AndreaBozzo/ceres-open-data-index huggingface dataset:
Quarterly air quality and meteorology data. Final technical report, November 1980-May 1982. [Proposed WyCoalGas project, Converse County, Wyoming; air quality and meteorology data at proposed site]

This report summarizes the meteorological and air quality data that have been collected during the fourth quarter and the whole year of monitoring (September 12, 1981 to December 11, 1981 and December 12, 1980 to December 11, 1981), at the proposed WyCoalGas coal gasification project site near Douglas, Wyoming. Details concerning monitor operation, siting, and data collection are provided in earlier WyCoalGas, Inc., submittals to the Wyoming Department of Environmental Quality (DEQ) (November 17, 1980, and February 10, 1981). Quarterly precision and accuracy results are reported, as well as brief discussions of periods of maximum concentrations for each pollutant. Fourth quarter audit results were prepared from a performance audit conducted on December 1-3, 1981 (Woodward-Clyde Consultants March 1982). Measurements of wind speed and direction have been processed and summarized to provide a joint frequency distribution for the two sensor levels. Temperature data that have been tabulated and summarized, are presented in Appendix A-2.0. Visibility data have been summarized to provide a cumulative frequency distribution and are presented in Appendix A-3.0. Also provided are brief discussions of the ambient visibility. Total Suspended Particulate matter data from Station 2 (Project Monitor Site), have been tabulated for the period from September 16, 1981 to December 12, 1981 and are presented in SAROAD daily format in Appendix A-4.0. The results of the analyses of particulate matter samples for ambient lead concentrations are also presented in SAROAD daily format in Appendix A-4.0. Hourly data for the following parameters are presented in Appendix A-5.0: nitrogen dioxide (NO/sub 2/), sulfur dioxide (SO/sub 2/), ozone (O/sub 3/), visibility (B-scat), wind speed and direction (lower level (33 feet) and upper level (131 feet)), standard deviation of horizontal wind direction (lower level (33 feet) and upper level (131 feet)), temperature (33 feet), and pressure.

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Computer modeling of coal gasification reactors. Year 4. Annual report, October 1978-September 1979

The research in Year 4 was primarily directed to the application of the fluidized bed computer model to specific gasifier systems. These simulations include jet penetration of bubble formation, solids mixing and product gas composition for the Institute of Gas Technology (IGT) six-inch diameter bench scale reactor, and cold flow predictions of jet penetration and solids recirculation in the IGT-UGAS and Westinghouse-Agglomerating Combustor/Gasifier reactors. The fluidized bed coal gasifier computer model is designed to provide a description of the hydrodynamic mixing and coupled chemistry within the reactor. This model should permit a designer to predict: bubble size, gas composition and temperature, stagnant particle regimes, elutriation, jet penetration, and solids mixing. It is basically a hydrodynamic model, including particle scale effects, which can, therefore, be used to study scaleup and optimization of fluidized bed gasifiers. The hydrodynamic component of the model has been validated through comparison with cold flow visualization data and limited hot flow measurements. The chemistry component of the model is, in most aspects, identical to the chemistry of the classical models of fluidized bed gasification. A major difference between the classical models and the present fluidized bed coal gasification computer model is that the classical models require specification of the bed hydrodynamics, such as bubble size. The present model can predict bubble size and the associated solids mixing.

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Operating experience with Grimethorpe Distributor Plate Seal. Part 1. Initial design and first stage modification

During the early stages of hot commissioning of the Grimethorpe Experimental Facility it was found that the Distributor Plate Seal did not operate correctly. It allowed the upward leakage of fluidizing air and the downward leakage of bed material out of the combustor. The seal was modified and has now performed satisfactorily during a number of hot commissioning trials. Additionally, a further modification involving the elimination of the seal from the base of the combustor is being developed and will be available should the first modification prove to be unacceptable as a long term solution.

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Fiber optic sensor fluidized bed behavior measurement. Final report

The goal of this program is to develop a quartz fiber optics sensor suitable to measure relevant bubble parameters in an operating fluidized bed combustor. During the preceding ten month period, a probe has been designed and assembled. The probe was first tested in a 6''cold bed built especially for this project. The relative distribution of bubble sizes (or, more correctly, of void dimension in the vertical direction) is exhibited. The bubble frequency distribution is plotted. The above constitutes a full set of relevant information on bubble dynamics. In addition, the number of bubbles detected by the probe can be directly counted and plotted versus superficial air velocity. Several hot bed tests were conducted. It was found that the probe could successfully detect bubbles until a bed temperature of approximately 730/sup 0/C was reached. At that temperature, the signal got lost and the probe stopped functioning. When the probe was opened up at the end of the eight hour run, we found that the optical fibers had disintegrated. Although the precise nature of the failure has yet to be ascertained, it is most probably associated with the failure of the cladding material of the optical fiber which is not specially made for high temperature use.

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Weeks island ''S''sand reservoir b gravity stable miscible CO/sub 2/ displacement Iberia Parish, Louisiana

Shell, in conjunction with the Department of Energy, is conducting a gravity stable displacement field test of the miscible CO/sub 2/ process. The test is being conducted in a 12,800-foot deep Gulf Coast reservoir. Injection of the CO/sub 2/ slug at the producing gas-oil contact commenced in October 1978. The slug of CO/sub 2/ is being moved downward by production of downdip water. Injection of the 50,000-ton slug was completed in February of 1980, and production is projected to start in the third quarter of 1980. Conventional cores and the log-inject-log technique were used to determine residual oil saturation in a well drilled as the pilot producer. The new well is being used to monitor the downdip displacement. Pulsed neutron logging devices have been used to monitor the downdip displacement. Pulsed neutron logging devices have been used to monitor the CO/sub 2/ movement in the vicinity of the observation well. The logs have been successful in detecting the CO/sub 2/ slug and its subsequent movement. Production tests of the log-inject-log perforations, located in a previously watered-out portion of the sand, 48 feet below the point of CO/sub 2/ injection in the offset well, have indicated an oil column has passed the observation perforations. Further tests and logs indicated CO/sub 2/ had reached the observation perforations in November 1979. These perforations were then squeezed off and new production perforations were placed at the final completion depth 130 feet below the level of CO/sub 2/ injection.

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EASTERN GAS SHALES PROJECT APPALACHIAN,ILLINOIS AND MICHIGAN BASIN CORING, LOGGING AND WELL EVALUATION PROGRAM

This report summarizes the results of work involving drilling, coring, logging and/or testing of 13 wells as part of the US Department of Energy's Eastern Gas Shales Project (EGSP) coring program in the Appalachian, Illinois and Michigan Basins. The 13 wells include seven in New York State, two in Pennsylvania, one in Tennessee, one in Illinois and two in Michigan. The results of each well are evaluated in regard to regional and local exploration rationale formulated by EGSP investigators prior to drilling. New information acquired in the course of coring, logging and testing of these wells is summarized. The complete details of drilling operations and results of analyses of cores, logs, and stimulation of each well are contained in final reports submitted by Gruy on each well.

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Organic composition of Devonian shale cores from Wells No. 11940 and No. 12041, Cottageville, Jackson County, West Virginia

Detailed studies of the composition of the organic content of two shale cores from Cottageville, West Virginia, are reported. Analyses were performed on core samples selected at five foot intervals from a 287 ft section of core from the L.A. Bailer Well No. 11940; and a 470 ft section of core from the W.L. Pinnell Well No. 12041. The two wells are located approximately 5 miles apart. The core samples were analyzed for total organic material, organic and mineral carbon, and solvent extractable organics. Infrared spectroscopy and thermal chromatography were used to determine the gross organic composition of extracted and pyrolysis products. Isolation of the bitumen and kergen was accomplished by solvent extraction and chemical separation. Variations in the total organic content, benzene-soluble organic, and pyrolysis product composition are presented for both cores. The organic content and composition of these two cores are also compared with Perry County, Kentucky, well results reported in TPR 77/3. The organic carbon content for the cores from Cottageville, WV, shows an average of 1.48% for No. 12041 and 2.47% for No. 11940. In both cores these values are much less than the organic content of the core No. 7239 from Perry County, Kentucky, which averaged 3.95%. Stratigraphic variations observed in the organic content were similar in the upper two-thirds of the two Cottageville cores. The amount of solvent extractable organics in both of the Cottageville cores is less than that observed for the core from Perry County, but does vary with the amount of organic material in the samples studied. The extraction ratios, however, vary in a similar manner to that observed for the Perry County, Kentucky core. The extractable organics are primarily aliphatic in composition. No apparent relationship between the pyrolysis product composition and organic carbon content was observed.

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Pilot study of gas production analysis methods applied to Cottageville field

Gas production data from 63 wells in the Cottageville Gas Field, producing from Devonian shales, are studied in relationship to structure above and below producing horizons, isopach data and dip of producing shales, and basement structure trends. Gas production data are studied from several aspects including highest accumulated production, mean annual production, initial well pressure, and calculated loss ratio values for four different time periods. A trend correlation of these parameters is presented. The initial pressure trends correlate with all geological parameters, i.e., Devonian shale dip and strike, 40 to 50/sup 0/ NE fracture facies trend, structure on the base of the Huron, structure on the top of the Onondaga, and the basement magnetic density data. Production data trends show greatest correlation with structure on the top of the Onondaga and with fracture facies trends from the Baler well. Production decline data in terms of loss ratio values show trends correlating with all geologic parameters except the Onondaga. Two loss ratio maps correlate with the structure on the bottom of the Huron. The strike of Onondaga structure correlates with the 40 to 50/sup 0/ NE fracture facies trend. These parameters may be generally viewed as the production maps representing free gas pockets and migration-accumulation trends; the loss ratios as possible permeability and migration trend indictors; and the geologic parameters as possible constraints or causative agents. The lack of correlation of geologic parameters with production data trends a few degrees west of north may be suggestive of a fault or faults in that direction, providing the correlative causative agent. This is not an unreasonable possibility from the production data maps. It is concluded that this approach could be useful in gas exploration and development evaluation of Appalachian Devonian shale gas fields. Similar relationships will be examined in the Eastern Kentucky Gas Field(s) Study presently in progress.

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Structural mechanics simulations associated with underground coal gasification. [Including temperature dependence]

Analytical simulations of the structural and thermal responses associated with the Longwall Generator concept of underground coal gasification are described. The work includes characterization of the mechanical properties of coal and shale overburden at elevated temperature, preliminary thermal and structural response modeling, finite element model formulations, and master model analysis. The characterization of mechanical properties of coal and shale overburden includes thermotheological representation of Pittsburgh coal and shale overburden at elevated temperature and the swelling characteristics of bituminous coal. For the preliminary thermomechanical modeling, dynamic thermal and stress response solutions are obtained for boundary value problems representing a radially expanding circular cavity and a line drive in the coal seam. Two dimensional static stress, displacement, and temperature fields are presented for cylindrically circular and elliptic cavities in a homogeneous isotropic medium. Field stresses, displacements, and temperature profiles for various structural model representations are obtained using finite element model formulations. The effects of layering, coke/softened layered regimes, and roof collapse are investigated. Subsidence and roof collapse resulting from in-situ gasification are computed employing elasto-plastic finite element formulations. The results are compared to empirical and classical results from conventional mining. Master model analyses by use of the canned NASTRAN program are conducted to provide a general simulation of the structural mechanisms in the vicinity of burn cavity and the gross strata movements. The results from the NASTRAN program are calibrated with a finite element computer program developed here. It is concluded that structural responses are important in the consideration of the UCG processes.

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Coal gasification via the Lurgi process: Topical report: Volume 2, Production of IFG (industrial fuel gas)

A Lurgi baseline study was requested by the DOE/GRI Operating Committee of the Joint Coal Gasification Program for the purpose of updating the economics of earlier Lurgi coal gasification plant studies for the production of industrial fuel gas (IFG) based on commercially advanced technologies. The current study incorporates the recent experience with large size Lurgi plants in an effort to improve capital and operating costs of earlier plant designs. The present coal gasification study is based upon a plant producing 73.3 billion Btu (HHV) per day of IFG using the Lurgi dry bottom coal gasification technology. A Western subbituminous coal was designated as the plant feed, obtained from the Rosebud seam at Colstrip, Montana. This study presents the detailed description of an integrated facility which utilizes coal, air, and water to produce 73.3 billion Btu (HHV) per day of industrial fuel gas. The plant consists of coal handling and preparation, seven Lurgi dry bottom gasifiers, acid gas removal, sulfur recovery, phenol and ammonia recovery, as well as necessary support facilities. The plant is a grass roots facility located in the area of Minneapolis, Minnesota. The Lurgi Corporation assisted in this study, under subcontract to Foster Wheeler, by supplying the heat and material balances, flow sheets, utilities, catalysts and chemical requirements, and cost data for Lurgi designed process sections. Details of material supplied by Lurgi Corporation are presented in Appendix A. 39 refs., 33 figs., 50 tabs.

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Fundamental research on novel process alternatives for coal gasification: Final report

The Institute of Gas Technology has conducted a fundamental research program to determine the technical feasibility of and to prepare preliminary process evaluations for two new approaches to coal gasification. These two concepts were assessed under two major project tasks: Task 1. CO/sub 2/-Coal Gasification Process Concept; Task 2. Internal Recirculation Catalysts Coal Gasification Process Concept. The first process concept involves CO/sub 2/-O/sub 2/ gasification of coal followed by CO/sub 2/ removal from the hot product gas by a solid MgO-containing sorbent. The sorbent is regenerated by either a thermal- or a pressure-swing step and the CO/sub 2/ released is recycled back to the gasifier. The product is a medium-Btu gas. The second process concept involves the use of novel ''semivolatile''materials as internal recirculating catalysts for coal gasification. These materials remain in the gasifier because their vapor pressure-temperature behavior is such that they will be in the vapor state at the hotter, char exit part of the reactor and will condense in the colder, coal-inlet part of the reactor. 21 refs., 43 figs., 43 tabs.

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Pretreatment techniques for coal gasification. Sixth quarterly report, January 1-March 31, 1986. [Steam treatment of coal to increase eight liquid yields]

Pretreatment of coal in steam is being explored with the goal of improving the economic attractiveness of coal gasification by cogeneration of light liquid fuels. The final draft of a literature survey has been completed and issued. Inert gas pyrolysis runs were made at atmospheric pressure with raw and pretreated Illinois No. 6 coal. Two coal batches showed no response to pretreatment in either pyrolysis or extraction perhaps because of oxidation during grinding. A new batch was ground, and this showed a response to pretreatment in agreement with that obtained in earlier experiments. The maximum liquid yield of 33 wt. % at 650/sup 0/C is raised to 40% by pretreatment. A procedure for determination of gas yields using the on-line mass spectrometer was implemented. Material balance closures between 90 and 95% are obtained. Helium pyrolysis of raw and pretreated Illinois No. 6 coal was conducted at 200 and 500 psia. The yield of liquid product is severely depressed by increasing pressure and is not improved by steam treatment. Kentucky bituminous coal (-8 mesh) received from United Coal Co. was ground under nitrogen to pass 200 mesh. Pyrolysis tests with this coal were conducted in 20 psia helium at temperatures from 550 to 800/sup 0/C. Material balance closures are 90 to 98% and averaged 93.4%. A maximum condensable yield of 28 wt % on daf coal is obtained at 650/sup 0/C. Room temperature pyridine extracts from raw and pretreated Illinois No. 6 were fractionated according to molecular weight and functionality using liquid chromatography. Extract from pretreated coal contains less polyfunctional material, more basic nitrogen species, and more oxygen containing species. The former results suggest cleavage of multifunctional components, the latter may arise from oxidation of the extracts during handling. 6 figs., 8 tabs.

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Techniques for coal gasification: Final report. [Conditioning coal in steam]

Conditioning of coal in steam is being explored with the goal of improving the yield and quality of condensable hydrocarbon product obtainable by mild gasification. A literature review shows that temperatures between 300 and 350/sup 0/C are promising for this purpose. In this range there is evidence that coal is thermally labile and that steam can dissolve in and react with coal. Experiments were conducted using a semicontinuous bench scale reactor processing up to 2.5 grams per run. Raw and conditioned samples of Illinois No. 6 coal were mild gasified in steam at atmospheric pressure and in inert gas at pressures up to 500 psia. Atmospheric pressure tests under inert gas were carried out with raw Kentucky bituminous coal, steam conditioned coal, and coal mixed with hydrated lime. When Illinois No. 6 coal is mild gasified in either inert gas or steam at atmospheric pressure, conditioning at 340/sup 0/C for 15 min. in 50 atm. steam increases the yield of condensable product by 30%. The corresponding result in inert gas for this sample of Kentucky bituminous coal is 5%. Considerable progress has been made in understanding the steam conditioning effect through comparative studies of steam conditioned, helium conditioned, and raw samples of Illinois No. 6 coal using solvent extraction, diffuse reflectance infrared spectroscopy, and solvent swelling. Extraction of steam conditioned coal with pyridine at room temperature gives twice the extract yield obtained from raw coal and in all respects parallels the results from mild gasification. Steam conditioning greatly increases the swelling of coal in water and water miscible solvents, but not in water immiscible solvents, and shows changes in the infrared spectrum only in the region attributed to hydroxyl groups. An interpretation of these results is that new hydroxyl groups are formed during steam conditioning at sites which in the starting coal are covalently bound. 97 refs.

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Reservoir characterization for the CO/sub 2/ enhanced oil recovery process: Annual report

This report summarizes progress in a research effort to quantify the effects of nonuniform flow on displacement performance in CO/sub 2/ floods. Results are reported in three areas: (1) effect of phase behavior in one-dimensional flow; (2) interaction of viscous instability and flow in heterogeneous porous media; and (3) detection and representation of reservoir heterogeneity. 94 refs., 83 figs., 8 tabs.

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Industrial market for sulfur dioxide emission-control systems. Final report. [Forecasting to 2000]

Under the postulated EIA medium world oil price scenario, in which oil prices are projected to rise at a real rate of 2.2% per year, coal will represent from 78 to 91% of MFBI fuel consumption by the year 2000, up from the present 16%. This increase would occur even in the absence of FUA, because the cost of coal is substantially lower than the cost of oil or gas. Much of this market will develop in the relatively near to intermediate term (before 1990). Annual installations will be much lower (by about 40%) after that period, reflecting a lower overall steam demand growth rate and the fact that much of the discretionary conversion of gas and oil boilers to coal will have been completed. About 22% of the sales will be for discretionary conversion of oil and gas boilers still having some useful life; the rest will be for nondiscretionary expansion or replacement of worn-out boilers. Under the postulated cost and performance estimates for the competing coal-burning technologies, we expect that AFB combustors and lime spray dryer FGD systems will dominate the market, with 42% of the market in our base case scenario. If the attitudes of the industrial decision-makers are factored into the analyses, particularly their aversion to FGD systems with wet wastes, the AFB and lime spray dryer technologies will capture as much as 73% of the coal-burning market. Costs for the various flue gas desulfurization (FGD) technologies were projected to be sufficiently close that the selection of one over another will depend on site-specific factors such as the availability of waste disposal facilities, the demonstrated reliability of the particular systems, and the vendor's reputation.

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