AndreaBozzo/ceres-open-data-index huggingface dataset:
Multistage leaching of spent modified in situ oil shale retorts

With a view toward reducing the various costs associated with environmental control technologies for spent modified in-situ (MIS) oil shale retorts, a concept study of forced multistage leaching of these retorts, followed by surface treatment for removing trace elements, has been conducted. The well-known process of multistage, countercurrent leaching was adapted to the conditions of an MIS retort battery, and energy expenditures for pumping and for water treatment, and water requirements were calculated. In comparing control costs for three individual pore volume leaches with a three-stage countercurrent leach, energy expenditure for leaching a hypothetical 50,000 bbl/day plant was reduced from 9.4 million kWh/yr to 3.9 million kWh/yr. Consumptive use of water for leaching similarly was reduced from 70 million cu ft/yr to 31 million cu ft/yr (1,985,000 m/sup 3//yr). The major cost savings were identified to be in the water purification plant investment and size of lined evaporation ponds. Specific site calculations may be made when better information is available on the chemistry of the burned solids and their reaction with leach solutions.

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Ultrasonic thermometry in oil shale retorts

The method relies on the principles of ultrasonic reflectometry to locate and determine temperatures within zones of a slender-rod-sensing element installed in the in-situ retort bed. The measurement technique consists of sending an ultrasonic pulse down an element containing n zones spaced along its length. The zone boundaries are defined by n   1 discontinuities within the element. The time intervals between pairs of returning echoes, caused by reflections from these discontinuities, are measured electronically. These measured time intervals are then related to the average temperature of the corresponding zones. Preliminary results are encouraging, and it appears that the ultrasonic thermometer can be a useful in situ instrument.

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Summary of large block oil shale retorting experiments. [Rapid heating of large blocks of oil shale during retorting occurs in air but not in nitrogen]

An unexplained rapid heating of large blocks of oil shale in an experimental retort has been reported by the Bureau of Mines. Experiments at LLL have shown that this effect is present in blocks as small as 170 lb. when retorted in air but not when retorted in nitrogen.

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Trace elements associated with oil shale and its processing. Final report 1975--1977

This report includes a summary of existing trace element composition data for shale and its products, an evaluation of these data and related studies to estimate the distribution of trace elements among shale products during oil shale processing, and predictions of the disposition and ultimate fate of trace elements after waste disposal or product use. Wide ranges in trace element concentration reflect natural geographic and vertical profile variations in shale.

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Characterization of organic matter recovered from Green River oil shale at temperatures of 400/sup 0/C and below

Organic matter extracted from Green River oil shale by supercritical extraction experiments was characterized by elemental analysis, number average molecular weight determination and field ionization mass spectrometry. The organic matter was also separated into fractions of organic acids, bases, and hydrocarbons. Characterization data demonstrate that the organic matter recovered in high yield from autoclave experiments is similar in composition to organic matter extracted in low yield at solvent reflux temperatures. The composition of organic matter extracted from Green River shale by supercritical techniques is compared with the composition of Green River shale oil produced by several pilot-scale retorting processes.

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Use of high-boiling alcohols to produce shale oil from Green River shale

This report describes the results of experiments in which Green River shale was treated with mono-, di-, or trifunctional alcohols in an attempt to produce high oil yields under lower pressure treatment conditions. The experiment using 1,2-ethanediol (ethylene glycol) and water resulted in a yield of 81 weight percent based on recovered liquid organic matter, a yield equivalent ro 124% of Fischer assay. The experiments using other di- and trifunctional alcohols were not successful in recovering large amounts of oil from the shale. The 1, 2-ethanediol experiments suggests that it may be possible to recover oil from shale in yields much higher than those of conventional retorting precesses at pressures well below supercritical methanol-water. Solvents with boiling points up to 200C, such as n-octanol boiling at 194C and 1,2-ethanediol boiling at 198C, can be removed from liquid product using rotary evaporation under reduced pressure. Higher-boiling alcohols such as glycerin and diethylene glycol would probably not be satisfactory solvents even if recoveries were high because of complicated separation requirements. 10 refs., 1 tab.

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BX In Situ Oil Shale Project. Quarterly technical progress report, September 1--November 30, 1977

Work on the BX in situ oil shale project during the quarter September 1, 1977 to November 31, 1977 focused on the tasks related to laboratory experimentation; project reactivation; mathematical modeling; design and installation of the instrumentation system; project design and construction; and environmental monitoring. Specific activities related to each of these principal task areas are reported here.

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BX In Situ Oil Shale Project. Quarterly technical progress report, June 1--August 31, 1977

Work on the BX In Situ Oil Shale Project during the quarter June 1, 1977 through August 31, 1977 was confined primarily to the tasks concerned with site evaluation. This included the drilling of two core holes, BX-12 and BX-13, and the performance and evaluation of a vertical communication test. Specific activities, their results, and interpretation of these results, with resultant recommendations are reported below.

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Arsenic and nitrogen removal during shale oil upgrading

A reactor model for removal of As and N from shale oil is presented. For shale oil hydrotreating, the reactor model must take into account the effect of arsenic since arsenic is a strong catalyst poison. Even with a guard bed, arsenic is deposited continually throughout the cycle and to compensate for its poisoning effect temperature must be raised to maintain denitrification activity. Because of the highly exothermic reaction, means of heat removal are required to control reactor temperature. As the catalyst activity declines, both due to arsenic and time on stream, conversion in each catalyst bed changes. The lower conversion gives less heat release and, therefore, bed temperature must be increased to maintain catalyst activity. This in turn greatly changes the required hydrogen quench after each catalyst bed as the cycle progresses. Using the developed model the overall shale upgrading process can be optimized. Since arsenic removal and denitrification are highly interdependent, the reactor design needs to be studied in order to minimize overall processing costs. One use of the model is to determine the optimum conditions for arsenic removal since any arsenic leakage directly affects the required severity and cycle life for denitrification. As the arsenic removal is increased via increased guard reactor size, capital costs increase but catalyst usage decreases. The optimum design for denitrification can be found using the model. Conditions are chosen so arsenic removal and coke deposition are balanced to minimize costs.

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Separation of nitrogen compound types from hydrotreated shale oil products by adsorption chromatography on basic and neutral alumina

The nitrogen compounds in hydrotreated shale oil products derived from Paraho shale oil are separated into specific nitrogen-type fractions by using basic/neutral alumina adsorption chromatography. The separation scheme, which gives fast and reproducible results, is successfully applied to shale oil products produced under different hydrotreating conditions. These products vary in the level of nitrogen and/or in the distillation range. Infrared spectrometry of the fractions identified three major nitrogen compound types: pyridine-type nitrogen, pyrrole-type nitrogen, and amide-type nitrogen. The distribution of these nitrogen types in various hydrotreated shale oil products is shown.

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Preliminary sensitivity analysis of the Devonian shale in Ohio

A preliminary sensitivity analysis of gas reserves in Devonian shale in Ohio was made on the six partitioned areas, based on a payout time of 3 years. Data sets were obtained from Lewin and Associates for the six partitioned areas in Ohio and used as a base case for the METC sensitivity analysis. A total of five different well stimulation techniques were evaluated in both the METC and Lewin studies. The five techniques evaluated were borehole shooting, a small radial stimulation, a large radial stimulation, a small vertical fracture, and a large vertical fracture.

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Synfuels technology publications and related reports: a bibliography, January 1983-December 1984

Research on synfuels processes at Sandia National Laboratories emphasizes the chemistry and physics of in situ processes for coal gasification and oil shale, and direct liquefaction processes for coal. Research encompasses modeling, laboratory studies, field testing and diagnostic development. This bibliography lists publications, abstracts and sources documenting the research results for calendar years 1983 and 1984. All papers are available, either from the National Technical Information Service for Sandia documents or from the journals of publication.

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Failure surface model for oil shale

One promising means of recovering oil from oil shale is to retort the shale in situ. Currently, modified in situ technology requires the construction of extensive underground openings or retorts. The remaining media (structure left around these retorts must support the overburden and contain the retorting shale. A failure criterion for oil shale, which is presented in this paper, was developed so that regions in the retort structure where the shale may be approaching failure can be identified. This criterion, adapted from composite materials applications, is essentially a closed surface in six-dimensional stress space and makes it possible to describe the anisotropic nature of failure in layered materials. The failure surface can be defined by five parameters which are determined from five simple laboratory tests. The surface is developed for a 80 ml/kg kerogen content shale and its features are discussed in detail. The predictions of the model are found to be in agreement with the results of a large number of laboratory tests, including uniaxial and triaxial compression tests. One unique (for rocks) test series is discussed which involves the failure of thin-walled tubes under combined compression and torsion. Finally, it is shown how the model can be extended to include the variation of material properties with kerogen content and temperature.

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NOSR 1 hydrology data book. Naval Oil Shales Reserves management support and systems engineering project. Volume 4

Water quality data on NOSR 1 are available for surface water, springs, and groundwater. Surface water samples have been obtained and analyzed by the USGS at the surface water gages since Water Year 1977. The surface water quality analyses contained in this section have been compiled and published in Water Resources Data for Colorado, Volume 2, Water Years 1977, 1978, 1979, and 1980. Springs have been sampled for water quality analysis by both DOE/TRW and the USGS. DOE/TRW has sampled 12 springs. Nine of these springs were sampled once. The other three springs were sampled in September 1980, March 1981, and July 1981. These multiple samples from individual springs were analyzed to determine if spring water quality varied at different times of the year. The USGS has sampled eight springs on NOSR 1 as part of a regional study of the drainages of the Roan Creek and the Parachute Creek. Groundwater has been sampled on NOSR 1, beginning during the 1977 resource evaluation drilling program. During the 1977 drilling program, the USGS sampled the groundwater during drilling using air circulation. In 1978, three additional core holes were drilled - primarily for resource evaluation purposes (core holes 18, 19, and 24). Groundwater samples were obtained during limited pump testing on core holes 18 and 24. Beginning in the summer of 1980 and continuing in the summer of 1981, DOE/TRW obtained groundwater samples from individual water-bearing zones during pump testing of most core holes. In addition, in February 1981, DOE/TRW obtained one bailed open-hole sample from each core hole for water quality analysis. The location of all core holes used to obtain groundwater samples are described. 4 figures, tables.

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Mass spectrometric-potentiometric titration analyses of nitrogen concentrates from shale oils

Nitrogen-rich fractions from retorted and hydroprocessed shale oils have been analyzed by high resolution mass spectrometry. The results from this analysis are compared to the results from titrimetric measurements on the same samples. The comparison shows good agreement except in fractions where the pyrrole and arylamine compound types are concentrated. The use of adequate chromatographic procedures and high resolution mass spectrometry enables the semi-quantitative determination of nitrogen compound types in retorted shale oils and intermediate refined products. From a comparison of the nitrogen compound type distributions in retorted and hydroprocessed shale oils, the effect of catalytic hydrotreatment on nitrogen compound types can be studied. Evidence for the formation of reaction intermediates during hydroprocessing was obtained. The intermediates are similar to those identified in model compound studies.

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Spent shale disposal study for NOSR 1. Naval Oil Shale Reserves management support and systems engineering project

The objective of this study was to develop a disposal system concept for up to four leases operating simultaneously on the NOSR 1 property. Each lease would have a plant operating at a shale oil production rate of 50,000 BPD. Additional objectives included the development of capital costs, operating costs, and the necessary environmental controls for spent shale disposal. The study considered only surface disposal of the spent shale, although disposal back into the mine could be an attractive alternative. The cycle of operation for spent shale disposal developed in this study is comprised of: conveyor belt delivery of the spent shale to an unloading station near the disposal area; loading and hauling of the spent shale to the disposal site; compaction of spent shale; and maintenance of a drainage system for water to a catchment basin. Environmental concerns relating to air quality, water quality, and pile stability are addressed. Potential control measures emphasizing proper compaction, shaping of the pile, revegetation, and leachate/runoff management are suggested. Environmental siting considerations including physical and chemical contexts of the surroundings, biological setting, and regulatory attitudes are addressed for each site. From an environmental standpoint, the NOSR 3 and Ben Good sites are the most favorable for disposal. Unfortunately, slope steepness and inaccessibility make disposal pile operation at the NOSR 3 site virtually impossible. Consequently, this site is not included in the proposed disposal system. Designs are based on a nonhazardous waste classification for the spent shale. Capital and operating costs for preparation, disposal system operation, and environmental controls total $1.20/ton of spent shale or about $1.31/bbl of shale oil produced. 4 references, 7 figures, 13 tables.

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Steam stripping of oil shale wastewaters. LBL/SEEHRL steam stripper:  design, operation, and maintenance manual

Steam stripping is the most often proposed means of treating oil shale wastewaters for the removal of ammonia and carbon dioxide. The removal of organic carbon generally is not an objective. This manual compares current steam stripper design theory with actual operating data reported in the literature and concludes that discrepancies exist between theory and actual practice. Although this manual is by no means a complete literature review on the more detailed subject of mass transfer, references are provided so that the reader can explore the subject material more closely. The primary intent of the manual is to give the operator a brief overview of the chemical and physical principles underlying the steam stripping process. Sufficient information is provided so that the operator can understand how the LBL/SEEHRL experimental-scale steam stripper was designed to be operated. Start-up procedures are detailed, and modifications required to improve performance are presented. Included are notes outlining periodic maintenance procedures for mechanical parts, protocols for the reduction of data, notes on the methods of chemical analysis, and the calculations used for mass balances. 66 references, 16 figures, 21 tables.

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Physical-chemical approaches for the environmentally sound disposal of an oil shale retort water

The extraction of shale oil produces relatively large volumes of polluted process water. These waters contain large concentrations of organic and inorganic pollutants as well as environmentally significant amounts of trace materials. These substances either individually or in combination can be highly toxic to environmental systems. This paper addresses a suggested cleanup sequence designed to remove specific pollutants and to detoxify these waters. Hot gas stripping, followed by activated carbon adsorption and reverse osmosis removed over 93 percent of the total organic carbon load while also reducing the toxicity of the resultant effluent as measured by a standard technique. Depending upon the ultimate use of these waters, the suggested treatment sequence or its individual components could be employed at a pilot or commercial scale retorting facility.

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Reaction kinetics for remodeling oil shale retorting

Results from recent laboratory kinetic studies at the Lawrence Livermore Laboratory (LLL) on gasification, pyrolysis, and mineral reactions in oil shale are presented. The specific pyrolysis reactions investigated include the decomposition of kerogen, the evolution of oil, hydrogen and C/sub 2/ plus C/sub 3/ hydrocarbons and the formation of a carbonaceous residue. Data describing the evolution of H/sub 2/ and CH/sub 4/ during secondary pyrolysis of the carbonaceous residue are also presented. The mineral reaction kinetics discussed include the decomposition and/or reaction (with silica or silicates) of calcite, dolomite, dawsonite and nahcolite. Rate equations describing the effects of CO/sub 2/ and steam on the reactions of calcite and dolomite are presented. Finally, kinetics describing gasification of the carbonaceous residue by CO/sub 2/ and H/sub 2/O are examined. The above kinetic data are summarized in a set of rate expressions that can be used in numerical modeling of oil shale retorting. The rate equations are general enough for modeling both in-situ and surface retorting processes.

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Chemical characterization and analytical considerations for an in situ oil shale process water

Reliable chemical characterizations of oil shale process water have been difficult to obtain due to the lack of standards and limitations of many available analytical methods. These waters are very complex and contain very high or very low levels of many constituents. Chemical interferences are numerous. This paper describes the collection, preparation, stabilization, and chemical analysis of an in situ produced oil shale process water suitable as a reference sample. The sample was produced during the Laramie Energy Technology Center's 1976 Rock Springs Site 9 true in-situ oil shale combustion experiment and carries the designation ''Omega-9.''The sample was analyzed by 13 separate laboratories using six instrumental techniques and a wide range of wet chemical methods. The results of this survey are presented and discussed. Analytical problems specific to process waters are discussed and recommendations for revised methods and additional research are made. The study demonstrated that many standard analytical methods, such as EPA, USGS or ASTM methods, cannot be used to accurately or precisely determine many water quality parameters in process waters. Poor results were obtained for CN/sup -/, COD, phenols, PO/sub 4//sup 3 -/, solids, HS/sup -/, and others. Instrumental methods, including x-ray fluorescence and neutron activation analysis, produced more accurate and precise results than chemical methods of analysis.

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Thermal degradation of shale oil on quartzite particles - preliminary experiments

Oil yields from oil shale retorts are usually less than predicted from Fischer assay, because oil is degraded by consumption, cracking, and coking before it can escape the retort. Work is in progress at Western Research Institute (WRI) on determining rates of oil degradation by cracking and coking exclusive of combustion, under conditions similar to those in the preretorting zone of a retort. The experimental approach involves the introduction of shale oil downward into a bed of crushed quartzite packed in a tubular reactor. The reactor is heated to temperatures in the range of 400/sup 0/F to 800/sup 0/F, while preheated nitrogen flows upward through the tube. The reaction system is described in this report and results are presented of 10 preliminary experiments in which Paraho shale oil was degraded on quartzite particles at 400/sup 0/F, 500/sup 0/F, 600/sup 0/F, and 700/sup 0/F. Residence times for oil vapor were one to two seconds and for heavy (unvaporized) oil were 17 to 180 minutes. Recovery values varied from 85 to nearly 100 wt.%, and there was substantial loss of liquid products in the gas stream. Only trace quantities of light hydrocarbon gases were detected, indicating only a minor amount of cracking. It is concluded that there was little oil degradation in these experiments. It was also concluded that the operating procedure should be changed to achieve better product recovery and longer vapor residence times. 6 refs., 2 figs., 4 tabs.

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Impact of environmental control costs on an indirect coal liquefaction process

This report examines the effect on product price of three different scenarios for the control of emissions to the environment by a conceptual, commercial indirect coal liquefaction facility. The plant design utilizes Lurgi dry-ash gasifiers operating on western, subbituminous coal to provide synthesis gas for low-pressure methanol synthesis and subsequent conversion of the methanol to gasoline. Levels of emission control, which are based as much as possible on existing regulations for analogous processes, range from minimal control to more stringent control than that currently in effect. The use of several emission control options and the reduction of plant size are also examined in regard to their effects on product price. Environmental control to current levels would account for 12% of the product price for the facility assumed here. More stringent emission standards would produce an additional 3% increase. Reducing plant size would also raise product price. Two unpredictable factors having the greatest impacts on product price, however, are inflation and the method of financing. It should be noted that emisson control requirements could be postulated which would substantially change the assumed plant design and, consequently, the assumed service factor and the calculated product price.

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