AndreaBozzo/ceres-open-data-index huggingface dataset:
Industrial application of fluidized-bed combustion. Quarterly technical progress report, October-December, 1980

In line with a determination by the Federal Government that a fluidized bed combustion process can efficiently convert the energy of coal to usable power in an environmentally acceptable manner, Georgetown University was awarded a contract by the Department of Energy to construct and operate a demonstration plant. This report, which is the seventeenth quarterly progress report under the contract, reflects the progress made during the fourth full quarter of plant operation.

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Development of an advanced, continuous mild gasification process for the production of co-products

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.

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High-temperature turbine technology program. Turbine subsystem design report:  Low-Btu gas

The objective of the US Department of Energy High-Temperature Turbine Technology (DOE-HTTT) program is to bring to technology readiness a high-temperature (2600/sup 0/F to 3000/sup 0/F firing temperature) turbine within a 6- to 10-year duration, Phase II has addressed the performance of component design and technology testing in critical areas to confirm the design concepts identified in the earlier Phase I program. Based on the testing and support studies completed under Phase II, this report describes the updated turbine subsystem design for a coal-derived gas fuel (low-Btu gas) operation at 2600/sup 0/F turbine firing temperature. A commercial IGCC plant configuration would contain four gas turbines. These gas turbines utilize an existing axial flow compressor from the GE product line MS6001 machine. A complete description of the Primary Reference Design-Overall Plant Design Description has been developed and has been documented. Trends in overall plant performance improvement at higher pressure ratio and higher firing temperature are shown. It should be noted that the effect of pressure ratio on efficiency is significantlly enhanced at higher firing temperatures. It is shown that any improvement in overall plant thermal efficiency reflects about the same level of gain in Cost of Electricity (COE). The IGCC concepts are shown to be competitive in both performance and cost at current and near-term gas turbine firing temperatures of 1985/sup 0/F to 2100/sup 0/F. The savings that can be accumulated over a thirty-year plant life for a water-cooled gas turbine in an IGCC plant as compared to a state-of-the-art coal-fired steam plant are estimated. A total of $500 million over the life of a 1000 MW plant is projected. Also, this IGCC power plant has significant environmental advantages over equivalent coal-fired steam power plants.

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Rivesville multicell fluidized bed boiler

One objective of the experimental MFB at Rivesville, WV, was the evaluation of alternate feed systems for injecting coal and limestone into a fluidized bed. A continuous, uniform feed flow to the fluid bed is essential in order to maintain stable operations. The feed system originally installed on the MFB was a gravity feed system with an air assist to help overcome the back pressure created by the fluid bed. The system contained belt, vibrating, and rotary feeders which have been proven adequate in other material handling applications. This system, while usable, had several operational and feeding problems during the MFB testing. A major portion of these problems occurred because the coal and limestone feed control points - a belt feeder and rotary feeder, respectively - were pressurized in the air assist system. These control points were not designed for pressurized service. An alternate feed system which could accept feed from the two control points, split the feed into six equal parts and eliminate the problems of the pressurized system was sought. An alternate feed system designed and built by the Fuller Company was installed and tested at the Rivesville facility. Fuller feed systems were installed on the north and south side of C cell at the Rivesville facility. The systems were designed to handle 10,000 lb/hr of coal and limestone apiece. The systems were installed in late 1979 and evaluated from December 1979 to December 1980. During this time period, nearly 1000 h of operating time was accumulated on each system.

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Rivesville multicell fluidized-bed boiler. Quarterly technical progress report, July-September 1980

The objective of this program is to design, construct and test a multicell fluidized-bed boiler as a pollution-free method of burning high-sulfur or highly corrosive coals without excessive maintenance problems. The fluidized-bed boiler will provide approximately 300,000 lb of steam per h. Steam pressure and temperature conditions were selected to meet requirements of the site at which the boiler was installed.

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Field techniques for measuring joint intensity

Hydrocarbon production from fractured reservoirs, increased water-well yields, coal mine roof falls, and some construction problems often have been cited as having been caused by an increase in fracture intensity. A relatively fast and easy method to measure fracture intensity and locating areas of intense fracturing would be generally useful, and in particular, in potential drilling areas where little or no subsurface data is available. As part of the Eastern Gas Shales Project, funded by the US Department of Energy, such a method was developed. This paper reports the summary of methods used, a test of operator variability, and a handbook of suggested procedures. 1 table.

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Development of a coal/water-slurry-fueled diesel engine for industrial cogeneration: Task 1. 0, Thermodynamic analysis

This project is part of a longer-range program in which the objective is to establish a high efficiency prototype industrial power system that can burn coal directly. The power system consists of a slow-speed, two-stroke diesel engine and a fuel preparation system which provides clean micronized coal in a water slurry for use as the primary fuel. The project is divided into five tasks. This topical report is concerned with the subject of Task 1: Thermodynamic Analysis.

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Project ''Topper'': A parametric cycle study for the evaluation of externally-fired, open cycle, cogenerated gas turbines with a natural gas-fired topping burner to attain attractive turbine inlet temperatures for superior performance

Owing to excellent incremental heat rate (8000 Btu/kWh) when firing the topping burner, the ability to use abundant low-cost domestic fuels and heat sources for at least half of the engine heat input, and excellent waste heat steam production, this hybrid cycle has outstandingly good characteristics for stationary power and heat generation. It is worth noting that this hybrid cycle can offer all this with even low state-of-the-art internal engine performance (including an uncooled turbine) and only a steel heat exchanger because it has two simultaneous heat sources - the heat exchanger and the ''topper''which is not used until power production is in the efficient high-power range, plus the cycle is cogenerated. This cycle is attractive in terms of high electrical production efficiency, excellent overall thermal efficiency and efficient substitution of abundant low-cost fuel for scarce imported high-cost fuels. The cycle presents considerable technical risk, not just because it has never been done but also because it has been tried (without the ''topper'') and the program never got the engine beyond starter cranking speeds. A success is yet to be seen. Of all the technologies required, the heat exchanger seems to be the most difficult, especially the task of keeping its size and cost down when the compressor discharge pressure is much higher than the heat source of the heat exchanger. Leakage losses are also a concern if they exist.

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MHD air heater technology development. Annual technical progress report, January 1, 1980-December 31, 1980

Progress on the technology development of the directly-fired high temperature air heater (HTAH) for MHD power plants is described in detail. The objective of task 1 is to continue development of ceramic materials technology for the directly-fired HTAH. The objectives of task 2 are to demonstrate the technical feasibility of operating a directly-fired HTAH (including both the heater matrix and valves), to continue obtaining information on life and corrosion resistance of HTAH materials, and to obtain design information for full-scale studies and future design work. The objectives of task 3 are to begin the identification of HTAH control requirements and control system needs, and to continue full-scale study efforts incorporating updated materials and design information in order to identify development needs for the HTAH development program. (WHK)

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Investigation of carbon-formation mechanisms and fuel-conversion rates in the adiabatic reformer. Annual report, March 19, 1980-March 19, 1981

Fuel cell power plants may be required to use coal derived liquid fuels or heavy petroleum distillates as fuels. Among the fuel processor candidates, the adiabatic reformer is at the most advanced state of development. The objective of the present program is to establish a reactor model for the adiabatic reformer which will predict process stream compositions and include carbon formation processes. Four subordinate tasks were proposed to achieve the objective. These are: 1) to determine on selected catalysts rate expressions for catalytic reactions occurring in the entrance section of the adiabatic reformer; 2) to determine with microbalance experiments critical conditions for carbon formation on selected catalysts; 3) to establish a reactor model to predict process stream compositions in the adiabatic reformer using data from Task 1 for catalytic reactions and data from the literature for homogeneous gas phase reactions; and 4) to establish a model to predict carbon formation by combination of the model for process stream composition from Task 3 and data for carbon formation from Task 2. Progress is reported. (WHK)

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In-house coal-fuels combustion technology for use with gas turbines

This report briefly describes the Department of Energy's (DOE's) coal-fueled gas turbine program as implemented by the Department's Morgantown Energy Technology Center (METC), and presents in some detail METC in-house research and development (R and D) related to this program. Previous coal-fired gas turbines and technological barriers to their use are discussed. The incentive for the Department's coal-fueled turbines program is the development of a modular, low-cost, electric-generating capacity using domestic coal as the fuel. The program concept is an outgrowth of, and builds upon, past DOE programs in heat engines and coal preparation. Recent and anticipated advances in these technologies are being examined in an integrated systems approach to electric power generation. In-house R and D includes laboratory- and bench-scale combustion testing, systems and economic analyses, and computer modeling of the combustion and deposition processes.

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User's manual for computer simulation and design of the moving-bed coal gasifier. Final report

A computer model of countercurrent moving-bed coal gasifier developed previously has been updated. This manual presents in detail how the computer program developed is used. The unique feature of the present gasifier model is the treatment of the pyrolysis of coal. A semi-empirical approach is taken in the present model to represent the pyrolysis zone of the bed. The pyrolysis reactions are represented by three simple chemical reactions: devolatilization, cracking and carbon deposition with empirically estimated reaction rate constants. The gasification reactions are assumed to be heterogeneous reactions. For fast reactions, diffusion is the rate controlling step while for slow reactions, the surface reactions within the pores of particles is the rate controlling step. Therefore, the rates of gasification reactions used in the model are composed of two terms, the reaction term and the diffusion term. The computer program developed can be used for both simulation and design. It can be used to simulate a gasifier to obtain the gas product distributions and coal conversion and calculate the required bed height for a given carbon conversion. A map of feasible operation ranges can then be constructed for the optimum design of a gasifier. Kinetic parameters for three different kinds of coal are specified in the program. However, the program users may change these parameters according to the guides listed in the manual if the coal used is different. In addition, the reaction rate equations may be replaced if better rate expressions become available. It is important that the user checks the assumptions, the simplifications and the limitations of this computer program before applying in order to assure that the applicability of the model is within the range specified. The scale-up and extrapolation from normal operating conditions should be done with caution and, if possible, verified through additional experimentations.

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Coal-fueled diesel locomotive economic assessment

This report presents an initial effort in determining the eonomic viability of a coal-fueled diesel locomotive for the time period 1995 to 2010. The criteria used for determining the economic viability of a coal-fueled diesel is the internal rate of return on investment (IRR). The coal-fueled diesel locomotive is compared to a baseline petroleum-fueled diesel. The coal-fueled diesel locomotive is still very much conceptual, therefore many assumptions are made with regard to cost, operating procedure, fuel form, fuel cost, maintenance, etc. The assumptions are discussed and the spreadsheet calculation procedure used for determining the IRR is presented. Conclusions based on the assumptions and calculations are given.

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Effects of aqueous effluents from in situ fossil fuel processing technologies on aquatic systems. Progress report, 1 January 1980-1 November 1981

During 1980, we completed the literature review task with publication of Volumes 1 and 2 of the ''Bibliography of Aquatic Ecosystem Effects, Analytical Methods and Treatment Technologies for Organic Compounds in Advanced Fossil-Fuel Processing Effluents.''A summary of work completed on all process waters evaluated during this project (15 May 1977 through 1 November 1981) is presented. A total of 32 process waters from coal gasification, oil shale retorting and tar sands extraction have been evaluated through our screening steps that include chemical toxicity, degradation and bioaccumulation testing. For the current reporting period we have completed work on 9 process water samples or sample sets: (1) the embryo-larval bioassay exposing fathead minnows (Pimephales promelas) to Hanna-4B-01W coal gasification condenser water; (2) toxicant avoidance bioassays with the same Hanna-4B sample; (3) acute toxicity bioassays of chemical fractions of Hanna-3 (CGR-76-178) coal gasification condenser water; (4) Occidental-6 oil shale retort water (embryo-larval bioassays on fathead minnows and rainbow trout,6679 ); (5) Lawrence Livermore Run-4 oil shale retort water (chemical characterization, acute toxicity tests, and toxicant avoidance tests,6679 ); (6) Geokinetics-17 oil shale retort water (chemical characterization and acute toxicity tests,6679 ); (7) Omega-9, Geokinetics-9, and Paraho Tank 500 oil shale retort waters (fractional toxicity tests,6679 ); and (8) one major tar sands process water, Vernal tar sands water (80-Tarsand-1S-03W-00-C). Because this sample was produced as a stable oil-water emulsion, it was necessary to treat the sample in various ways producing several treated water samples which were characterized along with the raw water.

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Study of CO/sub 2/ recovery and tertiary oil production enhancement in the Los Angeles Basin. Final report, September 1978

Results are presented of stuides conducted to evaluate carbon dioxide sources in the Los Angeles Basin, determine the requirements for upgrading and transmitting the gas, write the necessary material specifications, and determine where carbon dioxde may be effectively utilized as an enhanced recovery agent in oil fields, estimate recovery performance, and evaluate potential economic benefits. Study results show that there are two major sources of CO/sub 2/ in the Los Angeles Basin. Six oil refineries and one ammonia plant (all near Los Angeles Basin oil fields), have hydrogen plants with by-product streams of concentrated CO/sub 2/. The total available (uncommitted) CO/sub 2/ from these streams is about 3,000 tons per day. Six major electric power plants, all near L.A. Basin oil fields, discharge a combined total of 70,000 tons per day of CO/sub 2/ from 27 large boilers. Average CO/sub 2/ concentration in the flue gas is about 14 percent on a dry basis. CO/sub 2/ processing recommendations include modification of the existing hydrogen-CO/sub 2/ separation system, so that nitrogen is not used for stripping and therefore does not need to be removed, use propylene carbonate absorption, and use low-temperature separation. For CO/sub 2/ extraction from flue gas, monoethanolamine (MEA) absorption is recommended. Several reservoirs have been identified and are listed as prime candidates for CO/sub 2/ injection, using the major criteria of high oil saturation in the reservoir, suitable depth of the reservoir, and a good potential for zone control. (JRD)

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Literature review for steam pretreatment. [85 references]

A literature survey has been conducted to support an experimental investigation of steam pretreatment of coal for improving liquid yields and quality in gasification processes. Experiments have so far shown pretreatment to be effective from 320 to 360/sup 0/C in 50 atm. steam. Information on thermal effects, steam reactivity, and phase equilibrium at temperatures and pressures which are relevant, but not restricted, to these conditions have been reviewed. Evidence for thermal activity below 350/sup 0/C comes from observation of softening and/or melting, acidity, volatiles loss, solvent extraction, differential thermal analysis, differential scanning calorimetry, electron spin resonance, and mild oxidation reactions. Reaction of steam with shale oils at 425/sup 0/C and with coal and model compounds in the neighborhood of the critical point have been reported. Phase equilibrium data show complete mutual solubility of water and aromatic hydrocarbons at conditions approaching those of pretreatment. A few pretreatments reported for other processes are noted. A survey of studies of weathering is included for its possible relevance to the observed sensitivity of pretreated coal to ambient air exposure. These literature citations corroborate our experimental findings and offer possible explanations for pretreatment. To discriminate among these possibilities and to provide a more detailed picture of the processes will require further experimental work. 85 refs.

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Technical assessment massive foam stimulation attempt in Mercer Co. , PA. The Peoples Gas Company well No. 4978

This report provides an assessment of a large-scale foam fracturing test performed by the Peoples Gas Company in cooperation with the Energy Research and Development Administration (now the Department of Energy) in Mercer County, PA. The test was designed to evaluate gas productivity of the Devonian Shale in a currently non-producing area, and was to utilize 270,000 gallons of nitrogen/water foam as the fracturing fluid and 324,000 pounds of sand proppant in a massive stimulation attempt. Unexpectedly high treating pressures encountered during the frac job as well as a mechanical packer problem caused a catastrophic downhole casing failure and the stimulation test could not be completed. The report describes the aborted foam fracturing operation and its aftermath. After extensive remedial efforts, the well was plugged and abandoned, but the Devonian Shale, despite the stimulation failure, produced some evidence of free gas in place.

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Hanna, Wyoming underground coal gasification data base. Volume 1. General information and executive summary

This report is part of a seven-volume series on the Hanna, Wyoming, underground coal gasification field tests. Volume 1 is a summary of the project and each of Volumes 2 through 6 describes a particular test. Volume 7 is a compilation. This report covers: (1) history of underground coal gasification leading to the Hanna tests; (2) area characteristics (basic meteorological and socioeconomic data,6674 ); (3) site selection history; (4) site characteristics; (5) permitting; and (6) executive summary. 5 figs., 15 tabs.

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In-situ stress determination of Devonian shales. [Depth - 1500 to 8000 ft]

One of the important design parameters to improve natural gas recovery from Devonian shale through hydraulic fracturing operations is to determine accurate values of in-situ stresses at depths between 1500 and 8000 feet. This study has attempted to develop a methodology to accurately and economically determine the magnitude of overburden pressure and horizontal (in-situ) stresses. This is attempted, herein, through an extensive experimental program to establish basic mechanical properties, and through a refined analytical model based on the finite element method accounting for the stress-relieved core fracture phenomenon. In compliance with the ASTM and Bureau of Mines standards, Devonian shale samples were tested under split tension, direct tension, three-point bending, uniaxial and biaxial compression and direct shear to find the mechanical properties, fracture toughness and stress-strain behavior in the overburden and bedding plane directions. The proposed analytical phase to find horizontal stresses by incorporating the mechanical properties and fracture toughness constants has not been carried out due to difficulties encountered in implementing the computer based model on WVNET for Educational Telecomputing. However, the stress memory concept has been utilized to determine the overburden and horizontal stresses through the stress-strain plots of Devonian shales under biaxial compression. It has been shown that the overburden and horizontal stresses from the stress-strain plots compared extremely well ( - 5 percent) with the stresses obtained from the field hydraulic fracturing experiments. Based on the experience gained during this research program, pertinent recommendations are made.

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