sub 2}, SO{sub 3}, HCl, and HF emissions by at least 95%; and reducing Hg emissions by at least 90% while the unit fired 2-4% sulfur eastern U.S. bituminous coal and co-fired up to 10% biomass. This report details the final results from the project. The multi-pollutant control system was constructed in 2006, with a total plant cost of $349/kW and a footprint of 0.4 acre - both substantially less than would have been required to retrofit AES Greenidge Unit 4 with a conventional SCR and wet scrubber. Start-up of the multi-pollutant control system was completed in March 2007, and the performance of the system was then evaluated over an approximately 18-month period of commercial operation. Guarantee tests conducted in March-June 2007 demonstrated attainment of all of the emission reduction goals listed above. Additional tests completed throughout the performance evaluation period showed 96% SO{sub 2} removal, 98% mercury removal (with no activated carbon injection), 95% SO{sub 3} removal, and 97% HCl removal during longer-term operation. Greater than 95% SO{sub 2} removal efficiency was observed even when the unit fired high-sulfur coals containing up to 4.8 lb SO{sub 2}/mmBtu. Particulate matter emissions were reduced by more than 98% relative to the emission rate observed prior to installation of the technology. The performance of the hybrid SNCR/SCR system was affected by problems with large particle ash, ammonia slip, and nonideal combustion characteristics, and high-load NO{sub x} emissions averaged 0.14 lb/mmBtu during long-term operation. Nevertheless, the system has reduced the unit's overall NO{sub x} emiss

  11. Demonstration of An Integrated Approach to Mercury Control at Lee Station

    SciTech Connect (OSTI)

    Vitali Lissianski; Pete Maly

    2007-12-31T23:59:59.000Z

    General Electric (GE) has developed an approach whereby native mercury reduction on fly ash can be improved by optimizing the combustion system. This approach eliminates carbon-rich areas in the combustion zone, making the combustion process more uniform, and allows increasing carbon content in fly ash without significant increase in CO emissions. Since boiler excess O{sub 2} can be also reduced as a result of optimized combustion, this process reduces NO{sub x} emissions. Because combustion optimization improves native mercury reduction on fly ash, it can reduce requirements for activated carbon injection (ACI) when integrated with sorbent injection for more efficient mercury control. The approach can be tailored to specific unit configurations and coal types for optimal performance. This report describes results of a U.S. DOE sponsored project designed to evaluate the effect of combustion conditions on 'native' mercury capture on fly ash and integrate combustion optimization for improved mercury and NO{sub x} reduction with ACI. The technology evaluation took place in Lee Station Unit 3 located in Goldsboro, NC and operated by Progress Energy. Unit 3 burns a low-sulfur Eastern bituminous coal and is a 250 MW opposed-wall fired unit equipped with an ESP with a specific collection area of 249 ft{sup 2}/kacfm. Unit 3 is equipped with SO{sub 3} injection for ESP conditioning. The technical goal of the project was to evaluate the technology's ability to achieve 70% mercury reduction below the baseline emission value of 2.9 lb/TBtu, which was equivalent to 80% mercury reduction relative to the mercury concentration in the coal. The strategy to achieve the 70% incremental improvement in mercury removal in Unit 3 was (1) to enhance 'naturally' occurring fly ash mercury capture by optimizing the combustion process and using duct humidification to reduce flue gas temperatures at the ESP inlet, and (2) to use ACI in front of the ESP to further reduce mercury emissions. The program was comprised of field and pilot-scale tests, engineering studies and consisted of eight tasks. As part of the program, GE conducted pilot-scale evaluation of sorbent effect on mercury reduction, supplied and installed adjustable riffle boxes to assist in combustion optimization, performed combustion optimization, supplied mobile sorbent injection and flue gas humidification systems, conducted CFD modeling of sorbent injection and flue gas humidification, and performed mercury testing including a continuous 30-day sorbent injection trial. Combustion optimization was the first step in reduction of mercury emissions. Goals of combustion optimization activities were to improve 'native' mercury capture on fly ash and reduce NO{sub x}. Combustion optimization included balancing of coal flow through individual burners to eliminate zones of carbon-rich combustion, air flow balancing, and burner adjustments. As part of the project, the original riffle boxes were replaced with Foster-Wheeler's adjustable riffle boxes to allow for biasing the coal flow between the coal pipes. A 10-point CO/O{sub 2}/NO{sub x} grid was installed in the primary superheater region of the back pass to assist in these activities. Testing of mercury emissions before and after combustion optimization demonstrated that mercury emissions were reduced from 2.9 lb/TBtu to 1.8 lb/TBtu due to boiler operation differences in conjunction with combustion optimization, a 38% improvement in 'native' mercury capture on fly ash. Native mercury reduction from coal was {approx}42% at baseline conditions and 64% at optimized combustion conditions. As a result of combustion optimization NO{sub x} emissions were reduced by 18%. A three-dimensional CFD model was developed to study the flow distribution and sorbent injection in the post air heater duct in Lee Station Unit 3. Modeling of the flow pattern exiting the air pre-heater demonstrated that because of the duct transition from a circular opening at the exit of air-pre-heater to a rectangular ESP inlet duct, flow separation occurred at the corners afte

  12. FIELD TEST PROGRAM TO DEVELOP COMPREHENSIVE DESIGN, OPERATING, AND COST DATA FOR MERCURY CONTROL SYSTEMS

    SciTech Connect (OSTI)

    Michael D. Durham

    2005-03-17T23:59:59.000Z

    Brayton Point Unit 1 was successfully tested for applicability of activated carbon injection as a mercury control technology. Test results from this site have enabled a thorough evaluation of the impacts of future mercury regulations to Brayton Point Unit 1, including performance, estimated cost, and operation data. This unit has variable (29-75%) native mercury removal, thus it was important to understand the impacts of process variables and activated carbon on mercury capture. The team responsible for executing this program included: (1) Plant and PG&E National Energy Group corporate personnel; (2) Electric Power Research Institute (EPRI); (3) United States Department of Energy National Energy Technology Laboratory (DOE/NETL); (4) ADA-ES, Inc.; (5) NORIT Americas, Inc.; (6) Apogee Scientific, Inc.; (7) TRC Environmental Corporation; (8) URS Corporation; (9) Quinapoxet Solutions; (10) Energy and Environmental Strategies (EES); and (11) Reaction Engineering International (REI). The technical support of all of these entities came together to make this program achieve its goals. Overall, the objectives of this field test program were to determine the impact of activated carbon injection on mercury control and balance-of-plant processes on Brayton Point Unit 1. Brayton Point Unit 1 is a 250-MW unit that fires a low-sulfur eastern bituminous coal. Particulate control is achieved by two electrostatic precipitators (ESPs) in series. The full-scale tests were conducted on one-half of the flue gas stream (nominally 125 MW). Mercury control sorbents were injected in between the two ESPs. The residence time from the injection grid to the second ESP was approximately 0.5 seconds. In preparation for the full-scale tests, 12 different sorbents were evaluated in a slipstream of flue gas via a packed-bed field test apparatus for mercury adsorption. Results from these tests were used to determine the five carbon-based sorbents that were tested at full-scale. Conditions of interest that were varied included SO{sub 3} conditioning on/off, injection concentrations, and distribution spray patterns. The original test plan called for parametric testing of NORIT FGD carbon at 1, 3, and 10 lbs/MMacf. These injection concentrations were estimated based on results from the Pleasant Prairie tests that showed no additional mercury removal when injection concentrations were increased above 10 lbs/MMacf. The Brayton Point parametric test data indicated that higher injection concentrations would achieve higher removal efficiencies and should be tested. The test plan was altered to include testing at 20 lbs/MMacf. The first test at this higher rate showed very high removal across the second ESP (>80%). Unlike the ''ceiling'' phenomenon witnessed at Pleasant Prairie, increasing sorbent injection concentration resulted in further capture of vapor-phase mercury. The final phase of field-testing was a 10-day period of continuous injection of NORIT FGD carbon. During the first five days, the injection concentration was held at 10 lbs/MMacf, followed by nominally five days of testing at an injection concentration of 20 lbs/MMacf. The mercury removal, as measured by the semi-continuous emission monitors (S-CEM), varied between 78% and 95% during the 10 lbs/MMacf period and increased to >97% when the injection concentration was increased to 20 lbs/MMacf. During the long-term testing period, mercury measurements following EPA's draft Ontario Hydro method were conducted by TRC Environmental Corporation at both 10 and 20 lbs/MMacf test conditions. The Ontario Hydro data showed that the particulate mercury removal was similar between the two conditions of 10 or 20 lbs/MMacf and removal efficiencies were greater than 99%. Elemental mercury was not detected in any samples, so no conclusions as to its removal can be drawn. Removal of oxidized mercury, on the other hand, increased from 68% to 93% with the higher injection concentration. These removal rates agreed well with the S-CEM results.

  13. Fate of Mercury in Synthetic Gypsum Used for Wallboard Production

    SciTech Connect (OSTI)

    Jessica Sanderson; Gary M. Blythe; Mandi Richardson

    2006-12-01T23:59:59.000Z

    This report presents and discusses results from Task 6 of the study 'Fate of Mercury in Synthetic Gypsum Used for Wallboard Production,' performed at a full-scale commercial wallboard plant. Synthetic gypsum produced by wet flue gas desulfurization (FGD) systems on coal-fired power plants is commonly used in the manufacture of wallboard. This practice has long benefited the environment by recycling the FGD gypsum byproduct, which is becoming available in increasing quantities, decreasing the need to landfill this material, and increasing the sustainable design of the wallboard product. However, new concerns have arisen as recent mercury control strategies involve the capture of mercury in FGD systems. The objective of this study is to determine whether any mercury is released into the atmosphere when the synthetic gypsum material is used as a feedstock for wallboard production. The project is being co-funded by the U.S. DOE National Energy Technology Laboratory (Cooperative Agreement DE-FC26-04NT42080), USG Corporation, and EPRI. USG Corporation is the prime contractor, and URS Group is a subcontractor. The project scope now includes six discrete tasks, each conducted at various USG wallboard plants using synthetic gypsum from different FGD systems. The project was originally composed of five tasks, which were to include (1) a baseline test, then variations representing differing power plant: (2) emissions control configurations, (3) treatment of fine gypsum particles, (4) coal types, and (5) FGD reagent types. However, Task 5, which was to include testing with an alternate FGD reagent, could not be conducted as planned. Instead, Task 5 was conducted at conditions similar to Task 3, although with gypsum from an alternate FGD system. Subsequent to conducting Task 5 under these revised conditions, an opportunity arose to test gypsum produced at the same FGD system, but with an additive (Degussa Corporation's TMT-15) being used in the FGD system. TMT-15 was expected to impact the stability of mercury in synthetic gypsum used to produce wallboard, so Task 6 was added to the project to test this theory. In this project, process stacks in the wallboard plant have been sampled using the Ontario Hydro method. For every task, the stack locations sampled have included a dryer for the wet gypsum as it enters the plant and a gypsum calciner. For Tasks 1, 4, 5 and 6, the stack of the dryer for the wet wallboard product was also tested. Also at each site, in-stream process samples were collected and analyzed for mercury concentration before and after each significant step in wallboard production. The Ontario Hydro results, process sample mercury concentration data, and process data were used to construct mercury mass balances across the wallboard plants. Task 6 was conducted at a wallboard plant processing synthetic gypsum from a power plant that fires Eastern bituminous coal. The power plant has a single-loop, open spray tower limestone forced oxidation FGD system, with the forced oxidation conducted in the reaction tank integral with the FGD absorber. The FGD system has gypsum fines blow down as part of the dewatering step. The power plant is equipped with a selective catalytic reduction (SCR) system for NOX emissions control, and the SCR was in service during the time period the gypsum tested was produced. Also, as mentioned above, Degussa additive TMT-15 was being added to the FGD system when this gypsum was produced. The results of the Task 6 stack testing, as measured by the Ontario Hydro method, detected that an average of 55% of the incoming mercury was emitted during wallboard production. These losses were distributed as about 4% across the dryer mill, 6% across the board dryer kiln, and 45% across the kettle calciner. Emissions were similar to what Task 5 results showed on a percentage basis, but about 30% lower on a mass basis. The same power plant FGD system produced the synthetic gypsum used in Task 5 (with no use of TMT-15) and in Task 6 (with TMT-15 added to the FGD system). The lower emissions on a mass basis appeared