AndreaBozzo/ceres-open-data-index huggingface dataset:
Methods for refining crude shale oil produced by in situ retorting. [Three methods involving 1) fractionation prior to catalyzed hydrogenations of residuum and naphthas, then reformation and cracking; 2) initial hydrogenation of total in-situ crude oil over Ni--W catalyst prior to further treatment; and 3) hydrostabilization over cobalt molybdate catalyst prior to further treatment]

Crude shale oil produced during in situ retorting by the Bureau of Mines at Rock Springs, Wyoming, was refined by three schemes. In the first, the crude oil was fractionated to raw naphtha and 400 degrees F  residuum. The residuum was hydrogenated over cobalt molybdate catalyst at 815 degrees F and 1100 psig. The blended raw and 160-400 degrees F hydrogenated naphthas were hydrodenitrified and then catalytically reformed. The 400 degrees F  hydrogenated oil was catalytically cracked. In the second scheme, the crude was hydrogenated over nickel-tungsten catalyst at 800 degrees F and 1500 psig. The hydrogenated fractions were processed by methods used in the first scheme. The third scheme resembled the second but, prior to hydrogenation, the crude was "hydrostabilized" over cobalt molybdate at 500 degrees F and 500 psig. Yields of reformate and cat-cracked gasoline as volume-percents of the crude, and research-method octane numbers for the three methods were as follows: First method, 32 pct reformate, 90 octane; 19.5 pct cracked gasoline, 99.2 octane. Second method, 29 pct reformate, 81.1 octane; 21.3 pct cracked gasoline, 99.6 octane. Third method, 28.2 pct reformate, 86 octane; 28.7 pct cracked gasoline, 95.9 octane.

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Rapid method for estimating oil yields of oil shales by broad-line NMR spectrometry. [Comparison of organic carbon (combustion), Fischer assay, and NMR methods]

The Bureau of Mines, US Department of the Interior, has been involved for many years in research work on oil shales. One phase of the work is a study of the characteristics, composition, and properties of Green River Formation oil shales in Colorado, Wyoming, and Utah. Of particular interest to a future oil shale industry is the determination of the quantity of organic matter and of recoverable shale oil that is represented in these deposits.

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Oil shale project. Quarterly report, April-June 1980

In this quarterly report, pilot retorting operations, field testing of retort operation and control, retort modelling and laboratory studies are covered in detail. Under the pilot retorting operations, preliminary results from small retort run S-20 which cover descriptions of the retort vessel and bed load, results of pre-run steam logging and summary of retort operations are included. Also, there is a discussion on the critical effect shale grade has on yield. Laboratory studies of oil shale cover carbonate decomposition and char gasification, oil composition and hydrogen sulfide evolution. The final section deals with the Discrete Interacting Block System (DIBS) computer model and verification experiment. The model is being developed as a tool to aid in determining optimum methods of creating uniformly distributed porosity in modified in-situ retorts.

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Lysimeter study on the disposal of Paraho retorted oil shale. Final report, July 1975-July 1978

This study used lysimeters to develop both a low-elevation (dry site) and a high-elevation (moist site) disposal scheme for Paraho (direct-heated) retorted shale. The objectives were to investigate: (1) vegetative stabilization of the surface of Paraho retorted shale and retorted shale covered with various soil depths; and (2) water and salt movement through both uncompacted and compacted Paraho retorted shale. The lysimeters were constructed in western Colorado in 1976 and filled in March 1977. Only a sparse vegetation cover (5% to 15) was established on retorted shale following fertilization, mulching, and irrigation. In contrast, adequate plant cover (55% to 85%) was established on the soil cover over retorted shale and on soil control treatment areas. Water balance calculations and drainage below the compacted zone indicated that water had moved into and through the compacted zone in the leached treatment areas. Further study is needed on the permeability of the compacted shale.

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Current appraisal of underground coal gasification

The Bureau of Mines in the Department of the Interior is increasingly concerned with the safety and health of personnel engaged in coal-mining operations, particularly below ground. The Bureau is also concerned with improving the utilization of domestic mineral resources, and reducing the environmental impact of mineral operations. One obvious way to improve safety and minimize health hazards would be to eliminate coal mining entirely by bringing the energy value of the coal to the surface in some other way, such as by partially burning it underground to form combustible gases and bringing these gases to the surface, where their energy content can be put to use. This technique might also improve the utilization of the coal resource.

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Proceedings of the ninth annual gasification and gas stream cleanup systems contractors review meeting

Research projects in each of these three categories are necessary for METC to meet its objective, which is to develop engineered systems that can take coal and convert it into a useful end product, reliably, economically, and cleanly. The advantage of this systems focus is that it places logical constraints on the R&D program. For example, research on the mechanism by which sortents capture sulfur is of interest, but only for sorbents that are economic enough to be viable candidates for a real fossil energy system.

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Postburn evaluation for Hanna II, Phases 2 and 3, underground coal gasification experiments, Hanna, Wyoming

A number of underground coal gasification experiments were conducted at the Hanna, Wyoming, United States Department of Energy, site from 1973 to 1979. The individual experimental sites are referred to as Hanna I, Hanna II,  Hanna III, and Hanna IV. All research was conducted under the direction of the Laramie Energy Technology Center with the intent of transferring the data and knowledge to the public domain for ultimate process commercialization by private industry. The UCG process has the potential to increase the utilization of coal reserves too deep and/or too thin to mine economically by conventional mining methods.

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Fire and explosion hazards of oil shale

The US Bureau of Mines publication presents the results of investigations into the fire and explosion hazards of oil shale rocks and dust. Three areas have been examined: the explosibility and ignitability of oil shale dust clouds, the fire hazards of oil shale dust layers on hot surfaces, and the ignitability and extinguishment of oil shale rubble piles. 10 refs., 54 figs., 29 tabs.

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Cost analysis of the carbon monoxide steam process

The Laramie Energy Technology Center has been investigating the use of a high-pressure carbon monoxide (CO) steam process to enhance the yield of oil from oil shale. Initially, the process showed much promise. One published laboratory run using this technique gave a product-recovery yield of 120% Fischer Assay. Unfortunately, the laboratory conditions for producing these high yields are quite different from those that would be required in a similar commercial process. Many assumptions had to be made to simulate the commercial process for cost analysis. Even though the process has an extremely high carbon recovery, it produces a relatively expensive product oil. The main reason for the high oil cost is the high-pressure retorting section, which uses high-pressure retorts and high-pressure feed and discharge systems. Another reason for the high cost is that not enough gas is produced in the retort to be reformed to produce make-up CO. The gas produced has a low heating value and must be upgraded significantly before it can be burned.

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Wet scrubbing for control of particular emissions from oil shale retorting

A mobile pilot-scale venturi scrubber was tested for control of particulate emissions from the Laramie Energy Techonolgy Center's 136-mg (150-ton)-capacity oil shale retort. The entire retort off-gas flow of 15.4 m/sup 3//min (545 ft/sup 3//min), discharged from a heat exchanger at a temperature of 58 /degree/C and saturated with water, was scrubbed at liquid-to-gas ratios of l.5 to 2.4 L/m/sup 3/. Sampling and analysis of the scrubber inlet and outlet gases were conducted to determine particulate removal. Outlet particulate concentrations were consistently reduced to 35 mg/m/sup 3/, even through inlet loadings varied from 125 to 387 mg/m/sup 3/ and 50 weight percent of the particles were less than four micrometers in diameter. Particulate control efficiencies up to 94 percent were achieved, although no correlation to liquid-to-gas ratio was observed. Simultaneous control of ammonia emissions, at efficiencies up to 75 percent, was also observed. 5 refs.

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High-temperature shale-oil production and utilization. [At 1200 to 1800/sup 0/F]

Crude shale oil is obtained by retorting the solid organic material occuring in oil shale. The purpose of the present investigation was to determine the composition of oils produced by retorting at temperatures substantially higher than those normalls employed. Detailed analysis of the products presented a complex problem, as shale oils usually contain saturated, olefinic, and aromatic hydrocarbons, plus significant amounts of nitrogen-, sulfur-, and oxygen-containing compounds. Therefore, simple physical property correlations do not give satisfactory results. To obtain an adequate picture of the composition of shale oil distillates, a number of techniques including fractional distillation, adsorption, and spectrometry are used.

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Mechanical design in oil-shale retorting plants. [Emphasis on gas combustion process]

For retorting of oil shale, the primary elements are handling of large quantities of crushed shale, in a satisfactory manner for good heat exchange, through a suitable retorting vessel; generation of the necessary heat at the temperatures required for retorting; controlled exchange of heat to the shale in the amount required for retorting; passage of a carrier fluid through the retorting shale to pick up the retorted oil; and further passage of this carrier fluid with the retorted oil through suitable equipment to seperate and recover the oil from the fluid stream. Of the processes tested experimentally by the Bureau of Mines at Rifle, Colorado, the gas combustion process is most efficient and most economical in operation. No water is required. The simplicity of the design, the gravity flow of shale through the retort, the heat exchange zones to keep all practicable heat within the retort, and the few simple mechanical devices make this retort both low in construction cost and most economical in operation.

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Recovery of waxes from shale oil

The occurence of waxy material in oil produced by pyrolitic decomposition of the organic material contained in oil shale is, of course, well known. Up to the present time, however, there has been relatively little investifation of these shale oil waxes, particularly in this country, and it has long been considered that these waxes, particularly those of higher melting point, are, like petroleum waxes, substantially paraffinic character. Thus, it has been considered that the same methods employed for the recovery and purification of petroleum waxes, such as sweating or solvent extraction followed by acid treatment, would be equally applicable for separation and recovery of shale oil waxes.

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High resolution seismic survey (of the) Rawlins, Wyoming underground coal gasification area. Final report

In October 1982 a high resolution seismic survey was conducted at the Gulf Research and Development Company's underground coal gasification test site near Rawlins, Wyoming. The objectives of the survey were to utilize high resolution seismic technology to locate and characterize two underground coal burn zones. Seismic data acquisition and processing parameters were specifically designed to emphasize reflections at the shallow depths of interest. A three-dimensional grid of data was obtained over the Rawlins burn zones. Processing included time varying filters, trace composition, and two-dimensional grid of data with obtained over the Rawlins burn zones. Processing included time varying filters, trace composition, and two-dimensional areal stacking of the data in order to identify burn zone anomalies. An anomaly was discernable resulting from the rubble-collapse cavity associated with the burn zone which was studied in detail at the Rawlins 1 and 2 test sites.

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High resolution seismic survey of the Hanna, Wyoming underground coal gasification area

In November 1980 a high resolution seismic survey was conducted at the Department of Energy, Laramie Energy Technology Center's underground coal gasification test site near Hanna, Wyoming. The objectives of the survey were to determine the feasibility of utilizing high resolution seismic technology to locate and characterize underground coal burn zones and to identify shallow geologic faults at the test site. Seismic data acquisition and processing parameters were specifically designed to emphasize reflections at the shallow, 61-91 meter depths of interest. A three-dimensional grid of data was obtained over the Hanna II, Phases 2 and 3 burn zone. Processing included time varying filters, deconvolution, trace composition, and two dimensional, areal stacking of the data in order to identify burn zone anomalies.

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Depositional environments, subsurface stratigraphy, and post-burn characterization of the Paleocene-Eocene Hanna Formation at the Hanna, Wyoming underground coal-gasification site:  Hanna II Phase 1 experiment. [Hanna II; post mortem examination]

During the summer of 1981, the Laramie Energy Technology Center conducted a post-burn coring program at the Hanna II, Phase 1 burn site in the Hanna Basin, Wyoming, underground coal gasification area. This drilling program produced 10 cores through areas underlain by or directly adjacent to the gasification zone. The cores were provided to the Department of Geology and Geophysics at the University of Wyoming for geologic analysis under Department of Energy Contract No. DE-AS20-81LC10695.

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Depositional environments, subsurface stratigraphy, and post-burn characterization of the Paleocene-Eocene Hanna formation at the Hanna, Wyo UCG site:  Hanna III experiment. [Hanna III post mortem]

During the summer of 1981 the Laramie Energy Technology Center conducted a post-burn coring program at the Hanna III Underground Coal Gasification site, Hanna, Wyoming. Detailed geologic studies were conducted on the altered and unaltered overburden as well as an analysis of the burn cavity. The overburden consists of about 46m of Paleocene Eocene Hanna formation above the Hanna No. 1 coal seam used in the burn the overburden contains two basic lithologic units: Unit A consists of very fine grained sandstones, siltstones, and claystones deposited as a lacustrine delta. Unit A is immediately above the Hanna no. 1 coal. Unit B is above Unit A and consists of carbonaceous shale's and mudstones containing isolated ventricular and tabular sandstone bodies deposited in a meandering fluvial system. The Hanna no. 1 coal accumulated in a poorly drained swamp that was subject to clastic flooding from an adjacent fluvial system.

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Oil-shale research and process development. [Description of Laramie station buildings, equipmnt, and research]

This research was undertaken by the Bureau of Mines to procure the chemical, physical and engineering data necessary for extracting oil from oil shale and refining shale oil into products meeting commercial specifications.  The data are essential for the development of appropriate processes and for the design, construction and operation of commercial plants.  Under this research program, basic information is being developed on the composition and characteristics of Colorado oil shale and its shale oil.  Engineering and process data are also being made available for converting these materials into acceptable motor fuels and useful by-products.  These results are the basis for the future development of a new industry for preparing liquid fuels and allied products from an extensive but hitherto fore unused natural resource-oil shale. This industry will aid the national economy by increasing the reserve of petroleum like materials.  Shale oil, however, differs considerably from petroleum and different refining techniques must be devised and utilized to process shale oil into acceptable products.

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Oil from shale. [Survey article]

Although at the present time there is no commercial production of shale oil in the United States, considerable effort has been directed toward the development of an oil shale retorting process adapted to the type of oil shale, as well as to the economic conditions prevailing. Shale oil can be produced by simple pyrolysis, but the scale of production necessary, the relatively small yield of oil, and the location of the principal deposits in an area of limited water supply present sizable engineering problems. These conditions dictate that the successful Americal oil shale process has high unit capacity, efficient energy utilization, and uses little or no water. This paper traces the development work which las led to the construction and operation of such an engineering plant.

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Thermal solution and hydrogenation of Green River oil shale. Experimental investigations and bibliography. [Use of batch-type autoclaves under high partial pressures of H at 850/sup 0/F]

Study of the thermal-solution process was begun by treating crushed oil shale in a small autoclave at temperatures of 700 to 950 F.  The effect of temperature, reaction time, type of solvent, and richness of shale upon the amount of organic matter that was removed from the shale oil, was thus determined.  Following this orientation work a semi continuous bench-scale apparatus was built so that heated solvent could be pumped through a bed of shale under elevated pressure, thus removing the converted organic matter from the spent shale.  After some operating experience had been gained, a continuous unit was constructed.  This permitted treating a slurry of shale oil and pulverized oil shale at about 300 p.s.i. and temperatures of 750 to 850 F. for various retention times.  Considerable cracking and polymerization of the shale oil were found to take place during the process.  In an attempt to prevent this, a study was made of extraction of the shale in batch type autoclaves under high partial pressures of hydrogen at total gas pressures of as much as 4,300 p.s.i. at 850 F.

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Large block experiments operational plan

The large block experiments were originally conceived of as a series of burn cavity growth tests in large, isolated blocks of coal that could be opened up for inspection after each burn was completed. The concept has been modified to be more economical by using an exposed coal face in a mine rater than separate blocks. Although the name "Large Block Experiment" is no longer quite so descriptive it has been retained since it does serve to emphasize the experimental, almost laboratory nature of these tests.

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Refining of shale oil. [5-stage process for removing N compounds]

The invention herein described and claimed may be manufactured and used by or for the Government of the United States of America for governmental purposes without payment of royalties thereon on thereafter.  This invention relates to the refining of crude oils derived from oil shale and is particularly concerned with the method for the removal of organic nitrogen compounds from shale oils wherein these compounds normally occur in large amounts.

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Isolation and identification of pyrrole and 2-methylpyrrole from shale oil

"Shale-oil products before treatment generally show excessive color and gum formation. This has been attributed to the presence of pyrrole-type compounds. To investigate this problem further, the particular compounds present should be known. In this research pyrrole and 1-methylpyrrole were isolated and identified from an oil prepared from Colorado oil shale. Pyrroles, as a class, have been identified in shale oils  by the pine-splint test and the isatin test. However, there is no record of previous identifications of individual compounds. This is probably due to the reactivity of the compounds as evidenced in this research by low recoveries from each  stage of the separation."

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Desulfurization of 10-ton retort off-gas using a Venturi scrubber

WRI has investigated Venturi scrubber performance in desulfurizing off-gas generated by WRI's 10-ton oil shale retort. A theory of weak electrolyte transport is derived, and two computer models are developed which describe desulfurization. Data on hydrogen sulfide removal and transmissometry are presented. The hydrogen sulfide removal data are analyzed using the above models. Desulfurization was selective, regardless of the solvent used. Removal efficiencies of 60 to 70% were routinely observed, even though solvent concentrations were low compared with industrial applications. This suggests the use of a low-cost desulfurization process using a Venturi absorber. Based on the above, it is concluded that a Venturi scrubber may be the best device for the treatment of in situ oil shale retort gas. The transmissometry data show good correlation with Venturi operating parameters, demonstrating the usefulness of transmissometry applications.

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Investigation of waxes isolated from heavy oils produced from Northwest Asphalt Ridge tar sands. [Utah]

During the late 1970's, the Laramie Energy Technology Center operated two in-situ combustion projects in the Northwest Asphalt Ridge tar sand deposit of Utah. Some of the heavy oils produced were observed to have high pour points, which resulted in handling problems in cold weather. These heavy oils contain waxes, which were found to be n-alkane homologues ranging past carbon number 60. These alkanes seem to have been derived from what are probably Ozokerite veins, which are found in the tar sand deposit. Samples from these veins and waxes derived from produced heavy oils were studied using /sup 13/C NMR, IR, and chemical ionization mass spectrometry.

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Wastewater treatment study:  MIS retorts. Naval Oil Shale Reserves Management Support and Systems Engineering Project

Results from an earlier analysis showed that water requirements for vertical modified in situ (MIS) retorting options were much higher (6 to 8 barrels water/barrel oil) than what has generally been published (0.6 to 2 barrels water/barrel oil). This large discrepancy was attributed to the lower oil yields from the MIS retorts (47 to 55 percent) and the fact that no retort waters were recycled to generate steam for the retorts and/or electric power. This study was undertaken to determine the efficacy of using dirty retort condensates to generate steam, evaluate technologies available for wastewater cleanup, and estimate costs associated with this cleanup. The retort waters would be treated to produce a 100-psig steam with 100 to 150/sup 0/F superheat for use in the retorts, and a medium- to high-pressure steam to generate power using steam turbines. A major determination of this analysis is that treatment of the retort waters has not been attempted to date. The incremental selling price of oil at 15 percent DCF-ROI, due to treatment of these retort condensates, is $1.45/barrel for generating 100-psig steam with 100/sup 0/F to 150/sup 0/F superheat and $2.28/barrel for generating high-pressure steam for power generation. This incremental cost is over the base selling price of oil for the MIS-5 case of $34.20/bbl. This analysis shows that it is possible to upgrade the retort condensates to boiler feedwater quality, but the cost of wastewater treatment is high compared to the purchase of raw water at approximately $0.50/barrel.

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