AndreaBozzo/ceres-open-data-index huggingface dataset:
Q-switched laser-induced reactions of thiophene with oxygen

Q-switched, laser-induced reactions of thiophene with oxygen were studied as a function of oxygen pressure in the range 0 to 500 Torr. The reaction products identified were CO/sub 2/, SO/sub 2/, H/sub 2/S, H/sub 2/O, C/sub 2/H/sub 2/, and COS. The product distribution varied with oxygen partial pressure. All products, except SO/sub 2/, reached maximum concentrations at 200 Torr of O/sub 2/, whereas SO/sub 2/ reached a minimum at this pressure. No explanation for the behavior of SO/sub 2/ is given. A possible explanation for the small concentration of C/sub 2/H/sub 2/ detected in the reaction mixture was advanced from the standpoint of elemental plasma reactions.

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Petroleum in the Williston Basin, including parts of Montana, North and South Dakota, and Canada, as of July 1953

Geologically, the Williston Basin is a large structural depression of sedimentary rock in Montana, North Dakota, and South Dakota and Manitoba and Saskatchewan, Canada. The approximate limits of the basin are shown on figure 1; it is roughly circular with a diameter of about 400 miles and contains approximately 120,000 square miles.

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Porosity of the Sundance sand in the Lance Creek oil field, Wyoming

"The growing importance of the Sundance (Jurassic) formation as a source of oil in the Rocky Mountain area has prompted the making of a series of porosity determinations of core samples collected from t he reservoir sands of the Lance Creek oil field ,Niobrara County, Wyoming. These analyses are preliminary to a study of fluid and energy relations in the Basal Sundance  reservoir of that field, and the determinations of porosity will be used in subsequent studies requiring calculations of the volumetric capacity of the reservoir and estimation of the reserves of oil and gas."

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A FIELD AND LABORATORY PROJECT TO ASSESS THE TECHNICAL SUITABILITY OF NEW MEXICO'S DEEP SEAM SAN JUAN BASIN FOR IN SITU COAL GASIFICATION

"The University of New Mexico, in cooperation with the local utility company, Public Service Company of New Mexico, has initiated a potential six-year project to assess the technical feasibility of underground coal gasification in the San Juan Basin of New Mexico. This paper describes the initial work of characterizing the chemical, physical and geological nature of a proposed UCG site located near the San Juan Power Generating Station in northwest New Mexico. The six-year project is also discussed.  A potential underground coal gasification site has been selected. Results of the preliminary drilling, hydrology, geology and environmental studies are presented. The studies to date have shown that the San Juan UCG site is similar in coal composition, permeability and water saturation to the Hanna, Wyoming site. The seam thickness is about half that of the Hanna site. Preliminary findings offer encouragement for in situ gasification of New Mexico coal."

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RESEARCH AND DEVELOPMENT LICENSE APPLICATION

Activity proposed for the Hanna UCG Facility is that required to bring the facility into compliance with regulations of the Wyoming Department of Environmental Quality, Land Quality Division for a research and development in-situ testing license. Since additional experiments are, currently, not planned for the Hanna Facility, activity will focus on groundwater and surface restoration of old burn sites. An extensive program (including drilling and coring) is planned for the collection of additional baseline data to further access the geology and hydrology of the proposed license area. Existing burn sites will be thoroughly monitored using new and existing wells in conjunctions with the groundwater restoration activities.

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Coal conversion technology

The basis of this book was a desire to prepare a report which provides readily accessible and concise data on all major activities in coal conversion technology. The data are given in three main sections: Section I, Coal Conversion Processes for the Production of Solid, Liquid, and gaseous products; Section II, High-Btu Coal Gasification Processes; and Section III, Low- and Medium-Btu Coal Gasification Processes.

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Thermal reactions of organic nitrogen compounds. I. 1-methylpyrrole

The thermal reactions of 1-methylpyrrole were investigated by the flow method over the temperature range of 475 to 700/sup 0/. In the temperature interval of 475 to 575/sup 0/ the reaction was found to be a homogeneous first-order isomerization that may be represented as shown: 1-methylpyrrole yields 2-methylpyrrole reverse arrow 3-methylpyrrole. The Arrhenius equation for this reaction, based on the disappearance of 1-methylpyrrole, is k = (2.39  - 0.11) x 10/sup 12/e/sup -(54,800  - 100)/RT/. Above 575/sup 0/ there was decomposition to give a complex mixture of reaction products.

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Trace elements in oil shale. Progress report, 1976--1979

The purpose of this research program is to understand the potential impact of an oil shale industry on environmental levels of trace contaminants in the region. The program involves a comprehensive study of the sources, release mechanisms, transport, fate, and effects of toxic trace chemicals, principally the trace elements, in an oil shale industry. The study group is a multi-institutional, interdisciplinary team from the University of Colorado, Colorado State University, and the Colorado School of Mines.

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Numerical simulation of air flow in a tar sand reservoir using the method of lines

This paper describes a two-dimensional numerical model for simulating the pressure distribution and air flow in a tar sand bed as a result of air injection into the middle line of a linear nine well pattern. The method of lines is used to solve the nonlinear differential equation describing the flow. The effects of injection pressure and well radius on the air flux are reported. The results are presented in context of field study of oil recovery from tar sands by reverse combustion.

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Results of experiments with underground gasification of brown coal in Northern Bohemia (Czechoslovakia)

"According to the resolution of the XIth Congress  of the Communist Party of Czechoslovakia it is necessary to concentrate on the application of underground gasification of coal (UGC) wherever conventional methods cannot be used. The article describes the results of experiments conducted in the North Bohemian brown coal basin and assesses the prospects for developing underground gasification on an industrial scale. The  experiments so far have been conducted without underground work, by using the filtration method , and have produced gas with a calorific value of 750- 850 kcal/Nm3 with atmospheric air as the gasification agent."

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Hydrodynamics of the underground gasification process

The idea of underground gasification of solid fuel, first advanced at the end of the past century by D.I. Mendeleev, specifies the utilization of the potential thermal energy it contains without extraction of the fossil fuel to the surface. V.I. Lenin made a high appraisal of the method of underground gasification of coal, brilliantly anticipating its revolutionary importance in the development of technology.

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Technique of drilling vertical and inclined directed boreholes for the underground gasification of coal. [Description of rigs and equipment]

At the present stage of technological progress, the preparation of shaftless underground gas generators is not feasible without the drilling of boreholes.  The different borehole varieties that are drilled from the surface are essential to the mapping of coal seams for the gasification, drainage of designated areas, construction of air inlets and gas offtakes, and the development of fire range.  They are also needed for the subsequent gasification drainage and pumping operations comprising the work of gas generators.

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Mathematical comparisons with the inclined fluidized bed retort

A one-dimensional oil shale retorting model was used to simulate inclined fluidized bed retorting of western oil shale. The calculated oil yields agree fairly well with data from previous experiments because the stoichiometry and kinetics of western oil shale pyrolysis do not depend strongly on heating rate. Although the model produces acceptable results with western shales, an understanding of the retorting mechanism for eastern shales at high heating rates is necessary to properly predict oil recoveries under fluid bed conditions. 6 refs., 3 tabs.

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Energy balance for the second underground coal gasification experiment, Hanna, Wyoming

The second underground coal gasification experiment conducted by ERDA's Laramie Energy Research Center at a site near Hanna, Wyo., was completed on July 30, 1976. During the experiment production reached 0.32 Mm/sup 3//d (12 M cu ft/d) of 6.9 MJ/m/sup 3/ gas (175 Btu per cu ft). Approximately 6100 tonnes (6700 tons) of coal were gasified during the experiment. Energy return ratios of 4.5 to 5.3, coal gas thermal efficiencies of 76 to 89%, and overall process efficiencies of 65 to 74% were achieved during the second Hanna experiment. This paper describes the experiment and the results obtained with emphasis given to the determination of the energy recovered relative to energy consumed in conducting the test. Data from this determination are compared with previously published data from the first test conducted at Hanna during 1973-74.

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Mechanical behavior of Anvil Points oil shale at elevated temperatures and confining pressures. [Compressive strength, ductility, fractures]

Twenty-one constant strain rate compression tests have been performed on 80 ml/kg (20 GPT) Anvil Points oil shale at elevated temperatures (50 to 200/sup 0/C) and confining pressures (0.5 to 40 MPa). The strength of oil shale increases with confining pressure and decreases with temperature. Ductility is greatly enhanced by addition of confining pressure. Elevated temperatures have little influence on ductility at low confining pressures; however, at greater confining pressures, temperature exerts a progressively stronger influence on ductility. A purely empirical failure law, incorporating the effects of temperature and confining pressure, has been fitted to the data. The failure law is in good agreement with the results of other studies on the compressive strength of oil shale. All specimens in this study exhibited some fracturing in post-test examination. However, with increasing temperature and confining pressure, plots of compressive differential stress versus axial strain tend to level off after an initial transient period of increasing stress. This indicates that (1) we are approaching the brittle-ductile transition, and (2) time-dependent effects may be important under physical conditions comparable to those of this study.

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Feasibility of Natomas process for extraction of bitumen from domestic tar sands

The general conclusion drawn from this feasibility study is that the Natomas proposed project is both technically and economically feasible. No major technical obstacles were encountered in the engineering design phase nor were any major environmental or permitting obstacles identified in the study of permits and socioeconomic issues. Based on the reported literature data and other data supplied by Sohio, there appears to be a sufficient mineable resource base at Asphalt Ridge, Utah, to support a 20,000 B/D extraction plant. A market exists for the product from the plant if sufficient upgrading is performed. The raw bitumen itself is not readily marketable. The nitrogen content of the bitumen and the products derived from bitumen are of concern. Typical conventional crude oils have nitrogen contents in the range of 0.01 to 0.03 wt % while the nitrogen content of the bitumen is close to 1 wt %. Nitrogen content of the distillate products from bitumen ranges from 0.3 to 0.5 wt %. Refiners need special equipment (hydrotreaters) to reduce the nitrogen content to acceptable levels in the products. Hydrotreating is a comparatively costly refinery operation and consumes hydrogen which is expensive. In this feasibility study, the nitrogen question is addressed in several of the tasks including plant design, upgrading process selection, and marketing. The project economics are based on the engineering design of the plant and the capital and operating costs derived from the design. Also, capital and operating costs on the mine operation were developed and included. A market price for the upgraded bitumen was determined and included. While this study was performed based on a site at Asphalt Ridge, Utah, the components of the study are generally applicable to any tar sand site with an adequate, surface mineable resource base.

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Bed preparation concepts for true in situ oil shale processing:  an evaluation of current technology

True in situ methods to process oil shale, which by definition require no mining and depend on wellbores for access to the underground formation, will be successful only if technique are available to transform the normally very tight oil shale seems into rubble beds that are sufficiently porous and permeable and composed of suitably sized fragments to permit effective retorting operations to be conducted. Prior experimental efforts to create such  beds in comparatively deep formations, where significant void cannot be introduced by explosively lifting the overburden, have in nearly all cases employed either the wellbore springing of hydraulic/explosive fracturing concept. Only very limited success has ever been achieved in these efforts, In this paper, reasons for the lack of success are identified. For the wellbore springing concept, the inherent cylindrical geometry is the primary difficulty in that it leads to small fractured zones because of rapid stress pulse attenuation, and also to regions of residual compressive stress around the wellbore, which restrict fluid flow and hinder void redistribution. Major difficulties with the hydraulic/explosive fracturing concepts are that many important operations cannot be controlled and that regions of enhanced permeability are formed only in the immediate vicinity of explosive filled hydro fractures. The future success of true in situ processing depends on the introduction of void prior to the blasting operation and development of explosive in a geometry that will ensure distribution of the void.

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Heat of combustion of Green River oil shale

The authors derive simple equations for estimating the heat of combustion of raw shale by thermochemical estimates and by linear regression of experimental data. They find that the heat can be estimated well by an exothermic term that accounts for the combustion of organic matter and a constant that accounts for pyrite combustion, carbonate decomposition, and glass formation. The net contribution of reactions included in the constant is endothermic for the standard state products of bomb calorimetry. As a sample application, the authors perform an energy balance on a modified Fischer assay of average Green River shale by using one of our formulas for raw shale along with previously derived formulas for pyrolysis products.

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Devonian oil shale of the eastern United States:  a major American energy resource

The eastern Devonian oil shale resource can yield 400 billion (400 X 10/sup 9/) bbl of synthetic oil, if all surface and near-surface shales were strip or deep mined for above-ground hydroretorting. Experimental work, in equipment capable of processing up to 1 ton/h of shale, has confirmed the technical and economic feasibility of aboveground hydroretorting of oil shales. Work done to date on nearly 500 samples from 12 states indicates that the HYTORT Process can give organic carbon recoveries from 2 to 2.5 times those of conventional retorting of the Devonian shales, so that the HYTORT Process yields 25 to 30 gallons per ton on syncrude at many localities, compared with 10 to 15 gallons per ton using Fischer Assay retort methods. Criteria for inclusion of shale in estimates of recoverable resources for the HYTORT Process are: (1) organic carbon of at least 10% by weight; (2) overburden of less than 200 feet (59 meters,10453 ); (3) volumetric stripping ratios of less than 2.5 to 1; and (4) stratigraphic thickness of 10 feet (3 meters) or more. Resource estimates include: Kentucky (Ohio, New Albany, and Sunbury shales), 190 billion (190 X 10/sup 9/) barrels (bbl,10453 ); Ohio (Ohio and Sunbury shales), 140 billion bbl; Tennessee (Chattanooga shale), 44 billion bbl; Indiana (New Albany shale), 40 billion bbl; Michigan (Antrim shale), 5 billion bbl; and Alabama (Chattanooga shale), 4 billion bbl. Recoverable resources have not been identified in West Virginia, Georgia, Oklahoma, Illinois, Arkansas, or Missouri outcrops. Co-production of uranium and metals is a possibility in the areas favorable for syncrude production.

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Economics of shale oil production by radio frequency heating

A conceptual facility for the production of shale oil by radio frequency(rf) heating has been designed to evaluate the economic feasibility of this technique. In the proposed procedure, the shale is processed in situ without being rubbed or explosively fractured. Metal electrodes inserted in a set of vertical drill holes are energized by a group of rf oscillators. The holes bound a block of shale that is to be retorted. The electric field is developed in such a way that heating within the block is almost uniform, and heating outside the block is very low. Retorting of the shale results in a pressure buildup of the hydrocarbon fluids. The oil and gas move horizontally (parallel to bedding planes), then down the electrode holes to a collection manifold. The facility schedule is planned so that off-peak electric power from existing generating stations can be used to operate the oscillators. Thus, the cost of power and the capital requirements for the facility are held to a minimum. Oil production costs and capital requirements indicate that the proposed procedure is economically attractive. The two principal costs are purchase of electric power and mining operations. The largest capital requirement is oscillators and associated electrical equipment.

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Characterization of condensates produced during underground coal gasification

Characterization of the organic and inorganic constituents of water and oil condensate phases produced during an in-situ coal gasification test at Hanna, Wyoming is presented. Over two hundred compounds were identified and quantified. It was found that phenols constituted the major portion of the organic material. Inorganic constituents included high concentrations of alkalinity, ammonia, sulphur species, dissolved solids plus traces of many other constituents. Total quantities of condensed oil and water were determined as a function of gas production, injection air rates, and coal consumption.

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Stress wave propagationin the site 12 hydraulic/explosive fracturing experiment

The Site 12 experiment was a heavily instrumented field event performed to examine the hydraulic/explosive fracturing concept for preparing an underground oil shale bed for true in situ processing. One of the key phases of this fracturing concept is the blasting operation which involves the insertion and detonation of slurry explosive in a pre-formed system of hydrofractures. To obtain a sound understanding of the nature of the blasting operations, a rather extensive array of stress gages, accelerometers, and time-of-arrival gages was installed in the rock mass in the vacinity of the explosive to monitor the dynamic events initiated by the detonation. These gages provided considerable amounts of information which were useful in evaluating overall results of the experiment. Details of the gage array, of the data, of analysis methods, and of the results and conclusions are considered in the report.

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BX in situ oil shale project. Site evaluation report

The Site Evaluation of the BX In Situ Oil Shale Project was conducted to determine if the selected project site was suitable for the conduct of the proposed project. Site evaluation work included the drilling, coring, and logging of two core holes and the analysis of the cores therefrom; temperature logging of existing wells at the project site; and the performance and analysis of pulse tests to evaluate inter-well communication. The site evaluation confirmed that the site would be suitable for the proposed project.

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

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

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Sulfur reactions in oil shale processing

The occurrence and reactions of sulfur are discussed in terms of defining concentrations of sulfur gases expected in various gas streams. Results are summarized from laboratory and pilot retort experiments at Lawrence Livermore National Laboratory. These results should be useful in terms of estimating the amount of corrosion resistance required for different parts of process-plant equipment, and the variability expected in terms of shale source and processing conditions.

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Organic constituents in process water from tar-sand oil recovery

Capillary-column gas-chromatography/mass-spectrometry was performed on acid, base, and neutral fractions of liquid filtrates and particulate-phase methylene chloride extracts of composite samples of raw process water collected from two in situ tar-sand oil recovery experiments. The experiments, conducted by Laramie Energy Technology Center, were the reverse/forward combustion experiment (TS-2C) of 1977 and the steam injection experiment (TS-1S) of 1980. Some 143 extractable/chromatographable organic compounds were tentatively identified in the TS-2C sample, and 95 were identified in the TS-1S sample. The predominant organic groups in the TS-2C process water included cyclic cyclohexonyl compounds, acetophenones of ketones, and alcohols in the neutral fraction; quinolines and isoquinolines, pyridines, phenyl piperidines, and pyrazoles in the base fraction; and phenols, carboxylic acids, and lactones in the acid fraction. Predominant in the TS-1S process water were alkenes or cyclohexanes, cyclic ketones, and toluenes in the neutral fraction; quinolines and isoquinolines, acridines, pyrazoles, pyridines, phenol piperdines, and piperidines in the base fraction; and phenols in the acid fraction.

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