AndreaBozzo/ceres-open-data-index huggingface dataset:
Composition of crude shale oils. [Analysis of 19 oils from 7 countries for N, S, pour point, sp. gr. , and viscosity]

At present there is no commercial oil shale industry in the United States. Therefore, laboratory analysis and comparison of the composition of shale oils furnish information on their characteristics and on processing problems. Nineteen shale oils from seven different countries were analyzed. The shale oils not only differ as a class from petroleum but also show substantial differences in composition among themselves. The composition is influenced by both shale source and retorting conditions. The sulfur and nitrogen contents of the oil are primarily dependent on shale source. Also, when ordinary retorting methods are used, the shale source is a factor in the hydrocarbon composition of the oil. The use of high temperature retorting produces oils of greater aromaticity. Comparison of the results obtained permits characterization of the crude shale oils, evaluation of the factors affecting their composition, and determination of the relationship between American and foreign shale oils.

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Thermal decomposition rates of carbonates in oil shale

"Retorting oil shale involves heating it to a temperature  over 750° F, to convert the organic matter to oil, gas, and  coke, Depending upon the maximum temperature to which the shale is raised and the rate of heating, a portion of the mineral carbonate contained in the shale is decomposed.  Calculations show that complete decomposition of the carbonate in a 30-gallon-per-ton Green River oil shale would require a quantity of heat equivalent to that obtainable by burning approximately  10% of the organic matter in the shale (16). Data on the extent and rate of this decomposition at various temperatures are essential in the design and operation of retorts for producing shale oil most economically and are the subject matter of this paper."

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Seventh underground coal conversion symposium

A three-dimensional numerical study was performed to better elucidate the rather complex flow patterns that can occur during the bed preparation stage of underground coal gasification when the linked vertical well method is applied. This study shows the important effects of the 3-D geometry, gravity, anisotropy, pressure dependent permeability, and dynamic two phase air/water flow. For the first time the dynamic, 3-D  growth of the air bubble is studied under simulated field conditions for western subbituminous coal. Interpretation of the 3-D flow and racer patterns is an important element in an effective site characterization program.

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Perform research in process development for hydroretorting of eastern oil shales

Six bulk samples of eastern oil shale were taken from the Clegg Creek Member of the New Albany Shale in northwestern Kentucky, the Chattanooga Shale in northern Alabama, the Gassaway Member of the Chattanooga Shale in central Tennessee, the Antrim Shale in northeastern Michigan, the Cleveland Member of the Ohio Shale in central Ohio, and the Sunbury Shale in eastern Kentucky. A seventh sample of Clegg Creek from southern Indiana had been sampled earlier. The stratigraphic position of all bulk samples was documented using both outcrops and subsurface control; at five sites stratigraphic test holes were cored and logged. Surface gamma was run on the cores before slabbing. The representative character of the Tennessee sample was assured by recovering the required weight in four cores. Obtaining representative bulk samples at other sites often required adapting channel sampling techniques to earth moving equipment, reducing an initial sample by hand methods, and minimizing contamination throughout the sampling operation. Cores were assayed for carbon and Fischer Assay oil yield both on a selected per foot basis as composites. 29 refs., 25 figs., 7 tabs.

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Tenth annual underground coal gasification symposium: proceedings

The spalling of sidewalls or roofs in underground coal gasification is modeled by assuming that it occurs due to strength reductions caused by heating, drying, or crack formation. The temporal or spatial variations of these effects are determined by the properties which control internal convection, diffusion, and conduction in the coal, liquid, vapor or gas flows. This paper examines the effects of changing these properties to determine the sensitivity of the regression process. It is found that the drying process is primarily sensitive to the coal thermal conductivity, internal diffusion of vapor and the surface heat transfer coefficient while the regression is dominated by the surface heat transfer coefficient and only slightly affected by the surface resistance to vapor flow.

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Use of Zeeman atomic absorption spectroscopy for the measurement of mercury in oil shale gases

Preliminary investigations of pilot-scale oil shale processing plants 1, 2 indicate that the level of mercury in off gasses may be significant. Extrapolation of these results to field conditions suggests that a 100,000 barrel per day oil shale plant processing 100 l/tonne oil shale with an average mercury content of 0.86 ppm 3 may release approximately 32,900 kg of mercury per year to the atmosphere. In contrast, the amount of mercury released from world coal consumption in 1967 is estimated to be 18,900 kg of mercury. 4, 5 These data suggest that mercury emissions from oil shale plants may be of future environmental concern and that they may require control technology to reduce mercury levels. This will require reliable techniques to measure the mercury in these gases.

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High risk groups in oil shale workforce

The workforce risks of a hypothetical one million barrels-per-day oil shale industry were estimated. The risks for the different workforce segments were compared and high risk groups were identified. Accidents and injuries were statistically described by rates for fatalities, for accidents with days lost from work, and for accidents with no days lost from work. Workforce diseases analyzed were cancers, silicosis, puemnoconiosis, chronic bronchitis, chronic airway obstruction, and high frequency hearing loss. A comparison of the workforce group under different risk measures was performed. The miners represented the group with the largest fatality and the most serious accident rate, although the estimated rates were below the average industry-wide underground mining experiments. Lung disease from inhalation exposure of about the nuisance dust threshold limit value presents a significant risk for future concerns. If future environmental dust exposure is at the 100 pg/m3 alpha-quartz level, safety improvements is the mining sector are of prime importance to reduce the oil shale worker's life-los expectancy.

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Perform research in process development for hydroretorting of Eastern oil shales: Volume 2, Expansion of the Moving-Bed Hydroretorting Data Base for Eastern oil shales

An extensive data base was developed for six Eastern oil shales: Alabama Chattanooga, Indiana New Albany, Kentucky Sunbury, Michigan Antrim, Ohio Cleveland, and Tennessee Chattanooga shales. The data base included the hydroretorting characteristics of the six shales, as well as the retorting characteristics in the presence of synthesis gas and ionized gas. Shale gasification was also successfully demonstrated. Shale fines (20%) can produce enough hydrogen for the hydroretorting of the remaining 80% of the shale. The amount of fines tolerable in a moving bed was also determined. 16 refs., 59 figs., 43 tabs.

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Ignition of in situ oil-shale retorts with hot inert gas

For controlled-combustion retorting of oil-shale rubble in situ, preheating with hot, inert gas appears to be a promising method to prepare the rubble for ignition. By thus setting up an initial separation between the combustion and retorting fronts, oil burning should be reduced and temperatures should remain below those at which spent shale fuses. Inert-gas preheating has been investigated by simulation, using the LLL computer model of in situ retorting. The modeling explored the effects of: temperature and flow rate of preheating gas, depth that ignition-range temperatures penetrated before changeover to retorting, temperature at the given depth of changeover, and staged changeover. Several sets of conditions gave retort temperatures below 1000/sup 0/C with low fuel usage. The choices of preheating factors strongly affect the maximum temperatures reached shortly after changeover. The cost of inert-gas startup appears to be small.

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True in-situ oil retort: the role of intrashale transport and char gasification and an analysis of retort performance

This study expands the theoretical understanding of the true in situ crack retort process for Eastern oil shale by (a) establishing the role of intrashale 2-dimensional transport on the performance of the retort, (b) determining the significance of the intrashale char gasification reactions with water and carbon dioxide, and (c) analyzing the performance characteristics of a theoretical true in-situ retort process for Eastern oil shale and establishing conditions for improving the retort performance. Two computer simulation models were developed and evaluated, one with 1-D mass transport and another with 2-D mass transport. The 1-D transport model featured instantaneous 1-D transfer of the pyrolysis products to the crack. The 2-D transport model featured 2-D species transport within the oil shale, and pyrolysis, gasification, and oxidation reactions within the oil shale.

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Sampling strategies in groundwater transport and fate studies for in situ oil shale retorting

This paper proposes a new concept for designing groundwater monitoring programs to assigns the effect of in situ oil shale retorting. The concept includes new ways to characterize pollution source terms, build and calibrate hydrological models, estimate stochastic systems, and optimize measurement system designs. The solution tc the monitoring problem would be the minimum cost program that estimates pollutant concentrations throughout the groundwater region within an acceptable error criterion. That program would specify the lowest number of wells that need to be drilled their best locations and depths, and how seldom they need to be sampled. The approach can be applied to meet differing requirements of characterizing regional hydrology, studying geochemistry, determining pollutant transport and fate, and designing monitoring networks to demonstrate compliance with effluent regulations.

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Working paper on candidate mining sites for surface mining of western oil shales

This report describes the selection of candidate surface mining sites for the development of oil shale resources in the western United States. The purpose of this study is to input the various scenarios into an economic mine model developed for underground oil shale mines in an earlier project. Site selection was a three-phase effort. Phase I consisted of a thorough review of available resource data, which resulted in a definition of surface mineable areas. Phase II was a detailed investigation of the regions identified in the initial phase. The end result of this task was a list of potential sites having favorable overburden, grade, shale thickness, and topography values. Phase III identified those sites from which a wide range of site specific parameters can be obtained for mine design and model testing purposes. This report describes the procedures used to obtain the candidate mining scenarios. Section 2.0 discusses the methodology used to determine candidate mining scenarios. Section 3.0 presents a more detailed review of the western oil shale resources and develops the rationale used in selecting candidate sites. 1 ref., 5 figs., 1 tab.

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Constitution of oil-shale kerogen:  bibliography and notes on Bureau of Mines research. [Data published from 1946 through 1957; bibliography of 237 references]

Oil shale kerogen was processed into oil and oil products before the first oil well was completed by Drake in 1859.  However, because of economic ;and other advantages, natural petroleum has been the principal source of liquid fuels and lubricants since 1859 and is a convenient root of many organic chemicals in common use today.  In recent years the difference has narrowed between the cost of producing liquid fuels from well petroleum and other sources.  This narrowing of cost difference has resulted both from the increased cost of finding new sources of petroleum in the United States and the experimental demonstration of lowered costs for synthetic fuels by the Federal Bureau of Mines and by industry.  Available petroleum resources of this country are being reduced and eventually may be inadequate to meet the demand.  Alternative means of assuring an adequate supply of liquid fuels for this country include the development of processes for utilizing other carbonaceous materials such as oil shale and coal,

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Diesel and burner fuels from hydrocracking in situ shale oil. [At 800/sup 0/F and 1,500 psig over Ni--molybdena catalyst; product distilled and blended]

In-situ crude shale oil, produced by the underground combustion retorting method, was hydrocracked over a nickel--molybdena catalyst at 800/sup 0/F and 1,500 psig. The liquid product was distilled into a low-octane reforming feedstock amounting to 18.5 volume-percent of the in-situ crude plus a large number of small-volume higher boiling fractions and small quantity of waxy residuum. Most of the small-volume distillate fractions were blended into types C-B, T-T, and S-M diesel fuels whose properties resembled those of diesel fuels and distillate fuels now being marketed. The diesel fuels also met the ASTM requirements for diesel fuels and distillate fuel oils with minor exceptions. All of the shale-oil diesel fuels had low sulfur contents and high cetane indexes. The dewaxed distillation residuum was blended with a portion of the small-volume distillate fractions to form a fuel oil fitting the requirements for No. 4 fuel oil except that its viscosity was between the viscosity limits for No. 2 and No. 4 fuels and its pour point of 30/sup 0/F was higher than ASTM recommendations, although in the range of No. 4 fuel oils now being marketed. This fuel oil could also be used as a low-sulfur, high-cetane-index S-M diesel fuel. The yield of diesel fuels was 51.6 volume-percent of the in-situ crude, and the yield of No. 4 fuel oil was 21.5 volume-percent, for a total of 73.1 volume-percent of the in-situ crude that could be used as low-sulfur, high-cetane-index diesel fuels or Nos. 1 through 4 burner fuels. (auth)

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Proposed methods and estimated costs of mining oil shale at Rulison, Colo

This present paper, which was finished in 1936, discusses methods that would be adaptable to mining certain American shales, and the treatment applies specifically to conditions in the Green River formation on Naval Oil Shale Reserve No 1. Estimates of mining costs, which were calculated on wages paid and prices of equipment and supplies in 1931, are based on assumptions that are clearly stated.

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Compositional studies of an asphalt and its molecular distillation fractions by nuclear magnetic resonance and infrared spectrometry

"Molecular distillation of a Wilmington (California) asphalt that was prepared in the laboratory gave fractions whose sulfur, oxygen, nitrogen, and aromatic contents increased with molecular weight. Paraffinic content was nearly constant with molecular weight. The increase in aromatic content with molecular weight was offset by a decrease in the naphthenic content. Although the total oxygen content increased with molecular weight, the acid oxygen decreased. A correlation between the naphthenic content and the acid oxygen was shown. Methylene chloride, as a  solvent, permitted the resolution of the 1700 cm carbonyl band in the asphalt and its fractions into three discrete bands at 1740, 1700, and 1655 cm. Carboxylic acids appear responsible for the 1740 cm  band in the asphalt and its distillation fractions. These acids were found to be associated in the asphalt. A model naphthenic acid, cyclohexanecarboxylic acid, associated with functional groups in the asphalt."

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Origin and composition of certain oil shales. [Chocolate shale of Devonian of Illinois; New Albany black shales of Indiana; Ohio shales; Chattanooga shales]

This paper comprise part of a preliminary report on the microscopial study of oil shales, undertaken in cooperation with oil-shale retorting experiments carried on by the Bureau of Mines at Salt Lake City, Utah and with the State Geological Survey of Kentucky.  A shale is generally defined as a rock formed by the consolidation of clay, mud or silt, having a finely stratified , laminated or fissle structure.  When such a rock contains organic matter it is termed carbonaceous of black shale; when the matter is of a bituminous nature it is called bituminous shale, and when rich in bituminous substances, yielding oil and gas on distillation, it is called oil shale.

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Some observations of retorting phenomena in shale blocks. [Large blocks in oxidizing and nonoxidizing atmospheres]

A small retort (nominal capacity, one-half-ton oil shale) with glass viewing ports was designed and operated to provide additional information on the retorting characteristics of large blocks of oil shale in oxidizing and nonoxidizing atmospheres. Shale blocks selected for retorting ranged in weight from 240 to 680 pounds and represented shale grades of 14 to 36 gallons of oil per ton. In all tests, temperature profiles show a lag in heating rate of the inside of these blocks compared to the heating rate for the shale rubble surrounding them. Analytical data on the vent gases and gas samples taken from inside the blocks are included along with physical observations to expand the technology on retorting large blocks of oil shale.

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Method for refining shale oil

"Methods for refining shale oil produced from oil shale of the Green River formation in Colorado include one proposed by the National Petroleum Council, involving the following steps:  1. Coking the oil to produce a distillate of approximately 700 degrees F end point.  2. Htdrogenating that portion of the coker distillate that boils above 400 degrees F.  3. Reforming a blend of the naphthas produced in the coking and hydrogenating steps.  4. Catalytically cracking that portion of the hydrogenated coker distillate that boils above 400 degrees F, together with the polymer produced in naphtha reforming."

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Distribution of nitrogen compounds in Wilmington, California, petroleum

"Nitrogen compounds in petroleum are known to have  deleterious effects on cracking catalysts in refining  operations (6. 8. 12, 16) and on the stability of petroleum  products (5, 15). Knowledge of the occurrence, types , and properties of nitrogen compounds in petroleum is important in combating these undesirable effects. To procure fundamental data on the structure and properties of these compounds, the American Petroleum Institute Research Project 52 on nitrogen constituents in petroleum was established July 1, 1954. The initial studies of one phase of Project 52 have been concerned with the nitrogen compounds in a crude oil from the Wilmington field in California."

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Design for Project Bronco, an experiment for nuclear fracturing and in situ retorting of oil shale

"The study was prepared cooperatively as part of the  AEC's Plowshare Program by the San Francisco Operations  Office of the U. S. Atomic Energy Commission.  the U. S. Bureau of Mines, the University of California's  Lawrence Radiation Laboratory and the CER Geonuclear  Corporation, the latter acting for approximately a score of oil companies. Part I of the study examines the feasibility of using deeply buried underground nuclear explosions to break oil shale deposits for in situ retorting, and recommends that a nuclear explosion experiment be designed to test the concept. Part II of the study describes Project Bronco, a proposed 50-kiloton nuclear explosion experiment. The detonation will fragment and fracture a deep, thick oil shale deposit which will subsequently be retorted in place. Bronco will provide information related to: the technical and economic feasibility of the basic concept, a predictive capability for the physical effects of nuclear explosions, and the distribution of radioactivity and its behavior during retorting."

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Scale-up comparisons between 10-ton and 150-ton oil-shale batch retorts. [Simulation of forward-combustion, modified in-situ process]

The retorting characteristics of a column of mine-run, ungraded oil shale ranging in size from fines to pieces weighing as much as 5 tons are being investigated. Two retorts nominally sized at 10 and 150 tons were used in this investigation to simulate the forward-combustion, modified in-situ process for retorting oil shale. The results of twelve experiments performed in these two retorts at six duplicate operating conditions are compared to assist in developing scale-up factors for the process.

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Oil production from frozen reservoir rocks, Umiat, Alaska

The Umiat oil field is in Naval Petroleum Reserve No. 4 between the Brooks Range and Arctic Ocean in far northern Alaska.  The Umiat anticline has been tested by 11 wells, six of which produced oil: however, the productive capacity and recoverable reserves of the field are subjects to considerable speculation because of unusual reservoir conditions and because several wells appear to have seriously damaged during drilling and completion. Oil is produced at depths of 273 to 1,100 feet: the depth to the bottom of the permanently frozen zone varies form about 800 to 1,100 feet, so that most of the oil reserves are in the permafrost.  Reservoir pressures are estimated to range from 50 to 350 psi, increasing with depth and the small amount of gas dissolved in the oil is the major source of energy for production.  Laboratory tests were made on cores under simulated permafrost conditions to estimate oil recoverable by solution gas expansion from low saturation pressures.  The cores were also tested for clay content and susceptibility to productivity impairment by swelling clays and increased water content if exposed to fresh water.  The results indicate that oil can be produced from reservoir rocks in the permafrost and that substantial amounts of oil can be produced from depletion-drive reservoirs by a pressure drop of as little as 100psi below the saturation pressure.  Freezing of formation water reduces oil productivity much more than that due to increased oil viscosity.  Failure of wells drilled with water-base mud to produce is attributed to freezing of water in the area immediately surrounding the wellbore.  Swelling clays apparently contributed very little to the plugging of the wells.

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Bureau of Mines experimental oil-shale plant; construction and operation, 1925--1927. [Selection and development of plant site, mining methods and equipment, operation of NTU and Pumpherston retorts, refining studies]

This report describes the construction of the Bureau of Mines experimental oil shale plant at Rulison, Colorado, during 1925 and 1926; its operation from the time the first shale was retorted on September 17, 1926, until July 1, 1927; and the results obtained to August 1928, from refinery studies of the oil produced. The appropriation provided by Congress for the construction of the plant became available March 4, 1925.

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How much nitrogen in crudes from your area

Very little crude of negligible nitrogen content is being produced in the U.S., according to the first comprehensive survey of nitrogen bearing crude oils.  The survey shows that while nitrogen problems are most acute in California, they are also a factor in processing the petroleum production in most states.  Little factual information has been available previously to indicate the extent of the nitrogen problem.  Nitrogen compounds in crude petroleum have become a problem to refiners with the advent of catalytic processing and will increase as more crude oil is subjected to catalytic processing.

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