AndreaBozzo/ceres-open-data-index huggingface dataset:
Isothermal decomposition of Colorado oil shale

Isothermal decomposition studies have been conducted in the temperature range of 368 to 500/sup 0/C using a 52-gallon-per-ton Colorado oil shale. A tubular and a heated sand-bath reactor system were used, both yielding material balances of at least 99.7  - 0.2%. Kerogen conversion to bitumen, oil, gas, and solid product was measured for different residence times at isothermal conditions. Elemental analyses were obtained on the bitumen, oil, and solid reaction products. Product gas composition was measured using an on-line gas chromatograph. Liquid and solid state /sup 13/C NMR measurements were made to determine the aliphatic and aromatic carbon fractions in the liquid and solid products. Molecular weights of the bitumens and oils were measured also. The hydrogen to carbon ratios, carbon aromaticities, and molecular weights of the produced oils were remarkably constant at all temperatures and residence times. The bitumen showed compositional changes indicative of progressive aromatization during decomposition. The aliphatic carbon in the residue decreased, having a time dependence similar to the total organic carbon, whereas the aromatic carbon exhibited almost no time dependence. The total aromatic carbon in the products increased by about 30% over the original aromatic carbon in the raw shale. One set of experiments showed a 94% conversion of kerogen to total soluble products. Rate constants for the kerogen decomposition and product evolution were obtained by simple first-order, distributed activation energy, and initial slope methods of analyses. Attempts were not successful in modeling the kerogen decomposition using a bitumen intermediate. While good fits were obtained for the oil and gas data, the model did not provide satisfactory fits to the bitumen or residue data. The lack of fit to the bitumen data is attributed to the changing composition of the bitumen. 27 refs., 21 figs., 3 tabs.

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Ecological investigations:  vegetation studies, preliminary findings

The objective of the vegetation studies conducted on the research site is to produce a descriptive data base that can be applied to determinations of carrying capacity of the site and surrounding area. Additional information obtained about parameters that influence vegetation growth and maintenance of soil nutrients, and moisture and temperature regimes help define dynamic relationships that must be understood to effect successful revegetation and habitat rehabilitation. The descriptive vegetation baseline also provides a point of departure for design of future monitoring programs, and predictive models and strategies to be used in dealing with impact mitigation; in turn, monitoring programs and predictive modeling form the bases for making distinctions between natural trends and man-induced perturbations.

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Vacuum process for recovery of oil from oil shale

A unique oil shale retorting method which operates at low pressures (5 to 10 torr) was developed. Investigations were conducted on one to five gram samples in a laboratory bench-scale reactor to determine the optimum retorting parameters. To demonstrate the feasibility of the method on a larger scale, experiments were carried out on a prototype reactor capable of processing 22 kg of shale in five hours. Initial studies of Green River Formation shale showed that the optimum yields of oil and high heating value gases were obtained at a retorting temperature of 420/sup 0/C to 450/sup 0/C and a residence time of one hour. Five gram samples of six grades of shale, ranging from 12 to 68 gal/ton were processed, and oil yields of 80 to 90% of the Fischer assay were achieved. Eastern shales were also processed in the benchscale unit, and oil yields of up to 200% of the Fischer assay and a high heating value gas were obtained at a retorting temperature of 400/sup 0/C. Retorting eastern oil shale in 200 torr of helium or 200 torr to 650 torr of hydrogen yielded less oil than retorting at a pressure of 0.1 torr. Oil yields of 92 to 97% of the Fischer assay were obtained from western shale in the prototype reactor at a temperature range of 340 to 375/sup 0/C and 110% at 425/sup 0/C. For an eastern shale, the oil yield was 114% of the Fischer assay. Western shale oils obtained from vacuum retorting are similar in composition and properties to shale oils obtained from other retorting methods. Eastern oils from vacuum retorting contain less nitrogen and have lower pour points than western shale oils, but have higher sulfur and aromatic contents. High Btu gases are obtained from the vacuum processing of both western and eastern shales. The gas from western shale contains more carbon dioxide while the gas from eastern shale contains more carbonyl sulfide and sulfur dioxide. 27 references, 34 figures.

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Quality of leachate from retorted oil shale wetted with treated process waters

Retorted oil shale samples were moistened with five different treated process waters and then leached following the American Society for Testing and Materials method D3987. Concentrations of total inorganic carbon, arsenic, boron, barium, cadmium, chromium, molybdenum, lead, antimony, selenium, strontium and vanadium were measured by inductively coupled argon plasma emission spectroscopy in both the process waters and the leachates from the moistened oil shale samples. Moistening the retorted oil shale with the treated process waters did not result in elemental adsorption by the oil shale and may have generally decreased the quality of the leachates. Long-term equilibrium studies are recommended for further evaluation of codisposal with treated process waters. 6 refs., 3 tabs.

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Shales and other argillaceous strata in the United States

This report presents detailed geologic and hydrologic data that describe shales and other argillaceous rocks; data are from the open literature. These data are intended to be used in the future to aid in assessment of various strata and their potential for repository siting. No observations, conclusions, or recommendations are made by the authors of this report relative to the suitability of various argillaceous rocks for waste disposal. There are, however, other published reports that contain technical data and evaluative statements regarding the suitability of various argillaceous rocks for repository siting. Where appropriate, the authors of this report have referenced this previously published literature and have summarized the technical data. 838 refs., 121 figs., 6 tabs.

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Environmental research plan for the Geokinetics Inc. investigation of the horizontal in situ oil shale retorting process

The Environmental Research Plan developed for the Geokinetics Inc. Horizontal In Situ Oil Shale Retorting Project, has been prepared as two individual documents. The first document is the Program Outline (Spradlin, et al, 1979) which defines the general goals and objectives of the environmental research program. The second document, i.e. this document, is the Research Record which details the actual research projects performed in accordance with the goals established in the Program Outline. In tandem, both documents comply with the provisions set forth in the Cooperative Agreement #DE-FC20-78LC10787, the Environmental Assessment (DOE, December 1979), and in DOE Order 5480.1. (Environmental Safety and Health Plan).

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Calculation of rock motion during bench blasting

CAROM is a distinct element, dynamic code developed at Sandia National Laboratories to calculate the motion of rock fragments during blasting. It has recently been improved to incorporate a mechanism for its elements to mimic non-circular rock fragments. With this option, elements stack and move in ways that are characteristic of irregular boulders of blasted rock. In bench geometry, CAROM has been used to examine the possibility of producing variations in muckpile shape due to variations in detonation-time delays between rows. Surprisingly, the shape of the muckpile was predicted to be insensitive to time delays between detonation of rows of explosives, except where the rock fracturing was affected by the time delays.

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Thermal conductivity and thermal diffusivity of Green River oil shale

Information on the thermal properties of oil shale is necessary for process design of both aboveground and in situ processes. This paper presents data on the thermal conductivities and thermal diffusivities of various grades of oil shale, of retorted shales, and of burned shales which are free of organic matter. The thermal properties are correlated with shale grade, temperature, and bedding plane orientation. Determinations were made both perpendicular and parallel to the bedding planes, and at several different temperature levels. Conductivity values ranged from about .69 W m-1 deg-1 for 58.6-gallion-per-ton shale to about 1.56 W m-1 deg-1 for a lean, 8.6 -gallon-per-ton shale. Conductivities of the retorted oil spent shales from these raw shales ranged from .26 to 1.38 W m-1 deg -1 and of the burned shales from less than .17 to 1.21 W m-1 deg-1. An equation was developed for calculating the thermal conductivity of raw, retorted, and burned Green River oil shales.

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Properties of Green River oil shale determined from nitrogen adsorption and desorption isotherms

Oil shale, a major potential source of liquid fuels, consists of a complex mixture of organic and inorganic constituents in variable proportions. Data have been reported on particle-size distribution, and particle-size classification of the inorganic constituents. The present study indicates that oil shale is a highly consolidated organic-inorganic system with no significant micropore structure, pore volume, or internal surface. The mineral constituents have an appreciable surface area, about 3 to 5 square meters per gram, which appears to be limited mainly to external surface. They contain some micropore structure which has random pore-size distribution, pore radii ranging from 10 to 100 A.

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Oil shale programs. Quarterly report, July 1978--September 1978

This document is the eleventh in a continuing series of quarterly reports, and describes the Sandia Laboratories'oil shale activities during the period between July 1 and September 30, 1978. This work is being performed under three seperately defined programs, all of which are funded by the United States Department of Energy (DOE) and administered through the Division of Fossil Fuel Extraction. The three programs are identified as follows:

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Analysis of oil shale retort production stream gases for sulfur species

"Analysis of the sulfur species in the production gas stream  of oil shale retorts is important for environmental and process development needs. Combined gas chromatography/mass spectrometry and gas chromatography with flame photometric detection  have been applied to the qualitative and quantitative analysis of sulfur species in the production gas stream from six oil shale retorting experiments . Hydrogen sulfide was determined to be the most abundant species and represented approximately 95 percent (wt.) of the sulfur present . Minor sulfur species identified and quantitated include carbonyl sulfide, carbon disulfide,  ethylmercaptan, ethylmercaptan, propylmercaptan, and thiophene.  Sulfur dioxide was not identified during any of the  retorting experiments studied. The distribution of these sulfur species from the six retorting experiments is important because it provides a baseline for the design of process control technologies. The importance of the  liquid product collection train for control of sulfur emissions was also demonstrated."

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Energy from true in situ processing of Antrim Shale:  extraction trials in an explosively fractured site

Three in situ energy extraction trials were conducted at The Dow Chemnical Company's oil shale site, in Michigan's Sanilac County, near the town of Peck. Here the Antrim shale layer occurs between 1200 and 1400 feet underground. The trials began on October 14, 1979 and ended on April 1, 1980. The three trials, lasting 7, 60 and 17 days respectively, were conducted in a formation prepared by explosive fracturing. Ignition energy was generated with a methan burner and ignition services were provided by TOR Developments, Inc. . Some energy in the form of a dilute fuel gas (5-50 btu/scf) was recovered in each trial but upon ignition drastic decreases in flow communication occurred between injection and production wells. That problem prevented the planned exploration of techniques which would raise the energy value of the production gas. Upon cool down of the formation after each trial, air permeability tests showd inter-well communication levels returning to near preburn levels. Thermal expansion is the most likely cause of the reduced permeability experienced under retorting conditions.

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Investigation of the effects of heating rate on coking of shale during retorting

The retorting of oil shale distributes organic carbon among three possible products: the liquid product, the noncondensible product, and the residual carbon (coke). The production of coke is detrimental because of the economic effects caused by the loss of organic carbon to this relatively intractable carbon form. Two reference oil shales, a Mahogany zone, Parachute Creek Member, Green River Formation oil shale from Colorado and a Clegg Creek Member, New Albany oil shale from Kentucky, were studied to evaluate the conditions that affect coke production during retorting. The variable that was studied in these experiments was the heating rate during retorting because heating rate has been indicated to have a direct effect on coke production (Burnham and Clarkson 1980). The six heating rates investigated covered the range from 1 to 650/degree/C/h (1.8 to 1169/degree/F/h). The data collected during these experiments were evaluated statistically in order to identify trends. The data for the eastern reference oil shale indicated a decrease in coke formation with increases in the heating rate. The liquid and noncondensible product yields both increased with increasing heating rate. The distribution of products in relation to retort heating rate follows the model suggested by Burnham and Clarkson (1980). Coke production during the retorting of western reference oil shale was found to be constant in relation to heating rate. The liquid product yield increased with increasing heating rate but the trend could not be verified at the 95% confidence level. The coke production observed in these experiments does not follow the prediction of the model. This may indicate that coke formation occurs early in the retorting process and may be limited by the availability of organic materials that form coke. 6 refs., 10 tabs.

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Economic analysis of a white nahcolite installation in Colorado. Option I, Circa 1971

This is one of three reports evaluating hypothetical industry-scale projects for mining and processing of oil shale and/or associated sodium minerals in Colorado. Option I is concerned only with material from a white nahcolite bed in the Piceance Creek basin, Colorado, containing a high concentration of sodium bicarbonate at a nominal depth of 1900 feet. A nahcolite mine and processing plant is designed to mine 8000 tons of nahcolite ore per calendar day yielding 4071 tons per calendar day of soda ash product. The soda ash will yield an annual income of $52,749,400. Annual operating expenses including labor, materials, maintenance, taxes, insurance, payroll overhead, and depreciation will be $18,821,900 in 1971 dollars. The discounted cash flow rate of return is equal to 30.74 percent based on a weighted average depreciation life of 12.88 years.

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Controlled-source audio magnetotelluric (CSAMT) survey of steamflood in subsurface tar sands

A steamflood experiment, designated TS-1S, was conducted by U. S. Doe Laramie Energy Technology Center in the Northwest Asphalt Ridge Tar Sand. The later stages of this experiment were mapped at depth using the controlled source audio magnetotelluric (CSAMT) technique to assist in determining the location of the stream front. Normalized maps were produced which are consistent with the production data, temperature data from monitoring wells, and post test coring data. The results indicate that the CSMT technique shows promise for monitoring thermal front locations.

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Energy from in situ processing of antrim oil shale. Quarterly technical progress report, October--December 1978

explosive fracturing activities for the hydraulic fracturing subtask were completed in the 100 series wells. Well cleanout was almost completed and permeability studies and fracture evaluation will proceed as soon as it is complete. Evidence that there is communication between these wells contiunes to accumulate. The third and fourth shots in the explosive underreaming series were detonated in Well #301. The well cavity was increased by a factor of 2.4 compared to the original borehole volume for a 62 foot section afte the third shot. The fourth shot produced more damage to the bottom section of well casing. Further activity here will be delayed until the well can be reopened and logged in January. For the chemical underreaming subtasks, well #201 was notched in a limestone stringer below the Antrim formation. The well was hydrofractured with water but no communication with nearby wells was observed. Further evaluation of this subtask is underway.

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Laboratory evaluation of selected syncrude products and upgraded by-products as pavement-recycling agents

The following conclusions appear warranted based on the information derived from this study: (1) Selected syncrude products and upgraded by-products may be successfully used as recycling agents for field aged asphalt pavements. Those tested in this study performed equally as well as the commercially produced recycling agents. (2) Several of the blends containing the syncrude recycling agents exhibited excessive hardening and weight loss upon exposure to the thin film oven test. (3) Properties of recycled mixtures are highly dependent upon the type and amount of recycling agent. (4) The Rostler-Sternberg separation analysis on both the syncrudes and syncrude blends does not seem to produce results that correlate with other recycling agents. (5) Rostler-Sternberg analysis indicated a relatively high fraction of nitrogen bases in the syncrude additives, particularly those from shale oil. Although basic nitrogen in asphalts has been associated with improved resistance to moisture, recycled mixtures containing these materials did not exhibit any significant improvement in resistance to damage by water. Recycled mixtures containing recycling agent 4 (a soft tar sand asphalt) imparted excellent flexibility and yet adequate strength to paving mixtures at low service temperatures. (7) All of the blends containing the syncrude-based recycling agents, except California Coastal with recycling agent 3 (Tar Sand Asphalt and Stabilized Shale Oil), met criteria set forth by Halstead and Krchma for acceptable field performance. (8) The syncrude-based recycling agents produced blends with Rostler parameters and N/P values nearer those of the original asphalts than the commercial recycling agents. (9) According to Rostler-Sternberg analyses, none of the recycling agents were able to restore a base asphalt to its original composition, but this was not and should be not expected. 33 figures, 21 tables.

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Retorting Green River oil shale in a carbon dioxide atmosphere

Green River oil shale was retorted in an atmosphere of carbon dioxide. An externally heated laboratory pressure retort was used. The effects of retort heat-up rate, gas flow rate through the retort, maximum retort temperature, system pressure on oil and gas properties and yields were studied. It was found that oil yield is inversely proportional to system pressure while gas yield is proportionally related to the pressure. High pressure also improves the pour point and viscosity of the crude shale oil. Correlations of oil and gas yields and properties with the test conditions were determined by least squares analysis of the data and are reported. 2 figures, 8 tables.

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Scaled-physical-model studies of the steam-drive process. Final report

The main goal of this project was to gain an understanding of the influence of controllable, operating practices and of reservoir parameters on the steam drive. The steam drive, because the chief phenomena of fluid flow and heat flow obey the same laws of diffusion, can be physically scaled. The validity of the results of the scaled models is evidenced by the correspondence of the results with those reported in field operations. In order to conserve on resources, this report is limited to a summary statement of the findings and conclusions of the overall project with separate chapters devoted to an account of specific tasks which came to fruition during the latter part of the project. Summary of results are presented for the following projects: gravitational instability of a steam drive; roles of oil viscosity and steam temperature on the production of crude oil when the steam flow is stratified; extension of the steam drive to tars and bitumens; occurrence of the optimum steam injection rate; emulsification and oil productivity; role of reservoir thickness; cyclic injection of steam in a steam drive; high gravity crudes; partial substitution of inert gas for steam. Two projects completed and described in detail are: effect of oil viscosity on reservoir thickness on the steam drive; and anticipated effect of diurnal injection on steam efficiency.

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Thermodynamic properties of organic nitrogen compounds that occur in shale oil and heavy petroleum: Topical report

Condensed-phase heat capacities and enthalpies were determined at temperatures from near 10 to 400 K for N-methylpyrrole, 2,5-dimethylpyrrole, piperidine, 2-methylpiperidine, 4-methylpyridine, and N-methylcarbazole and were used to provide the Gibbs energy, enthalpy, entropy and heat capacity along the vapor saturation line at temperatures from 0 to 400 K. The corresponding ideal gas thermodynamic properties were derived with available vapor pressure and enthalpy of vaporization data. The Gibbs energy, enthalpy, and entropy of formation were derived for the ideal gas at selected temperatures with available enthalpy of combustion data. 37 refs., 9 tabs.

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Ammonia evolution during oil shale pyrolysis

Ammonia (NH/sub 3/) evolution during pyrolysis of three Green River Formation shales and one Eastern (Devonian) shale was studied. Most of the NH/sub 3/ that evolved during Fischer Assay-type pyrolysis was dissolved in retort water; the remaining NH/sub 3/ was trapped in an acid solution. Ammonia concentrations were measured with an NH/sub 3/-sensing electrode. We varied the peak pyrolysis temperature (PT) from 350 to 750/sup 0/C and the heating rate from 1 to 50/sup 0/C/min. The NH/sub 3/ yields increased rapidly above the oil-generating temperatures to a maximum at PT approx. = 700/sup 0/C and then decreased at PT = 700/sup 0/C because of decomposition of NH/sub 3/. The NH/sub 3/ yield showed no dependence on the heating rate at PT < 550/sup 0/C and decreased with increasing heating rate at higher peak temperatures. The maximum yield of NH/sub 3/ at PT < 500/sup 0/C reflected the organic nitrogen content. We developed a kinetic model for NH/sub 3/ evolution which takes into account the NH/sub 3/ generation from organic and inorganic nitrogen sources and NH/sub 3/ decomposition. 6 refs., 7 figs., 3 tabs.

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