AndreaBozzo/ceres-open-data-index huggingface dataset:
Advanced coal-fueled industrial cogeneration gas turbine system: Semiannual progress report, December 1987--June 1988

Testing of the Component Screening Combustor (CSC) during the period was devoted to evaluating alternate designs which were intended to eliminate several shortcomings in the performance of the baseline. These areas were slag escape from the primary which solidified as a chimney in the secondary. Another concern was the escape of raw fuel from the primary zone. The first alternate designated as Mod. 1 features a raised rear primary wall which increases the volume by 50%. The second alternate design designated as Mod. 2 features a single centrally located fuel injector. Both the designs were evaluated using a computer modeling program and a flow visualization rig. Results indicated that the central core jet was more stable than the baseline and that the escape of slag would be reduced. The fabrication of the PRIS housing and both types of inserts were completed. The PRIS test plan was submitted for approval. Work conducted on the coal fuel specification task included: review of the effects of mean particle size, ash fluid temperature and viscosity as regards the combustor testing; determination of high temperature slag properties; high-temperature alkali release additive costs; treatment of waste slurry and grinding circuit optimization. 33 figs., 20 tabs.

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Conceptual design of a coal-fired fluidized-bed steam locomotive

This paper describes a conceptual design of a coal-fired, fluidized-bed, combustor-based steam locomotive that was developed as an approach to displacing premium fuel (diesel). This approach draws on relatively mature technology and appears feasible for the near term. Guidelines for the conceptualization are based on two previous designs that are relatively contemporary, and were built and tested during the steam locomotive era. Conclusions of this conceptual design study are summarized as follows: (1) a total conversion from diesel locomotives to coal-fired steam locomotives would displace up to 280,000 barrels of oil per day; (2) a fluidized-bed, steam turbine locomotive has the potential to offer very significantly lower operating costs and environmental burdens than the diesel; (3) fuel operating costs per horsepower hour for three comparably sized systems are as follows: diesel - $.19, fluidized-bed combustion (FBC) condensing steam cycle - $.085, and the FBC noncondensing steam cycle - $.021; (4) a cost estimate to build one commercially proven (post-prototype) coal-fired, fluidized-bed locomotive unit is estimated at $3,400,000; (5) an environmental analysis indicates that effective SO/sub 2/ and NO/sub x/ control is readily attainable with the FBC approach. If industrial New Source Performance Standards (NSPS) are imposed, particulate emission is likely to be the most severe constraint to FBC rail applications; (6) in general, there are no insurmountable roadblocks to early commercialization of mobile FBC steam generators, based on this analysis; and (7) in addition, the development of an attractive, mobile FBC power system appears to have significant potential for marine applications and industrial steam generators, either for direct heating or cogeneration applications.

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Proceedings of the fifth annual contractors meeting on contaminant control in coal-derived gas streams

This document contains papers that were presented at the Department of Energy's Fifth Annual Contractors Meeting on Contaminant Control in Coal-Derived Gas Streams. The meeting was sponsored and hosted by the Department of Energy, Morgantown Energy Technology Center and was held May 7 through 9, 1985, at the Sheraton Lakeview Conference Center in Morgantown, West Virginia. The purpose of this meeting was to present technical information on high-temperature, high-pressure control technologies for particulate and chemical contaminants in coal-derived gas streams. Two papers detailing the development of cold gas stream cleanup processes were also presented. The meeting provided a forum for the exchange and dissemination of contaminant control information generated under the sponsorship of the Department of Energy. The contaminant control technologies and instrumentation research have direct application to pressurized fluidized-bed combustion and coal gasification, as well as a number of additional Fossil research programs, commercial processes, and noncoal related operations. All papers have been processed for inclusion in the Energy Data Base.

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Handbook of gasifiers and gas-treatment systems. [39 gasification processes and 40 gas processing systems]

In February 1976, the Energy Research and Development Administration (ERDA) published the Handbook of Gasifiers and Gas Treatment Systems. The intent of this handbook was to provide a ready reference to systems that are or may be applicable to coal conversion technology. That handbook was well received by users and was subsequently reprinted many times. The Department of Energy (successor agency to the ERDA) expands, revises and updates the Handbook in this volume. This new Handbook is not intended as a comparative evaluation, but rather as an impartial reference on recent and current technology. The Handbook now presents 39 gasification technologies and 40 gas processing systems that are or may be applicable to coal conversion technology. The information presented has been approved or supplied by the particular licensor/developer.

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Design for coal supply analysis system. Final report

Coal supply forecasts are used by EPRI to assess the potential of new technologies and by member utilities for strategic planning. Developing realistic coal price--quantity relationships for technology assessment is one type of activity in the EPRI Energy Supply Program, and providing information on coal markets and coal forecasts to member utilities is another. To support activies such as these, EPRI is developing a computerized Coal Supply Analysis System (CSAS). The CSAS contains procedures for developing coal analyses and a data base to support them. The procedures include methods to estimate available coal resources, coal extraction costs, coal preparation costs, and regional coal supply functions, and to support price and production forecasts. The basic data base includes information on coal resources (resources, production), coal mining technology, and coal prices. Procedures are supported by data bases containing information developed from the basic data files or from other procedures in CSAS or other systems (demand, transport). Because CSAS supports analyses produced on a regular basis as well as special analyses, the system should provide flexibility for unanticipated analyses as well as cost-effective methods for frequently used procedures.To provide this capability, there should be a flexible data base management system, a variety of programming languages under a common operating sytem, and the ability to access nonresident programs.

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Advanced atmospheric fluidized-bed combustion design - spouted bed

This report describes the Spouted-Fluidized Bed Boiler that is an advanced atmospheric fluidized bed combustor (FBC). The objective of this system design study is to develop an advanced AFBC with improved performance and reduced capital and operating costs compared to a conventional AFBC and an oil-fired system. The Spouted-Fluidized Bed (SFB) system is a special type of FBC with a distinctive jet of air in the bed to establish an identifiable solids circulation pattern. This feature is expected to provide: reduced NO/sub x/ emissions because of the fuel rich spout zone; high calcium utilization, calcium-to-sulfur ratio of 1.5, because of the spout attrition and mixing; high fuel utilization because of the solids circulation and spout attrition; improved thermal efficiency because of reduced solids heat loss; and improved fuel flexibility because of the spout phenomena. The SFB was compared to a conventional AFBC and an oil-fired package boiler for 15,000 pound per hour system. The evaluation showed that the operating cost advantages of the SFB resulted from savings in fuel, limestone, and waste disposal. The relative levelized cost for steam from the three systems in constant 1985 dollars is: SFB - $10 per thousand pounds; AFBC - $11 per thousand pounds; oil-fired - $14 per thousand pounds. 18 refs., 5 figs., 11 tabs.

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Development of a generalized hydraulic fracture model. Annual report, November 1, 1983-October 31, 1984

The reported investigations furnish an integrated framework for hydraulic fracture model development. The finite element code for the determination of formation principal stresses provides a capability for in situ stress evaluation based on measured field data. The exact solutions for specialized cases associated with hydraulic fracturing are invaluable in terms of code validation, parametric sensitivity studies, and assumption verification. The advanced hydraulic fracture simulations using the finite element approach, yield reasonable comparisons with available results on fracture length, height and width for vertically symmetric and unsymmetric tectonic stress distributions. Consolidation of these studies in Section 3.3 to multi-layered formations, using the methodology and results in Section 3.4 and Appendix D, is a logical step in the model development. In addition, the integration of joint/interface bi-material properties and reservoir natural fracture systems in the developed code provides a formidable challenge. Finally, the interfacing of the developed hydraulic fracture model to a suitable reservoir production model by coupling of nodal points will yield a comprehensive simulation for potential commercial applications. 17 references, 11 figures, 2 tables.

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Viscosity and spray effects of coal slurry diesel fuels: Final report

An evaluation was performed on coal slurry fuels composed of 37.5 to 55 weight-percent coal in liquid carriers of water, methanol, a 50-50 blend of water-methanol, and diesel fuel No. 2. The variables of viscosity related to engine fuel injection equipment parameters and conditions and of spray density and droplet size were examined. 12 refs., 15 figs., 14 tabs.

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Geological evolution and analysis of confirmed or suspected gas hydrate localities. Volume 1. Blake-Bahama Outer Ridge - US East Coast

This document is Volume 1 of a series of reports entitled ''Geological Evolution and Analysis of Confirmed or Suspected Gas Hydrate Localities.''Volume 1 is an analysis of the ''Blake-Bahama Outer Ridge - US East Coast.''This report presents a geological description of the Blake-Bahama Outer Ridge, including regional and local structural settings, geomorphology, geological history, stratigraphy, and physical properties. It provides the necessary regional and geological background for more in-depth research of the area. Detailed discussion of bottom simulating acoustic reflectors, sediment acoustic properties, distribution of hydrates within the sediments, and the relation of hydrate distribution to other features such as salt diapirism are also included. The formation and stabilization of gas hydrates in sediments are considered in terms of phase relations, nucleation, and crystallization constraints, gas solubility, pore fluid chemistry, inorganic diagenesis, and sediment organic content. Together with a depositional analysis of the area, this report is a better understanding of the thermal evolution of the locality. It should lead to an assessment of the potential for thermogenic hydrocarbon generation. 111 refs., 26 figs., 6 tabs.

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[National Institute for Petroleum and Energy Research] 1991 annual report, October 1, 1990--September 30, 1991

This Annual Report provides research accomplishments, publications, and presentations resulting from the FY91 research conducted under the following Base Program projects: reservoir assessment and characterization; TORIS research support; three-phase relative permeability; imaging techniques applied to the study of fluids in porous media; development of improved microbial flooding methods; development of improved surfactant flooding methods; development of improved alkaline flooding methods; development of improved mobility- control methods; gas flooding; mobility control and sweep improvement in gas flooding; thermal processes for light oil recovery; thermal processes for heavy oil recovery; thermochemistry and thermophysical properties of organic nitrogen- and diheteroatom- containing compounds; and development of analytical methodology for analysis of heavy crudes.

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Hydrogeological and geotechnical procedures manual for the disposal of fly ash and FGD waste from low-rank coals in Western strip mines

The disposal of flue gas desulfurization and fly ash waste in surface mines was considered. The area of this study included Arizona, Colorado, Montana, Nevada, New Mexico, North Dakota, Texas, Utah, and Wyoming. Landfill and ponding have traditionally been the favored disposal modes for these wastes. However, by spring of 1983, nine western mine mouth power plants over a five state area (North Dakota, Wyoming, Colorado, New Mexico, and Texas) will be disposing of flyash or a mixture of flyash and flue gas desulfurization (FGD) waste in surface coal mines. A summary is provided of the current regulatory framework, FGD equipped power plant characteristics, and surface coal mine waste disposal site operations within the study area. Second, it is to provide a set of guidelines based on geologic and hydrologic criteria, for use in establishing flue gas cleaning waste disposal sites in surface mines.

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The Use of High-Boiling Alcohols to Produce Shale Oil from Green River Shale

This report describes the results of experiments in which Green River shale was treated with mono-, di-, or trifunctional alcohols in an attempt to produce high oil yields under lower pressure treatment conditions. The experiment using 1,2-ethanediol (ethylene glycol) and water resulted in a yield of 81 weight percent based on recovered liquid organic matter, a yield equivalent ro 124% of Fischer assay. The experiments using other di- and trifunctional alcohols were not successful in recovering large amounts of oil from the shale. The 1, 2-ethanediol experiments suggests that it may be possible to recover oil from shale in yields much higher than those of conventional retorting precesses at pressures well below supercritical methanol-water. Solvents with boiling points up to 200C, such as n-octanol boiling at 194C and 1,2-ethanediol boiling at 198C, can be removed from liquid product using rotary evaporation under reduced pressure. Higher-boiling alcohols such as glycerin and diethylene glycol would probably not be satisfactory solvents even if recoveries were high because of complicated separation requirements. 10 refs., 1 tab.

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Novel Sorbents for High-Temperature Regenerative H2S Removal

The overall objective of this program was to develop improved regenerable sorbents for the high-temperature desulfurization of coal-derived gas streams. The aim is to reduce the H/sub 2/S level, preferably in a single-stage, from 0.5 to 1.0 mol % down to 1 ppM. The specific objectives of this project were to synthesize, characterize and test two classes of sorbents. One consists of eutectic mixtures of metal oxides (e.g., ZnO-V/sub 2/O/sub 5/, CuMoO/sub 4/-MoO/sub 3/) in the form of a melt coating the pore surface of a high surface area solid support. The second class of sorbents includes unsupported mixed oxides, in the form of solid solutions or solid compounds, e.g., Zn-Fe/sub x/-O/sub y/, Cu-Fe/sub x/-O/sub y/, prepared as highly dispersed microcrystalline solids. The principal characteristics of both classes of sorbents are rapid kinetics of absorption, high absorption capacity and good regenerability. The rapid absorption kinetics are realized by eliminating or minimizing the resistance associated with solid state diffusion. With these properties, the sorbents would be suitable for coal gasification/molten carbonate fuel cell (MCFC) applications, but could also be applied to combined cycle power generation and the purification of synthesis gas. 22 refs., 31 figs., 31 tabs.

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Performance of low-rank coal in atmospheric fluidized bed combustion. Technology transfer report

This report presents test data generated at GFETC and discusses the implications of this data in regard to the technical and economic feasibility of using low-rank coals in the AFBC. Atmospheric fluidized bed combustion offers a number of potential advantages over conventional pulverized coal combustion due to the intense turbulence in the fluidized bed and long residence times of solids in the bed without a long linear flow path. Advantages of the AFBC include flexibility to handle varying fuels, sulfur capture by limestone, high combustion efficiency, compact combustor size, lower NO/sub x/ emissions, and reduced slagging and fouling problems. Low-rank coals with high alkali-to-sulfur ratios offer a significant additional advantage: the ability to absorb significant sulfur on the alkaline ash. Results verify that AFBC is particularly well suited for the direct combustion of low-rank coals. With combustion temperatures above 1450/sup 0/F at 20% excess air or higher, the combustion efficiencies while burning low-rank coal were found to be above 98%, with efficiencies above 99% for most tests. The CO emissions were very low, typically below 0.05 lb/MMBtu or 50 ppMv. Overall heat transfer coefficients to water-cooled tubes while burning low-rank coals were comparable to those obtained with other fuels in AFBC, or 20 to 60 Btu/h-ft/sup 2/-/sup 0/F. These are considerably higher than those obtained in conventional coal-fired systems which are typically 5 to 15 Btu/h-ft/sup 2/-/sup 0/F. Factors influencing heat transfer included mass velocity, bed particle size, bed temperature, and ash recycle.

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Advantages/limitations of solvent extraction, ozonation, and carbon adsorption for reduction of nonbiodegradable residuals in METC fixed-bed gasification wastewaters. Final report

This (second) year of effort examined the roll of solvent extraction, ozonation, and carbon adsorption for incorporation into the wastewater treatment scheme for purposes of enhancing process stability, decolorization, elimination of dilution water requirements, and minimization of nonbiodegradable residuals. This approach, while more costly, will better allow for direct discharge or reuse of gasification wastewaters. Di-isopropylether (DIPE) and methyl-isobutyl ketone (MIBK) were incorporated into a pretreatment step with free and fixed ammonia stripping followed by activated sludge treatment. Solvent extraction did not result in a decrease of nonbiodegradable residuals from the bioreactor, but did result in a highly stable operation of the bioreactors with no dilution water requirements and a minimal tendency for foaming and biodeflocculation. Ozonation of biofeed resulted in phenol being kinetically favored for oxidation. Ozonation of bioeffluents resulted in decolorization of wastewaters at low dosages, and first order kinetics in the reduction of nonbiodegradable TOC residuals. Steam stripping for ammonia removals, coupled with an understanding of anion/cation chemistry, led to a treatment system with minimization of salt additions. This is desirable if waste-waters are to be concentrated via evaporative techniques for partial reuse. Use of ozone followed by activated carbon further reduces nondegradable organics as may be desired for discharge or reuse purposes.

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Advanced turbine systems study system scoping and feasibility study

United Technologies Research Center, Pratt   Whitney Commercial Engine Business, And Pratt   Whitney Government Engine and Space Propulsion has performed a preliminary analysis of an Advanced Turbine System (ATS) under Contract DE-AC21-92MC29247 with the Morgantown Energy Technology Center. The natural gas-fired reference system identified by the UTC team is the Humid Air Turbine (HAT) Cycle in which the gas turbine exhaust heat and heat rejected from the intercooler is used in a saturator to humidify the high pressure compressor discharge air. This results in a significant increase in flow through the turbine at no increase in compressor power. Using technology based on the PW FT4000, the industrial engine derivative of the PW4000, currently under development by PW, the system would have an output of approximately 209 MW and an efficiency of 55.3%. Through use of advanced cooling and materials technologies similar to those currently in the newest generation military aircraft engines, a growth version of this engine could attain approximately 295 MW output at an efficiency of 61.5%. There is the potential for even higher performance in the future as technology from aerospace R D programs is adapted to aero-derivative industrial engines.

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Morgantown Energy Technology Center, Publications List, FY 89

This Publications List includes the scientific and technical reports and papers authored by Morgantown Energy Technology Center (METC) staff as well as those written by METC contractors during Fiscal Year 1989. The reports and papers are arranged by METC areas of expertise: Arctic and Offshore; Components; Computers, Models, and Simulation; Enhanced Oil Recovery; Environmental and Waste Management; Fluidized-Bed Combustion; Fuel Cells; Gas Stream Cleanup; Gasification; Heat Engines; Instrumentation and Control; Low-Rank Coal; Oil Shale; Tar Sand; Unconventional Gas Recovery; Underground Coal Gasification; and Crosscutting Technologies. Reports are subarranged by report numbers from the Energy Data Base. Author/Corporate Author, Report Number, Order Number, and Title indexes follow the listing.

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Evaluation of the use of UCG gas to produce 4000 BPD and 12,000 BPD of methanol with conversion to M-gasoline

This study involves an examination of the technical and economic feasibility of using raw gas from an underground coal gasification facility as feedstock for methanol synthesis, and producing M-gasoline from the methanol. It differs from previous studies in considering facilities smaller than those previously studied. Addressed also is the economic and technical feasibility of using equipment from existing ammonia plants for the production of methanol. Ammonia and methanol plants are very similar in type of equipment used and plant layout. Consequently, it is possible to convert an existing ammonia plant into a methanol facility. Existing ammonia and methanol plants which contain equipment that might be utilized with UCG all use natural gas for feedstock. The processing steps in these plants can be divided into unit operations which are described. The product price analysis shows that significant economies of scale exist for the larger of the two facility sizes considered in this study. The economies of scale are evident for both the methanol/M-gasoline and methanol-only facilities. Compared to current market prices, the calculated product prices for the 4000 BPD and 12,000 BPD methanol-only facilities are within the range of competitiveness with the prices of conventionally produced methanol. The product prices calculated for the 12,000 BPD methanol/4910 BPD M-gasoline facility are, under the most optimistic assumptions, 50% higher than the current market price for unleaded gasoline.

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