AndreaBozzo/ceres-open-data-index huggingface dataset:
Review of the environmental impact of ground disposal of oil shale wastes

Waste disposal methods for the major types of extraction processes, the potential environmental impacts of waste disposal to the ground, mitigation of environmental effects, and further research needs of the oil shale industry are considered. Principal waste products of oil shale extraction constitute up to 125% of the original volume, and disposal may, therefore, affect vast land areas. Principal wastes scheduled for ground disposal include the waters produced during retorting and subsequently separated from the shale oil and the spent shales remaining after extraction. Retort waters contain relatively high concentrations of complex, soluble organic components and the spent shales contain potentially leachable salts and organic pyrolytic products. In addition, spent shales have erosion potential when disposed on the surface and considerable effort is being directed to shale management, emphasizing erosion control and shale as a growth medium, and revegetation methods for establishing salt- and drought-tolerant plant species.

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Geokinetics in situ shale oil recovery project. Third annual report, 1979

Objective is to develop a true in situ process for recovering shale oil using a fire front moving in a horizontal direction. The project is being conductd at a field site located 70 miles south of Vernal, Utah. During 1979, five retorts were blasted. Four of these were small retorts (approx. 7000 tons), designed to collect data for improving the blast method. The fifth retort was a prototype of a full-sized retort measuring approximately 200 ft on each side. Two retorts, blasted the previous year, were burned, and a third retort was ignited near the end of the year. A total of 5170 bbl of oil was produced during the year.

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Investigation of the geokinetics horizontal in situ oil shale retorting process. Quarterly report, October-December 1979

The burn of Retort 17 was terminated December 10. Retort 18 was ignited November 12. Retort 17 produced 510 bbl during the quarter for the total of 3,775 bbl, while Retort 18 produced 1,187 bbl. The shale oil was analyzed. Environmental studies were done.

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Origin of the quartz in Antrim Shale

Study of the macroscopic and microscopic properties of the Antrim Shale indicated an important anomaly, the quartz. The Antrim Shale (Devonian, Michigan Basin) contains a large, but quantitatively undertermineable volume of authigenic quartz. The shale contains approximately 50% quartz by weight of which, in the >500 mesh size fraction, 56% is polycrystalline. This is approximately 2X the amount of quartz in most shales and 10X the amount of polycrystalline quartz in the silt-size fraction of sandstones and shales. Scanning electron microscopy reveals an authigenic surface composed of hexagonal tabular plates which coalesce to form smooth grain surfaces. These plates have not been previously reported on quartz grains. Oxygen isotopes of quartz and carbonate phases are interpreted to indicate a gradual isotopic lightening of the pore fluids, from approximately -4/sup 0///sub 00/. Most of the authigenic quartz has a delta/sup 18/O = 22/sup 0///sub 00/ (SMOW).

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Characterization of Devonian shales using laser pyrolysis-gas chromatography

Pulsed Nd pyrolysis with minimum sample pretreatment generates adequate quantities of products for analytical determinations. Significant quantities of pyrolysis products apparently result from methane and ethane released by thermal degradation. Focused power deposition leads to increased ethane production. This may result from a deeper penetration into the sample exploring regions removed from the surface that are less depleted in naturally occurring low molecular weight gases. Higher molecular weight components are readily apparent. These compounds may serve both as useful chemical markers and as component sections of the larger molecular weight species that contain the candidate gaseous fuels.

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Energy promise of unminable coal. [Hamma, WY, expts]

Low-Btu gas produced at Hanna consists of 4 to 6 percent methane; 45 to 50 percent nitrogen, because air rather than pure oxygen is injected; 12 to 18 percent carbon monoxide; 15 to 20 percent hydrogen; 10 to 15 percent carbon dioxide; small amounts (less than 1 percent) of ethane and propane; and about 0.1 percent hydrogen sulfide. The combustible gases contained in this mixture are hydrogen, methane, carbon monoxide, ethane, and propane, Nitrogen and carbon dioxide have no heating value and simply dilute the ases produced from underground coal gasification (UCG), thereby yielding the low-Btu gas. Injecting oxygen rather than air would achieve a higher Btu gas; no nitrogen would be produced. Plans to do this at Hanna have been made, but the first-generation process is to develop the system using air. Oxygen injection requires stringent safety precautions and preparation not needed during air injection. One of the most promising aspects of UCG is that it lacks those major environmental impacts associated with current coal mining or coal combustion techniques. Large areas of land are not removed from use for any extended periods of time, and reclamation is not a serious problem because the land surface is not disrupted. There are some other advantages: no sulfur oxides are emitted because the sulfur can be scrubbed from the gas before burning it; less-high-quality water is required because the water in the coal regardless of its quality, is used in the process; and, no large amounts of solid wastes are left above ground, all ash is left in the coal seam. However, there will be some environmental impacts. The areas of major concern are the effects of UCG on groundwater quality and the effects of subsidence. The economic feasibility of UCG is purely speculative at this time.

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Western oil-shale development:  a technology assessment. Volume 5:  an investigation of dewatering for the modified in-situ retorting process, Piceance Creek Basin, Colorado

The C-a and the C-b tracts in the Piceance Creek Basin are potential sites for the development of oil shale by the modified in-situ retorting (MIS) process. Proposed development plans for these tracts require the disturbance of over three billion m/sup 3/ of oil shale to a depth of about 400 m (1312 ft) or more below ground level. The study investigates the nature and impacts of dewatering and reinvasion that are likely to accompany the MIS process. The purpose is to extend earlier investigations through more refined mathematical analysis. Physical phenomena not adequately covered in previous studies, particularly the desaturation process, are investigated. The present study also seeks to identify, through a parametric approach, the key variables that are required to characterize systems such as those at the C-a and C-b tracts.

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Energy from in situ processing of antrim oil shale. Quarterly technical progress report, April-June 1980

Processing of data from the F80 extraction trials continued for much of this quarter. Several computer programs were written so the data could be evaluated or accessed for plotting. Numerous computer generated plots were made for use in the topical reports which are in preparation. Activity at the experimental site has been directed toward an orderly shutdown and dismantling of equipment. All but nine of the wells were filled with cement and capped in accordance with th requirements of the Michigan Department of Natural Resources. Shale characterization work was continued at four universities in Michigan under subcontracts. Work on final reports of several of these projects has begun.

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Oil shale programs. Seventeenth quarter report, January-March 1980

This document is the seventeenth in a continuing series of quarterly reports, and describes the Sandia National Laboratories oil shale activities during the period between January 1, 1980 and March 31, 1980. Sandia's major role in the DOE Fossil Energy in situ oil shale program is to provide a quantitative evaluation to DOE of the field projects being supported by DOE/FE in the development of commercial in situ oil shale processes. This requires the deployment of instrumentation systems and the application of analysis techniques to evaluate key procedures and operations. In order to fulfill this responsibility, it is necessary to develop new and advanced instrumentation systems and associated deployment, recording, and analysis techniques that are unique to the field project needs. In addition, a rock mechanics program provides material properties, material response models, and computational methods for use in the design, analysis, and evaluation functions. This report describes detailed activities in these project areas over the last quarter.

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Oil shale programs. Sixteenth quarterly report, October-December 1979

This document is the sixteenth in a continuing series of quarterly reports, and describes the Sandia National Laboratories oil shale activities during the period between October 1, 1979 and December 31, 1979. Sandia's major responsibility to the DOE in situ oil shale program is to provide a quantitative evaluation to DOE of the various field projects being supported by DOE in the development of commercial in situ oil shale processes. This requires the deployment of instrumentation systems and analysis techniques to evaluate key procedures and operations. In order to fulfill this responsibility, it is necessary to develop new and advanced instrumentation systems and associated deployment, recording and analysis techniques that are unique to the field projects. In addition, a rock mechanics program provides material properties, material response models, and computational methods to support the design and evaluation functions. This report describes detailed activities in these project areas over the last quarter.

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Steam generation using multi-solids fluid bed combustion technology for heavy oils and tar sands recovery

Conoco is successfully operating a prototype 50 MMBTU/hr., solid fuel-fired, Multi-Solids Fluid Bed Combustor (MS-FBC) to generate 80 quality 2450 psig steam for tar sands recovery from the San Miguel-4 formation in Maverick County in South Texas. The facility is designed to burn high ash coal or high sulfur petroleum coke with environmentally acceptable emission levels of SO, NO, CO and particulates. More than 8,000 hours of on line operation have been logged since startup of the fluid bed combustor in January 1982. This paper describes the selection process and criteria used by Conoco in selecting this technology, the key process design considerations and comparative economics with conventional oilfield steam generators. It also discusses the overall system performance and plant modifications which have contributed to improvements in the operability and reliability of the fluid bed combustor steam generator.

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Sources and kinetics of sulfur species in oil shale pyrolysis gas by triple quadrupole mass spectrometry

A fully computer automated triple quadrupole mass spectrometer was used to determine 10 sulfur containing gases from oil shale pyrolysis. The gases were present in concentrations ranging from tens of percent to less than 0.1 ppM. The TQMS was found to be the only instrument available with the required speed (10 gases determined in 600 ms), dynamic range (10/sup 7/) and ability to analyze for a wide range in concentration with only a single standard. This paper describes work done with organic and inorganic spikes added to raw shales and to acid treated shales. The sulfur containing organic spikes were chosen based on their sulfur group functionality to see if they would aid in determining which sulfur functional groups in the oil shale kerogen produce various sulfur gases.

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Volumetric heating of oilshales by electromagnetic methods. Volume 5. Mathematical modeling

A mathhematical model for electromagnetic heating of oil shales is developed. The model includes equations for temperature, pressure, saturations, chemical reactions, mass conservation, and source terms. The gases are all assumed to form one bulk species and the oil is assumed to remain in liquid form. The chemical reactions include pyrolysis of kerogen and char, release of bound water, coking, and decomposition of carbonates. Porosity and permeability are dynamic functions of the shale constituents. Nonlinear relationships for viscosity, thermal properties, and source terms are used as inputs to the model. A finite difference approximation to the differential equations is derived and solved using Newton's iteration technique. For the cases studied the solutions are quite stable. Numerical results are included and a preliminary study of the optimization of the heating process is presented. 17 refs., 19 figs.

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Proceedings of in situ oil shale briefing, June 7-8, 1983

The in situ shale briefing was organized to summarize the current state of in situ oil shale technology. Key researchers presented summaries of true in situ technology, particularly as represented by DOE sponsored research in the late 70's. Detailed analysis of the retorting process at Geokinetics and Occidental were reviewed. Current in situ retorting processes are characterized by local retort yields on the order of 50%. Presentations on current research emphasized developing a more thorough understanding of yield loss mechanisms in in situ retorts. Bed preparation was identified as being the key to improving retort yields. Research was presented that emphasizes the prediction of long term rock motion during blasting with the eventual goal of predicting permeability as a function of blast design parameters. The briefing concluded with a panel discussion during which representatives of private industry presented their views as to the priorities for the DOE funded research. All abstracts and presentations in the Proceedings have been processed for inclusion in the Energy Data Base.

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Pacific Project, Garfield County, Colorado. Phase 1. Project data book mine and related facilities - Task 8b, 8d. Volume 1. General conditions and engineering standards

The scope of work for the Phase I Pacific Project Mine and related Facilities encompasses a preliminary design package and cost estimates for an underground oil shale mine and related facilities which support a commercial-sized, 18,000 barrel-per-day surface retorting module. The Project design is presented in four major parts: the mine; mine services; raw shale fines and retorted shale disposal; and abandonment. Contents of Volume I include: (1) site description; (2) design basis data package; (3) other general descriptions (geology, rock mechanics, resource analysis, soils investigation and summary tabulation of overall project criteria and data,9046 ); (4) acceptable bidders list; (5) design considerations; and (6) appendices for rock mechanics report and mechanical properties testing of Pacific oil shale. 2 figs., 2 tabs.

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Approach to oil shale health and environmental research:  a concept paper

An integrated research approach is discussed for understanding the complex health and environmental issues that affect both the extent and rate of development of the US oil shale resource. Our main purpose is to investigate process modifications that mitigate any health and environmental impacts while improving or maintaining the yield and quality of shale oil. Because many of the recognized problems are influenced by the physics and chemistry of the retorting process, they must be understood in the context of those process parameters that control the identity and behavior of products, wastes, and effluents. To develop an orderly perspective of health and environmental consequences of oil shale processing, the identity and behavior of the raw material, the chemical principles operative during processing, and the interaction of the raw material and the process to yield products, effuents, and solid wastes must be understood. This approach allows us to determine the nature, magnitude, and time dependence of the organic compound, major, and trace element releases as functions of the raw shale mineralogy, retorting conditions, and spent shale and effluent compositions. This information is essential for understanding and quantifying the environmental behavior and health effects that may result from shale oil extraction and processing.

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Methods for characterizing manganese nodules and processing wastes. Information circular/1983

Analytical procedures are described for the quantitative determination of 16 elements (As, Ba, Be, Cd, Co, Cr, Cu, Fe, Mn, Mo, Ni, Pb, Sb, Se, Tl, and Zn) and 7 ionic species (NH4( ), CO3(-2), Cl(-1), F(-1), NO3(-), PO4(-3), SO4(-2), identification of major and minor mineral components, and measurement of physical properties associated with manganese nodules and nodule processing reject waste materials. Compound identification methods discussed include X-ray diffraction, infrared spectroscopy, scanning and transmission electron microscopy, selective area electron diffraction, and optical and reflected light microscopy. Methods for elemental analysis include atomic absorption spectrophotometry, inductively coupled plasma emission spectroscopy, neutron activation analysis, fluorescent X-ray spectrography, and ion chromatography. Thermal gravimetric analysis, ultraviolet-visible spectrophotometry, ion specific electrodes, and standard wet chemical procedures are briefly discussed. Physical properties determined in manganese nodule materials include grain size distribution, specific gravity, triaxial shear, permeability, maximum density, Atterberg limits, and slurry density. The results of a round-robin analysis of an ammonia process waste material and manganese nodule standards demonstrate the applicability of the discussed methods. Tests discussed for the evaluation of the waste materials for disposal options include the Environmental Protection Agency (EPA) EP toxicity test, the ASTM shake extraction test, and the U.S. Army Corps of Engineers EPA seawater elutriant test.

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Processing needs and methodology for wastewaters from the conversion of coal, oil shale, and biomass to synfuels

The workshop identifies needs to be met by processing technology for wastewaters, and evaluates the suitability, approximate costs, and problems associated with current technology. Participation was confined to DOE Environmental Control Technology contractors to pull together and integrate past wastewater-related activities, to assess the status of synfuel wastewater treatability and process options, and to abet technology transfer. Particular attention was paid to probable or possible environmental restrictions which cannot be economically met by present technology. Primary emphasis was focussed upon process-condensate waters from coal-conversion and shale-retorting processes. Due to limited data base and time, the workshop did not deal with transients, upsets, trade-offs and system optimization, or with solids disposal. The report is divided into sections that, respectively, survey the water usage and effluent situation (II,9043 ); identify the probable and possible water-treatment goals anticipated at the time when large-scale plants will be constructed (III,9043 ); assess the capabilities, costs and shortcomings of present technology (IV,9043 ); explore particularly severe environmental-control problems (V,9043 ); give overall conclusions from the Workshop and recommendations for future research and study (VI,9043 ); and, finally, present Status Reports of current work from participants in the Workshop (VII).

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Environmental assessment of the BX in-situ oil shale project and potential commercial scale development. Final report

This report presents a summary of the observed effects of the pilot scale BX in-situ oil shale project on the local environment. It also provides an estimate of potential impacts on the environment from a conceptual 10,000 bbl/day commercial scale operation. The BX process uses superheated steam as a heat carrying medium for the in-situ retorting of oil shale in the Green River Formation leached zone. No air quality monitoring was required or conducted. There were no serious impacts to surface or ground water from the research facility. Minimal effects on the fauna and flora were observed. Those occurring resulted from alterations to the stream channel which disturbed the substrate. It is projected that the commercial scale concept may result in significant impacts on air resources as a result of fugitive dusts and hydrocarbons. The potential impacts to water resources resulting from construction and operation of commercial scale facility include increased runoff, sediment loading and water quality degradation to both surface and ground water. However, the present concept of the commercial scale facility would minimize most of the aforementioned impacts. The normal operations of a commercial scale facility pose no harmful impacts to the fauna and flora of Black Sulphur Creek. Impacts could occur, however, from accidental spills or leaks from pipelines or from stream disturbances during construction activities. 49 references, 30 figures, 36 tables. (DMC)

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Partitioning and chemical speciation of volatile trace elements during inert gas oil shale retorting

The purposes of this study are to determine partitioning of Hg, As, and Se among spent shale, shale oil, retort water, and offgas during the retorting process and to identify Hg, As, and Se species in shale oil, retort water, and offgas. These species were investigated in eastern and western shales retorted at slow (1 to 10/sup 0/C/min) heating rates to final temperatures of 500 and 750/sup 0/C. The evolution of Hg in the offgas during retort run PNL-2 occurred in two clearly defined stages, with elemental Hg appearing first followed by the organomercury. During the initial stage of Hg release into the offgas, 87% (4 ..mu..g) was identified as elemental. The organomercury appeared at the later stage of Hg evolution in the retort run, accounting for more than 99% (126 ..mu..g) of the mercury in that sample. In general, more than 90% of the As remained in the shale after retorting. The As in the western shale demonstrated a slightly greater tendency to mobilize into the liquid products than did the As in the eastern shale retorted under similar conditions. The As that mobilized preferentially redistributed into the shale oil rather than the retort water in both eastern and western shales, and the redistribution into the liquid products appeared to increase with higher heating rates and maximum temperatures. No As was observed in the offgas during any of the three retort runs monitored. In general, more than 80% of the Se remained in the shale after retorting. The selenium in the eastern liquid products slightly favors partitioning into the retort water. Selenium in the western liquid products is preferentially redistributed into the shale oil. 15 refs., 10 figs., 2 tabs.

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Oil shale project. Quarterly report, January-March 1980

Results are reported on pilot retorting operations including: simulated modified in-situ (MIS) operations, aging of crushed shale, temperature measurement methods, intermittent retorting and recycled offgas. Field testing of retort operation and control is discussed. Model calculations of Rio Blanco No. 0 and No. 10 are summarized. The effects of using oxygen diluted by steam or carbon dioxide in MIS retorting are reported. (DC)

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