AndreaBozzo/ceres-open-data-index huggingface dataset:
Gas turbine systems research and development. Second topical report

The objectives of this program were to define the most attractive gas turbine power system that could operate on coal-derived fuel and to identify a research and development program that could lead to commercialization. The power systems investigated included a combined cycle system for baseload application and a simple cycle gas turbine for peaking application. The coal-derived fuels included a partially-cleaned fuel gas and a coal-water mixture. Both fuel systems were investigated for the baseload application, whereas only the coal-water mixture was investigated for the peaking application. The focal activity of the program was a comprehensive systems analysis which addressed critical technical, economic, environmental, and reliability issues. This analytical effort followed closely the spirit of systems analysis in that it drew on existing information to the maximum extent possible in order to minimize duplication of past efforts. Complementing the analytical efforts were two experimental tasks to prepare beneficiated coal samples and to quantify the physical properties of coal water mixtures made from the samples. Results of the systems analysis are presented herein. Starting with the general study guidelines and environmental concerns, the characteristics of the coal-derived fuels are given and the related system design considerations are described. The conceptual design, performance, reliability, and cost estimates are presented for the two baseline combined cycle system and the baseline peaking system. Results of key parametric and trade-off studies are also described. Cost of electricity estimates are given for the three systems, and comparisons are made with the conventional power generation alternatives. Finally, the technical problem areas are described.

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Primary heater module, Phase II. Volume III. Final report, February 1980-November 1983

Research was conducted on components and subassemblies of coal-fired heaters suitable to supply the heat input to closed-cycle gas turbine-based cogeneration systems of 25 to 50 MWe electrical output. Three concepts were researched: (1) a dry bottom, pulverized coal-fired radiant furnace heater for 1450/sup 0/ to 1550/sup 0/F turbine inlet temperature; (2) an atmospheric pressure fluidized bed fired heater for 1450/sup 0/ to 1550/sup 0/F; and (3) a heater employing atmospheric pressure fluidized beds in series, for 1750/sup 0/F turbine inlet temperature. The series beds concept employs ceramic heating surface in its high-temperature bed. Both laboratory and field testing was conducted on heating surface materials durability in the pulverized coal and fluidized bed environments. Burner and furnace designs were researched for pulverized coal heaters employing large quantities of flue gas recirculation to moderate the furnace heat flux. A 6'by 6'fluidized bed was assembled and tested for materials and operational research on the 1450/sup 0/ to 1550/sup 0/F heater concept. A ceramic-to-metal joint concept was devised, fabricated and made ready for test. The conceptual commercial heater concepts were refined. The program results indicate that each of the three heater concepts is technically feasible. The fluidized bed concepts are judged most likely to be both technically and commercially feasible. Their continued development is recommended. This volume deals with pulverized coal heat exchanger technology, cold flow model studies of burners and furnaces, and materials testing for corrosion.

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Oil recovery by carbon dioxide injection. Annual report, July 1977--July 1978

As of July 1, 1978, the project was thirteen months behind the original schedule. This failure to meet the original schedule resulted from a two-month delay due to contract negotiations, a six-month delay before an adequate source of water was developed and made available for injection, and a two-month delay due to a labor strike. The project is now showing a response to waterflood. Further delays might occur in order to properly evaluate oil recovery due to waterflood prior to initiating carbon dioxide injeection. Water injection into the backup injection wells was initiated on October 16, 1976 and water injection into the six pattern injection wells commenced on April 22, 1977. As of July 1, 1978, the cumulative injection into the nineteen injection wells totaled 1,306,966 barrels.

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Rock matrix and fracture analysis of flow in western tight gas sands, Phase 3: Quarterly technical progress report, April-June 1987

Progress reports are presented for the following tasks: (1) advanced core analysis; (2) flow along and across fractures; (3) chemical alteration; and (4) effect of water on gas production. Much of the advanced core analysis work needed to aid in the selection of cores for other tasks has been completed. Three areas where work is continuing are electrical resistivity, clay analysis, and preparation of thin sections. For task 2, core analysis work on core samples containing calcite-filled natural fracture is continuing. The status of work performed to date on such fractures is summarized. Chemical alteration of various mineralogical components and resultant effects on permeability were investigated using sodium hydroxide and oxalic acid. For task 4, a topical report is currently in preparation on ''Effect of Drying on Absolute and Relative Permeabilities of Low Permeability Gas Sands.''According to this report, permeabilities of cores which had been allowed to dry tended to be higher than those of the fresh ones. 6 refs., 6 figs., 1 tab.

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Factors Affecting In-Situ Recovery of Hydrocarbons from Oil Shale

Batch thermal solution of Hell's Hole Canyon oil shale in hydrocarbon solvents has been studied at temperatures of from 274/sup 0/ to 410/sup 0/C. Three solvents were used: cyclohexane; 1,2,3,4-tetrahydronaphthalene; and creosote oil. In 24-hour, constant-temperature runs under autogenous pressure, each solvent was found to be capable of removing over 90% of the original organic material at extraction temperatures of from 360 to 375/sup 0/C. Cyclohexane extraction resulted in somewhat greater yields than tetralin extraction in runs below 365/sup 0/C but approximately the same yields as tetralin at higher extraction temperatures. With one oil shale sample, virtually identical yields were observed in both cyclohexane and tetralin extractions. This finding suggests that mass-transfer restrictions within some oil shales may restrict the yield regardless of the solvent used. Carbon-13 NMR analyses of the spent shales showed that the aromaticity of the residual organic material in tetralin-extracted shale increased slightly from the raw shale value of 0.27 and remained essentially constant at a value of 0.31  increased. In constant temperature runs of 24-hour duration, the aromaticity of an oil shale sample increased from the raw oil shale value of 0.17 to 0.28 after cyclohexane extraction at 326/sup 0/C, while a tetralin-extracted sample of the same oil shale had an aromaticity of only 0.20 after extraction at 321/sup 0/C. The nitrogen content of the cyclohexane extracts, which ranged from 1.58 to 2.24%, was comparable to that of values reported in the literature for shale oils. The tetralin extracts had somewhat lower nitrogen content, ranging from 0.58 to 1.95%. Extract nitrogen content generally increased with extraction temperature. 55 references, 58 figures, 22 tables.

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Demonstration project for methane recovery from unmineable coalbeds. Final report

Mountain Fuel Supply Company is a publicly-owned, gas-utility company with extensive natural gas production, pipeline, and distribution facilities in Utah and Wyoming. Through its subsidiary Mountain Fuel Resources, an active research program is being conducted under which various nonconventional sources of pipeline gas are being investigated. As part of this program, a jointly funded project was initiated with the US Department of Energy to show the potential for commercial recovery of methane from deep, unmineable coalbeds. The Book Cliffs coal field located in central Utah was selected as the site of the demonstration project. This coal field is known for its high methane emissions. Numerous projects have been initiated or conducted in this coal field over the past several years. These projects have drilled vertical wells as well as horizontal boreholes from within existing mines in the area. A Bureau of Mines report noting the locations of high methane concentration coalbeds also mentions the Book Cliffs coal field. Figure 1, which was reproduced from this report, shows the counties in which coalbeds are located that emit in excess of 1 MMcfd of methane into mine ventilation systems. These counties are located in the states of Pennsylvania, West Virginia, Kentucky, Alabama, Illinois, and Ohio in the eastern part of the  country, and in Utah and Colorado in the West. The Utah Geological and Mineral Survey has also been conducting extensive studies relative to the methane production from Book Cliffs coals. Since 1975, they have been measuring the methane content of core samples. Data have been accumulated from over 200 core samples. Methane contents ranging up to 350 scf/ton have been reported.

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Gas turbine systems research and development program. Final report

Objectives were to identify promising gas turbine combined cycle plant system configurations for burning coal-derived fuels and to study the sensitivity of the plant economics to variations in key parameters. Two baseline plants were defined to accommodate two particular fuel forms: (1) hot coal gas, and (2) micronized coal water mixture. Technical assessments of reliability, availability, and maintainability were included to assure that candidate baseline plants and equipment options were suitable for baseload duty. Component and systems technology development needs and recommended development programs to resolve the technical issues were identified.

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Gas turbine systems research and development program. Topical report, June 6, 1983-October 19, 1984

This report presents the results of a study to evaluate the feasibility of using dirty coal-derived fuels in combustion turbine systems. The fuels selected for the Westinghouse study were coal gas and a coal/water slurry. Results show that both fuels, when used in properly configured systems, can produce power at significantly lower cost than conventional coal-fired systems.

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Fluidized-bed combustion: Technical status report

The goal of METC's FBC program is to establish, by the early 1990s, an engineering technology base that the utility, industrial, commercial, and residential sectors can use to build and operate coal-fired FBC systems. These systems would generate process steam, direct and indirect heat, and electric power from coals of all ranks and sulfur content in an economical and environmentally-acceptable manner. First-generation AFBC technology is already considered commercial and a number of US boiler manufacturers are offering commercial units. However, there are greater opportunities for improvement in economics, performance, and reliability. In order to resolve the remaining technical issues and to broaden the market sector served by AFBC, the DOE is pursuing advanced concepts. This second-generation AFBC technology is directed toward small industrial, commercial, and residential applications. Penetration of these potential markets will require 20- to 30-percent reduction in capital and operating costs over first-generation technology, significant improvements in performance and reliability, and compliance with existing and proposed New Source Performance Standards for environmental emissions. PFBC technology, on the other hand, is less developed and is not yet commercial. Sufficient R and D has been carried out, however, to establish its advantages and to demonstrate the viability of the technology for displacing imported oil and for improving the economics of conventional coal-fired systems.

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Integrated gasification/combined-cycle power plant at Sears Island, Maine:  feasibility study. Summary report

This report presents the results of a feasibility study to evaluate the use of medium Btu synthesis gas, produced from high-sulfur coal, in an Integrated Gasification Combined Cycle (IGCC) power plant, as an alternative to a conventional pulverized coal plant with flue gas scrubbers presently planned for the Sears Island, Maine site of Central Maine Power Company. The process configuration is based on the oxygen-blown Texaco Coal Gasification Process and a General Electric Combined Cycle power plant. The plant design includes a 5000 ton per day oxygen plant, four 1200 tons per day gasification trains plus one spare to reduce risk, four gas turbine-generators with heat recovery steam generators, and a reheat steam turbine generator. Plant output at ISO (59/sup 0/F) conditions is 524 MW net. The report includes preliminary design and arrangement drawings, a detailed plant description, detailed cost information, performance data, schedules, and an extensive evaluation of technical, economic, and environmental results. The results of the study indicate that the IGCC power plant is still a rapidly evolving technology. Before Central Maine Power Company can commit to construction of such a plant, several issues raised in the study need to be addressed. These issues deal with refinements in cycle performance, demonstration of various major components, and construction schedule, among others. The IGCC Plant does have less environmental impact than a comparably sized conventional coal plant, while using a high sulfur, high ash, less expensive coal. The life-of-plant levelized busbar cost for the IGCC Plant is estimated to be 5% lower than for the conventional coal-fired plant, although the initial capital cost is approximately 60% higher. Other cycle designs were identified which have the potential for improving plant economics. This Summary is published as one volume for executive review. The full report consists of two volumes detailing the complete study.

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Equipment-performance survey of the Bi-Gas coal-gasification pilot plant

An equipment performance survey was conducted at the Bi-Gas Coal Gasification Pilot Plant, Homer City, Indiana, under contract with the US Department of Energy, Morgantown Energy Technology Center (METC). Review of plant design files and maintenance records identified incidences of malfunctions and history of corrective modifications of equipment in the pilot plant. Interviews with plant engineering, operation, and maintenance personnel were made to obtain details of the malfunctions, probable causes, corrective actions, and the results of the corrective actions on ten selected equipment items. Based on the survey, significant experience and technology gaps in the equipment for the Bi-Gas pilot plant were identified.

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Coal-gasification basic research and cost studies. Quarterly report 2

Coal-gasification basic research and cost studies performed at Davy McKee Corporation supporting the Department of Energy's coal gasification program is on schedule through the Second Quarter. It is anticipated that work will continue on schedule for the remainder of the program. During the Second Quarter, efforts were concentrated on evaluations, laboratory studies and design activities. In Task I, information on how coals perform in and around fixed-bed gasifiers was reviewed and standards and tests to evaluate the expected performance of agglomerates were developed. The economics of coal agglomeration, the preferred size of agglomerates, and possible coal upgrading methods to enhance agglomerates were examined. Two topical reports describing the findings were prepared and were issued. Approximately 200 separate wafer briquetting runs and 29 double-roll briquetting runs were performed during the period to evaluate potential binders and to investigate different briquetting variables. In Task II, the design of a Winkler coal gasification plant to replace a two-stage gasifier plant in the original Erie Mining facility design was completed, and work on the design of a Combustion Engineering entrained-flow gasification plant replacement was initiated. 24 figures, 12 tables.

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Kinetics of coal pyrolysis and gasification. Final technical report for the period October 1979-September 1982

This research was divided into three main tasks. The major objective of each task was as follows: (1) to study pyrolysis and gasification of as-received and pretreated coals following their rapid heating to and short contact times at maximum temperature in N/sub 2/, steam, and syngas atmospheres by following weight loss and change in physical properties of the chars; (2) to measure continuously the major gases produced during the isothermal pyrolysis and gasification of as-received and pretreated coals in high pressure steam following their rapid heating to maximum temperature; and (3) to measure the catalytic activity of inorganic constituents in chars derived from as-received and pretreated coals for the concurrent methanation and hydrogasification reactions. Pyrolysis and gasification under Task 1 were followed in vertical isothermal, laminar flow furnaces at temperatures up to 1173 K and at pressures between 0.1 and 3.4 MPa. An extensive mathematical model was developed and tested, describing the time/temperature history of coal particles as they passed through the furnaces. Pyrolysis and gasification under Task 2 was achieved by injecting coal particles into a micro isothermal horizontal flow reactor. With the particles remaining stationary in the reactor, reactions were followed by monitoring products CO, CO/sub 2/, and CH/sub 4/ using nondispersive infrared (ir) gas analyzers. In Task 3, reactivities of coal chars in 0.1 MPa of various flowing atmospheres were measured in a vertical thermogravimetric system. Product CH/sub 4/ was measured by a nondispersive ir gas analyzer. Results, in particular, show that the presence of exchangeable cations in lignites greatly affects weight loss and composition of volatile products during pyrolysis and subsequent reactivity of the chars produced.

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Analysis of the structural parameters that influence gas production from the Devonian shale. Volume 1. Executive Summary and Task Reports. Annual progress report

The first portion of the report, from the Executive Summary (page 1) through the Schedule of Milestones (page 10), gives a general overview which highlights our progress and problems for the second year. The Task report portion of the text, written by individual task investigators, is designed primarily for scientists interested in technical details of the second year's work. The second portion of the report consists of appendices of data compiled by the principal investigators.

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Coal processing for fuel cell application; task report, November 6, 1978--January 15, 1979. Modeling of wet gas cleanup

The removal of tars and particulate materials from the effluent stream of a coal gasifier is of major importance in both a power generation sense and in an environmental sense. Gas cleanup systems represent a major cost item in powerplant design and their effective operation is crucial to the successful operation of coal gasifier powerplants. This is true whether the power generating unit is a fuel cell or one of the more conventional generators. The wet gas cleanup system presently under study by the Morgantown Energy Technology Center is an attractive approach to tar, particulate and sulfur removal. This report presents a preliminary analysis of four of the components used in the METC wet gas cleanup system. These components are: the humidification chamber, the disengagement changer, spray nozzles and final filter.

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Solvent refined coal (SRC) process. Research and development report No. 53:  interim report No. 18, 1975. Development of a process for producing an ashless, low-sulfur fuel from coal. Volume IV:  product studies. Part 9:  an investigation of the activity of two Cobalt-Molybdenum-Alumina catalysts for hydrodesulfurization of a coal-derived liquid. [M. S. Thesis]

Two Cobalt-Molybdenum-Alumina catalysts, Sphericat Nalco 474 and Nalcomo 474 having bimodal and unimodal pore size distribution respectively, were studied for hydrodesulfurization (HDS) of FMC oil in a trickle bed reactor. Experimental data were taken at 1500 psig, 2.99 liquid volume hourly space time, 7500 standard cubic feet hydrogen per barrel of FMC oil for temperatures of 700/sup 0/F, 800/sup 0/F, 850/sup 0/F using Sphericat Nalco 474 catalyst and for 700/sup 0/F and 800/sup 0/F using Nalcomb 474 catalyst. The experimental system carried out successful operation at 850/sup 0/F for 145 hours. Under the operational conditions of this study, sulfur concentration in the product oils of 0.02 wt% was observed. However, the presence of macropores in Sphericat Nalco 474 catalyst provided no advantage over the micropores alone in Nalcomo 474 catalyst. Both the catalysts maintained their activity during the entire period of operation of a particular run, the duration of which varied from 100 to 200 hours.

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Coordinated study of the Devonian black shale in the Illinois Basin:  Illinois, Indiana, and western Kentucky. Final report

An evaluation of the resource potential of the Devonian shales, called the Eastern Gas Shales Project (EGSP) was begun. A study of the stratigraphy, structure, composition, and gas content of the Devonian shale in the Illinois Basin was undertaken by the State Geological Surveys of Illinois, Indiana, and Kentucky, under contract to the U.S. DOE as a part of the EGSP. Certain additional data were also developed by other research organizations (including Monsanto Research Corporation-Mound Facility and Battelle-Columbus Laboratory) on cores taken from the Illinois Basin. This report, an overview of geological data on the Illinois basin and interpretations of this data resulting from the EGSP, highlights areas of potential interest as exploration targets for possible natural gas resources in the Devonian shale of the basin. The information in this report was compiled during the EGSP from open file data available at the three State Geological surveys and from new data developed on cores taken by the DOE from the basin specifically for the EGSP. The organically richest shale is found in southeastern Illinois and in most of the Indiana and Kentucky portions of the Illinois Basin. The organic-rich shales in the New Albany are thickest near the center of the basin in southeastern Illinois, southwestern Indiana, and adjacent parts of Kentucky portions of the Illinois Basin. The organic-rich shales in the New Albany are thickest near the center of the basin in southeastern Illinois, southwestern Indiana, and adjacent parts of Kentucky. Natural fractures in the shale may aid in collecting gas from a large volume of shale. These fractures may be more abundant and interconnected to a greater degree in the vicinity of major faults. Major faults along the Rough Creek Lineament and Wabash Valley Fault System cross the deeper part of the basin.

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