AndreaBozzo/ceres-open-data-index huggingface dataset:
Concentration-dependence of the effect of an in situ oil shale retort-produced water on metabolism

During the conduction of the Rock Springs Site 9 experiment a large volume of retort water was collected to support environmental research studies. This sample was designated Omega-9 retort water. The Omega-9 water has the following characteristics: pH 8.6, 1003 mg/1 total organic carbon, and 30,300 mg/1 of total dissolved solids which are principally bicarbonate, sodium, ammonium, thiosulfate, sulfate, chloride, and carbonate. Although the Omega-9 water cannot be ascribed as typical of in situ oil shale retort waters in general, its availability has supported numerous investigations into the treatment, disposal, use, and effects of such water. It is reported that consumption of undiluted Omega-9 water by 60 to 80 g Holtzman rats led to an increased rate of metabolism of hexobarbital in vivo and in vitro, an increased rate of metabolism of ethylmorphine in vitro, and an increased level of cytochrome P-450 activity. These observations indicated that Omega-9 water induced liver enzymes activity. The purpose of this study was to determine if the induction effect is concentration related.

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Mineralogy of Antrim Shale, Michigan

Semi-quantitative x-ray mineralogical determinations were made for 12 surface, 104 core, and 707 samples from oil well cuttings distributed throughout the Michigan Basin. In addition, 15 samples that had undergone retorting were checked for mineralogical changes. Gold, uranium, thorium, and rare-earth abundances were obtained for 22 samples from drill core at the Dow Chemical Company drill site in Sanilac County, Michigan. Typical Antrim Shale is composed of 50 to 60% quartz, 20 to 35% illite, 5 to 10% kaolinite, 0 to 5% chlorite, and 0 to 5% pyrite. Bedford Shale, which overlies the Antrim in eastern Michigan, has higher contents of total clays, illite, and kaolinite, and lower quartz contents. Ellsworth Shale, which grades laterally into Antrim in western Michigan, contains significant dolomite. Antrim Shale from the southern and eastern margins of the Michigan Basin contains as much as 15% kaolinite, while samples from the northern, central and western portions contain up to 5% chlorite. Illite and quartz contents tend to be highest in the deepest part of the basin, where the Antrim is thickest. Uranium content increases upward to about 40 ppM and is greatest within shales of the Antrim. Limestone interbeds contain up to about 9 ppM uranium. Highest uranium contents are found just beneath the limestone interbeds and just beneath Bedford Shale. Thorium contents, on the other hand, tend to be uniformly 10 to 12 ppM in Antrim Shale and up to 4 ppM in limestone interbeds. Gold contents range up to about 0.05 ppM in Antrim Shale and 0.01 to 0.02 ppM in limestone interbeds. Rare-earth abundances in Antrim Shale are lower than average North American shales. In the case of most rare earth elements, the overlying Bedford Shale has higher contents of most rare-earth elements.

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Shallow oil shale resources of the southern Uinta Basin, Utah

The shallow Green River Formation oil shales in the southern part of Utah's Uinta Basin are potentially developable by strip mining or by subsurface techniques which take advantage of limited overburden. The resource of potential shale oil represented by the shallow deposits is evaluated in detail from corehole oil-yield data. Cross-sections are constructed to readily correlatable stratigraphic units selected to represent resources in the shallow shale. To define each unit, the thickness, average oil yield, and oil resource of each unit in each core are calculated. Contour maps constructed from these data define the resource variation across the shallow resource. By measuring areas enclosed in each resource unit within the defined limit of 200 feet (61 meters) of overburden, the resource represented by the shallow oil shale is evaluated. The total resource is measured as 4.9 billion barrels (779.1 billion liters) of potential shale oil at depths less than 200 feet (61 meters). The rich zone incorporates the Mahogany bed, the best shallow oil-shale unit. This section, currently being exploited by Geokinetics, Inc., for in situ production of shale oil by horizontal combustion, represents 2.2 billion barrels (349.8 billion liters) of potential shale oil in place.

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Anaerobic fermentation of simulated in-situ oil shale retort water

The feasibility of removing soluble organics from oil shale retort water by anaerobic digestion with methane production was experimentally investigated. The following conclusions were made. The retort water studied had to be pretreated to remove toxic and add deficient constituents before it could be successfully treated with the anaerobic fermentation process. Pretreatment included pH adjustment to 7, ammonia reduction, and nutrient addition. A digested sludge from a conventional municipal sewage treatment plant was successfully acclimated to the retort water studied. A major fraction of the organics in the retort water studied was stabilized by conversion to CH/sub 4/ and CO/sub 2/ using the anaerobic fermentation process. BOD/sub 5/ and COD removal efficiences were 76 to 80 percent. The effluent from anaerobic fermentation of the retort water studied (BOD/sub 5/ : 530 to 580 mg/l) may be suitable for treatment by conventional aerobic processes. The growth of the methane formers, which stabilize the organics, is nutrient limited in the retort water studied. The pretreatment of the retort water studied removed 49 percent of the BOD/sub 5/. This was probably due to the reduction in solubility of high molecular weight fatty acids at neutral pHs. A major component removed from the retort water studied during anaerobic fermentation was fatty acids. The long hydraulic residence time used in this study would not be used in practice.

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Oil shale retorting:  Part 2, variation in product oil chemistry during retorting of an oil shale block

This report discusses the variation in composition of oil as it is evolved during the pyrolysis of oil shale. Thirteen shale oil fractions collected during pyrolysis of an 18- x 18-cm cylindrical shale block have been analyzed by measurements of density, viscosity, elemental composition, simulated distillation, GLC, /sup 1/H and /sup 13/C NMR, and infrared spectroscopy. The results show a striking change in the composition of oil collected early during retorting, as compared with that collected during the middle or latter part of retorting. In particular, the early oil fractions contain a predominance of naturally occurring isoprenoid compounds, whereas later fractions contain larger amounts of paraffin compounds. Less dramatic changes include variations in the amounts of olefins, aromatics, and degree of aromatic substitution, changes in amount of nitrogen-containing compounds, and variations in density and viscosity. The results of these analyses are used to form a picture of the changes in shale oil composition during retorting in the hope that a clearer understanding of the system's chemistry may eventually provide a way to optimize the shale oil retorting process.

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Application of solvent hydrogen donor process for the conversion of Eastern oil shales. Final progress report, October 1982-December 1984

The overall objective of this project was to develop an understanding of the fundamentals of a solvent hydrogen donor process to convert kerogen in Eastern US shales to useful products. The goals were to determine the effect of donor content on conversion, changes in kerogen and products with conversion conditions, and the fate of the donor solvent including material balances with losses through isomerization, adduction reaction, and physical retention in the rock matrix. In particular, the project was divided into: (1) characterizing the kerogen of two samples of Eastern US shale, (2) hydrogen donor conversion of these shales using model solvents of varying donor content, and (3) characterizing the unreacted kerogen and liquid products. Progress reports are presented for these tasks. 26 refs., 51 figs., 34 tabs.

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Theoretical and experimental investigations of underground coal gasification. Final technical report

Contents of this report include work performed at the University of Wyoming and the University of Colorado. For the University of Wyoming these are: (1) statistical correlations; (2) Hanna core data analysis; and (3) reverse combustion in Balsa Wood. The University of Colorado conducted: (1) reverse combustion studies; (2) water-influx modeling studies and applications; and (3) laboratory core characterization studies.

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Polyaromatic hydrocarbons in high-boiling petroleum distillates

The identification of seven polyaromatic ring systems in petroleum is reported. The ring systems are 1.12,2.3-dibenzoperylene; 1,12-o-phenyleneperylene, pyreno(1.3:10'.2')pyrene; 2.3,10.11-dibenzoperylene; 1,2,4,5-dibenzopyrene, benzo(e)pyrene, and benzo(g)chrysene. These polyaromatic hydrocarbons were isolated by a separation scheme involving ion exchange chromatography, gel permeation chromatography, and thin-layer chromatography and were identified by fluorescence spectroscopy. Gel permeation chromatography separated pericondensed aromatic ring systems from catacondensed ring systems and the other components of an acid concentrate.

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Development of technology for in situ oil shale processes. [Operation of 10-ton retort, 150-ton retort, small high-pressure batch retort, and simulated-overburden retort; development of mathematical retorting model]

Laboratory and pilot plant research is being conducted by the Bureau of Mines at the Laramie Energy Research Center to support the development of in situ retorting processes for treating oil shale. Results of this research indicate that fairly wide ranges of gas velocity and oxygen concentration may be used to produce an optimum oil yield. Retorting advance rate increases with increasing oxygen flux, but maximum oil yield does not occur at the maximum advance rate. Oils produced by in situ retorting of oil shale will have lower pour points, higher API gravities, and a higher percentage of lower boiling distillate fractions than will oils produced by many aboveground retorting processes. Total system gas pressure has an effect on oil yield, and overburden pressure decreases the permeability of a bed of broken oil shale during retorting.

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Nitric oxide (NO) reduction by retorted oil shale

Nitric oxide gas (NO) is effectively reduced by retorted oil shale. At 300/sup 0/C half of the NO in a gas stream is removed when the gas stream contacts a bed of crushed retorted oil shale for 0.4 s. The fraction removed in 0.4 s reaches 90% at a temperature of 375/sup 0/C. As long as the reducing agent, presumed to be char in the retorted shale, is not depleted, the rate of reduction of NO appears to be proportional to the partial pressure of NO, and our results can be expressed in terms of a rate constant (k) which is a function of temperature (T, Kelvin) as follows: k = Ae/sup -//sup E/RT/ (s/sup -1/), where A = 4.0 x 10/sup 5/ (s/sup -1/) and E = 59.7 kJ/mole. This rate is many times faster than the rate of reduction of NO by coal char as measured by Furusawa et al. (1983). The principal reduction reaction is unknown; it does not release CO/sub 2/.

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Study of gas evolution during oil shale pyrolysis by TQMS (triple quadrupole mass spectrometer)

Real-time gas evolution during pyrolysis of two Green River Formation (Colorado) oil shales, one eastern US Devonian shale, and two Chinese shales was monitored using a triple quadrupole mass spectrometer (TQMS). We calculated kinetic parameters for hydrocarbon generation. For water, carbon oxides, and sulfur gases, we compared evolution profiles and identified the organicinorganic precursors of each species. We also monitored nitrogen- and sulfur-containing naphtha components. Hydrocarbon gas profiles, except for CH/sub 4/, are similar for all shales, and their rates of evolution reach a maximum at around the temperatures of maximum oil evolutions. The evolution profiles for H/sub 2/, CH/sub 2/, CO, and CO/sub 2/, at high temperatures are affected by the amount of char remaining in shale, carbonate minerals, and the water-gas shift reaction. The water profile, in general, consists of waters from surface dehydration, kerogen pyrolysis, and mineral dehydration. Mineral dehydration was the dominant water source for all shales, but the temperature ranges for the major water peak varied because of widely different mineral composition. Chinese shales evolved much more water than U.S. shales. Major differences between shales were seen in the sulfur gases. 17 refs., 4 figs., 3 tabs.

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/sup 13/C NMR studies of oil shale evaluation and processing

The solid state NMR techniques of cross polarization with magic angle spinning have been employed to characterize the organic carbon distribution in raw, partially and fully retorted oil shales. A high degree of correlation was obtained between the fraction of aliphatic carbon in an oil shale and the genetic potential of oil shales from various worldwide deposits. The correlation was found to be independent of geologic factors such as geologic age or environment of deposition of the oil shales. NMR measurements of a Colorado oil shale heated to various retorting temperatures for a fixed time period show a depletion of the aliphatic carbon fraction relative to the aromatic carbon fraction. This depletion becomes more pronounced with increasing temperature. NMR measurements of the carbon distribution of several different types of oil shales show that residual carbon in retorted oil shales is almost exclusively aromatic. 39 refs.

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Development of the IIT research institute RF heating process for in situ oil shale/tar sand fuel extraction - an overview

The history and current status of development of IITRI's RF process for in situ oil shale/tar sand fuel extraction is described. A brief description of the salient features of IITRI's RF process is given, together with a review of past laboratory development activites. Activities within IITRI's current cooperative development program, jointly funded by government and industry, are also described, including oil shale fields tests, tar sand field tests, and supporting laboratory and analytical studies. 9 refs.

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Lithologic examination of cores and well cuttings from the Antrim Shale

Cores from three wells and a portion of the core of a fourth well drilled in Sanilac County, Michigan were subjected to lithologic examination. These cores began in the Bedford shale and extended through the Antrim shale into the Traverse Formation. The predominant minerals were illite, chlorite, dolomite and quartz. Numerous fossils were observed.

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Development of a reservoir simulator for thermal recovery of heavy oils/tar sands in the presence of gas hydrates: Annual report

This report provides the summary of work performed under the US Department of Energy, Grant numberDE-FG21-86LC11075, during the past year. The report contains detailed equations, numerical solution approach for the three models, namely: fundamental hydrate dissociation model, model for layered hydrate-oil configuration, and model for distributed hydrate-oil configuration. The results of the fundamental hydrate dissociation model are provided and discussed. The other two models have been formulated and computer coded. The results of these two models will be provided in the final report.

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Vapor-phase hydrogenation of oils derived from coal and oil shale. [Gasoline from middle oil from hydrogenation of bituminous coal using German Mo--Zn--Cr catalyst; Co molybdate especially effective catalyst for S removal]

"The Bureau of Mines studied single-step catalytic vapor-phase hydrogenation of oils derived from coal and oil shale. Treatment of middle oil, from hydrogenation of bituminous coal, gave good yields of gasoline with a German-made molybdenum-zinc-chromium catalyst. The  Bureau also achieved good results with duplicates of this catalyst made from domestic raw materials. In one set of experiments with the German catalyst, 38 to 52 wt pct of feed was converted to gasoline. The total liquid product  was 91 to 98 wt pct of the feed. Not all this gasoline can be claimed as production, however, because about 20 pct of the feed was in the gasoline range, and part of it undoubtedly survived the hydrocracking treatment.  Hydrogenation of crude shale oil in the presence of cobalt molybdate catalyst produced a total liquid product of 89 wt pct of feed. The hydrogenation converted 27 wt pct of feed to gasoline and 44 wt pct of feed to diesel fuel . The remaining liquid product, 18 wt pct of feed, was residue boiling above diesel fuel. The gasoline was of poor quality, with an octane number of 39.1. The overall product seemed a suitable feed stock for a conventional  refining operation. Coker distillate hydrogenation, using a cobalt molybdate catalyst, gave a total liquid product of 97 vol. pct of feed; of this product 60 vol. pct was  jet fuel and 40 vol. pct was diesel fuel. High nitrogen and sulfur in all three of these raw materials severely poison the usual refining catalysts. Thus, the common objective in these studies was application of poison-resistant catalysts to the problem of reducing nitrogen and sulfur to tolerable levels. Cobalt molybdate was a particularly  effective catalyst for sulfur removal."

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New concept for in situ coal gasification. [Coal shattered with conventional explosives, then retorted with O--H/sub 2/O mixture at 700 to 0300/sup 0/K; reactants pumped into deposit at 500 to 1000 psi and carbon dioxide and methane removed from bottom]

A method is described by which deeply buried coals can be converted to methane through chemical reactions with oxygen and water.  The coal would first be shattered with conventional explosives, then retorted with an oxygen--water mixture at between 700 and 1300 K.  The reactants would be pumped into the top of the coal deposit at between 500 and 1000 psi and carbon dioxide and methane would be removed from the bottom. No sulfur gases of fly ash should be produced and the water requirements can be fulfilled from brackish water supplies.  Coals available and suitable for this kind of gasification might yield as much as 10,000 trillion ft 3 of pipeline gas.  This constitutes about 300 times the present annual consumption, and if the process is successfully developed, it could materially alleviate future gas shortages. Rough estimates of process costs based on plant capacity of 0.1 trillion ft3 per year indicate that an investor could expect about 15% internal rate of return on a 42 million capital outlay assuming 38 cents per MVF of gas as a field price. Both the capital requirements and selling priced are much less than for surface gasification plants.  Previous underground gasification has been accomplished with mined gallery or drill hole low pressure burning.  The methods proposed here should minimize bypassing of the coal by the inlet gases and thereby maintain a high quality product. This is accomplished by flowing the reactant gases very slowly downward through the shattered coal, keeping the hot zones above the colder ones.  This creates  a thermally stable advancing hot zone and avoids the mixing of reactants and products.  The proposed process will lead to ultimate surface subsidence of many tens of feet over the whole area of racted coal.  Experience from potash mines suggests that there would be no surface disruption.  While the concept appears most promising from a theoretical point of view, it is unproven. To test its feasibility it will be necessary to conduct a number of laboratory studies and calculations and to perform pilot scale field tests in suitable deep coal deposits.

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Synthetic liquid fuels. Annual report of the Secretary of the Interior for 1949

The reports on synthetic liquid fuels for 1949 deal primarily with progress in utilizing coal and oil shale as raw materials. It should be noted, however, that the program embraces very important work on the conversion of agricultural wastes into liquid fuels, together with significant research on secondary recovery from stripper oil fields and on refining processes. Notable processes has been made in each of these programs, and the results are sketched in he latter part of this summary.

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Slagging fixed-bed gasification of North Dakota lignite at pressures to 400 psig. [Pilot plant for production of coal gas]

"This is the final report on a research program to develop a pilot plant gasifier for slagging gasification of lignite at high pressures and to obtain process data under various operating conditions. An operable pilot plant was developed, and the test results show that lignite is well suited for the process. Tests were run at pressures from 80 to 400 psig, and the results indicated that pressure had little effect on gas composition or the material  requirements per unit of gas produced. Gas production rates as high as 26,000 scfh/sq ft of reactor area were obtained at 300 psig, but limitations on auxiliary  equipment prevented full-capacity operation at 400 psig . In several tests lignite having a 37-percent moisture content and 2,500° F ash-fusion temperature was successfully gasified. Refractory materials were found to  have a short life in contact with high-temperature slag , and a water-cooled taphole was developed. Exploratory tests with coking coal were unsuccessful ."

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Compositional variations of organic material from Green River oil shale. Wyoming No. 1 core

Oil shale samples selected from a core of the Green River Basin (Wyoming) were studied to ascertain differences in the composition and/or chemical structure of the organic material in the samples relative to stratigraphic position within the Green River Formation.  This involved a systematic study of the soluble organic materials and the insoluble kerogen present in the samples.  Emphasis was placed upon the distribution of the alkanes (normal and isoprenoid compounds) in the soluble extract and upon the aromaticity of the kerogen.  In general, it was concluded that significant differences exist in the chemical structure of the oil-shale organic material from various strata within the Green River Formation of Wyoming.  Most of the compositional and structural changes were not related to burial depth but were related to source material variations, environmental differences or other factors.

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