AndreaBozzo/ceres-open-data-index huggingface dataset:
Characterization of oil shale waters by gas chromatography/mass spectrometry

Characterization work has begun on organic compounds and compound classes to establish a baseline for the evaluation and development of alternative instrumental characterization techniques. For this purpose raw water from two oil shale processes has been subjected to an extraction and gas chromatography/mass spectrometry (GC/MS) analysis. Samples from the R-17 and Rio Blanco processes were chosen for comparison with previous characterization work reported by Poulson et al. (1984, 1985), who used low-cost gas and reverse-phase liquid chromatographic (LC) techniques. In addition, various inorganic and physical parameters were re-evaluated. The preliminary comparison of GC/MS data with the GC and reverse phase LC data previously reported by Poulson et al., indicates a number of positive correlations for both the process waters. Aliphatic carboxylic acids, cresols, xylenols, methyl pyridines, dimethyl pyridines, and trimethyl pyridines were found both in present GC/MS analysis and in earlier GC and LC analyses of the samples. In addition, trimethylphenols were observed in both the present GC/MS analysis and in the previous GC and LC analyses of the Rio Blanco sample. A number of tentatively identified compounds and compound classes were observed in the GC/MS analysis but were unreported in either the GC or LC analyses for both samples. Similarly, several compounds and compound classes previously reported by GC and LC techniques were absent in the GC/MS analysis. These discrepancies may be attributed to either the original GC and LC research design or to a fundamental chemical change in the samples used for the GC/MS characterization. Additional research is necessary in the areas of extraction design, use of comparable GC and GC/MS marker compounds for identification, standardization of chromatographic columns and GC conditions, and the validity of computer library identifications. 3 refs., 2 figs., 12 tabs.

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

Experiments to recover organic matter from Green River oil shale in high yields at temperatures of 400/sup 0/C and below are described. Three different recovery procedures are discussed: experiments wherein liquid organic materials were extracted at atmospheric pressure and temperatures below 75/sup 0/C by solvents of different strengths, autoclave experiments where liquid organics were recovered by heating the shale with a variety of solvents at temperatures between 300 and 400/sup 0/C and pressures between 5 and 32 MPa; and an autoclave experiment where liquid organics were recovered by heating shale in an argon atmosphere for 1 hour at 400/sup 0/C. The liquid organic materials recovered in these experiments represent from four to 90 weight percent of the total organic material in the shale. The liquid organic materials have an average molecular weight of between 500 and 600 amu as compared to a typical shale oil that has an average molecular weight of 300 to 350 amu. Elemental analyses show that the liquid organic materials contain high percentages of hydrogen and nitrogen, as does shale oil. Moreover, the liquid organic materials also contain much larger concentrations of oxygen-containing compounds than shale oil. The experimental results suggest the possibility of developing a new process for recovering both organic and inorganic material from Green River shale.

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BX In Situ Oil Shale Project. Annual technical progress report, March 1, 1977-February 28, 1978 and quarterly technical progress report, December 1, 1977-February 28, 1978

The objective of this project is to demonstrate the technical feasibility of using superheated steam as a heat carrying medium to retort in situ the oil shale in the Green River Formation "leached" zone and provide a mechanism for the recovery of this shale oil with a minimum impact on the environment. Utilizing primarily the natural porosity in the leached zone, approximately one trillion BTU of heat will be injected into a site over a two-year period to heat to retorting temperature a shale zone approximately 550 feet thick and covering about 1 acre. The field project is located at equity DX in situ site in Rio Blanco County in northwestern Colorado.

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Characterization of DOE reference oil shale: Tipton member, Green River formation oil shale from Wyoming

Measurements have been made of the chemical and physical properties of a Tipton Member Green River Formation oil shale from Wyoming. This shale has been designated as a western reference shale by the Department of Energy. Material balance Fischer assays, carbon aromaticities, thermal properties, and bulk mineralogic properties have been determined for the oil shale. Kerogen concentrates were also prepared. Most of the measured properties of the Tipton shale are comparable to results from previous studies of similar shales. 22 refs., 4 figs., 12 tabs.

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Interim hydrology report for NOSR 1. Naval Oil Shale Reserves management support and systems engineering project

In 1977, seven coreholes were drilled on Naval Oil Shale Reserve No. 1 (NOSR 1) in Garfield County, Colorado, to gather information on the groundwater resource, oil shale resource, and stratigraphy. Three additional coreholes were drilled on NOSR 1 in 1978. Limited aquifer testing was performed in both 1977 and 1978. Toward the end of 1979 and early in 1980, all geologic and hydrologic data available for NOSRs 1 and 3 were assembled and subjected to detailed evaluation. Planning for the summer 1980 field program on NOSRs 1 and 3 was based on this evaluation. The evaluation is now documented here, with data samples and those maps and charts necessary for understanding the water resources on NOSRs 1 and 3. A similar evaluation is scheduled for data gathered in the 1980 field program. Publication of a comprehensive data book is planned toward the end of FY 1981, along with a final report characterizing specifically the hydrology of NOSRs 1 and 3. Compiled for this report are data on surface water and precipitation gathered by the US Geological Survey (USGS) (under contract to DOE), groundwater information from the coreholes on NOSR 1, and geological and groundwater data from various sources throughout the Piceance Basin. 139 references, 26 figures, 10 tables.

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Trace nitrogen-containing species in the offgas from two oil shale retorting processes

Five organic nitrogen species were identified in the off gas from two different retorting processes, a modified in situ process and an aboveground process. Hydrogen cyanide, acetonirile, acrylonitrile, propionirile, and isobutyronitrate were determined by gas chromatography combined with a nitrogen-phosphorus detector. Seven other nitrogen species have been tentatively identified in the off gas at one of the in situ retorts. The low molecular weight organic nitrogen species appear to be predominantly nitrides; low molecular weight aliphatic amines do not appear to be present. Possible reaction mechanisms were considered. The nitriles were present in amounts on the order of tens of ppm which was ~1-2% of the gas phase ammonia nitrogen concentration in the off gas. Most of the nitrogen species except hydrogen cyanide appear to be reasonably stable, at least qualitative, for a period of several months in Teflon-lined stainless steel bombs.

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Aromatic hydrocarbons obtained by thermal conversion of Green River oil shale kerogen using CO and H/sub 2/O at elevated pressure

Aromatic hydrocarbons produced from the reaction of Green River oil shale with carbon monoxide and water at elevated pressure and at temperatures from 300 to 450/sup 0/C were investigated. The isolation of these aromatic hydrocarbons involved ion exchange, complexation, silica gel, and alumina chromatographic techniques. Compound types present in these aromatic hydrocarbons were studied by high resolution mass spectrometry and combined gas chromatography-mass spectrometry. Compound types were mostly phenylcyclohexylalkanes, dinaphthenobenzenes, trinaphthenobenzenes, naphthenonaphthalenes, and carotenoid types at 300/sup 0/C; but at 450/sup 0/C compound types were mostly alkylbenzenes, alkylbiphenyls, and alkylnaphthalenes. The composition of aromatic hydrocarbons from the benzene-extracted bitumen of Green River oil shale was found to be similar to that in the 300/sup 0/C product from the CO-H/sub 2/O reaction.

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Basic mechanism to achieve clean combustion of oil shale in fluidized beds

Results are presented of a study undertaken to analyze and assess fluidized bed oil shale combustion, particularly from an environmental standpoint. Oil shales are classified and characterized and their properties are described. Attention is focused on mineralogical composition, porosity, specific gravity, specific heat, calorific value, thermal conductivity, trace metal content, and sulfur and nitrogen content. The mechanisms and kinetics of oil shale retorting and combustion are discussed. The clean combustion of oil shale is examined and fluidized bed oil shale combustion is explored. The simulation of oil shale combustion in a fluidized bed, 6 inches in diameter, is described. The advantages of combustion in a fluidized bed are listed, including: (1) fluidized beds can be effectively used to burn oil shale to produce heat or steam at a high combustion frequency and (2) gaseous pollutants can be removed during combustion inside the bed. Disadvantages are noted, including: (1) the spent shale from a 10-ton steam/hour boiler is estimated to be 78 tons per day at the fresh oil shale feed rate of 104 tons per day; and (2) the fluidized bed must be maintained at a relatively low temperature of 810C.

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Preliminary analysis of pipeline corridor alternatives for Naval Oil Shale Reserve 1

The purpose of this study was to identify and rank potential corridors for pipeline transport of oil shale product from Naval Oil Shale Reserve 1 (NOSR 1) near Rifle, Colorado, to Casper, Wyoming. The oil shale product (classified as a refinery feedstock-grade oil shale) to be transported via insulated and underground pipeline will be transferred to the Northern Tier pipeline at Casper, Wyoming, and then pumped to any of several suitable Midwest refineries for conversion to a refined slate of products. The scope of this preliminary study included the following steps: identification of potential pipeline corridors; development of environmental and engineering criteria with which to evaluate the corridors; development of an approach for comparing and ranking the corridors using the evaluation criteria; ranking of the alternative corridors; and preparation of a rough estimate of pumping and cost requirements. 9 references, 5 figures, 10 tables.

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Proposed water treatment approach for commercial tar sand wastewaters

Waters produced during the steamflood extraction of bitumen from tar sand require treatment before they can be recycled as feedwater for steam generation. The characterization of two waters from commercial-scale tar sand operations indicates that the levels of hardness, oil and grease, silica, suspended solids, and iron must be reduced before these waters can be reused in the bitumen extraction process. The Western Research Institute proposes two treatment methods (electrocoagulation and ultrafiltration) that may, when used in conjunction with standard practices, improve the efficiency of the overall treatment process. 21 refs., 3 tabs.

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Simultaneous measurement of the thermal and electrical conductivity of Green River oil shale. Final report, June 2, 1976--August 30, 1977

Goal was to investigate the thermal environmental effects of in-situ retorting operations. Conclusion is that the insulating nature of the shale and the surrounding country rock are such as to make the thermal pollution due to in-situ retorting an insignificant environmental hazard. An estimate of minimum pillar thickness for pillar temperatures below 250/sup 0/C can be made from the calculations. Thermal conductivity of Green River oil shale decreases with temperature, and 30% anisotropy exists parallel and perpendicular to the sedimentary varve lines. 31 figures, 3 tables. (DLC)

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BX in situ oil shale project. Final report

This final report summarizes the field and laboratory work conducted as the BX in Situ Oil Shale Project, a project jointly funded by the U.S. Department of Energy and Equity Oil Company under a Cooperative Agreement entered into on March 1, 1977. The work described covers the period of March 1, 1977 through September 15, 1982, and includes a period of two years from September 18, 1979 to September 15,1982, during which superheated steam and hot water were injected into an array of eight injection wells completed in the leached zone oil shale of the Parachute Creek member of the Green River Formation in the Piceance Creek Basin of northwestern Colorado.

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BX In Situ Oil Shale Project. Annual technical progress report, March 1, 1980-February 28, 1981 and Quarterly technical progress report, December 1, 1980-February 28, 1981

The objective of this project is to demonstrate the technical feasibility of using superheated steam as a heat-carrying medium to retort in situ the oil shale in the Green River Formation "leached some" and provide a mechanism for the recovery of this shale oil with a minimum impact on the environment. Utilizing primarily the natural porosity in the "leached zone", approximately one trillion BTU of heat will be injected into a site over a 2-year period to heat to retorting temperature a shale zone approximately 540 feet thick and covering about one acre. The field Project is located at Equity's BX In Situ site in Rio Blanco County in northwestern Colorado.

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Alkaline scrubbing of in-situ oil shale retort offgas at Geokinetics

The paper discusses the use of EPA's mobile wet scrubber on a 200-acfm slipstream of Geokinetics'retort offgas to investigate the H2S removal efficiency and selectivity (percent H2S removal/percent CO2 removal) as a function of liquid/gas contact time, alkaline solution OH(minus) concentration, and the specific scrubbing chemical. A venturi and spray tower were used to produce contact times of about 0.003 and 0.2 second, respectively. Three alkaline solutions (NaOH, KOH, and NH4OH) were employed on each contactor at various concentrations for a total of 22 runs. To analyze these results and provide design criteria for future alkaline scrubbers a sophisticated computer model employing the penetration theory for liquid-phase mass transfer was developed.

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Oil shale project run summary large retort Run L-2. [Oil shale blocks in shale nibble matrix]

The object of the L-2 Run was to determine the retorting behavior of individual oil shale blocks in a shale rubble matrix during simulated modified in-situ (MIS) combustion retorting. Conclusions are as follows: The interiors of large particles are delayed in retorting (compared to a surrounding matrix of small particles) by the greater lengths of the heat transports paths in the larger particles and their lower surface/mass ratio. In Run L-2 these delays were determined for six cylindrical blocks of three sizes surrounded by two different matrices. The delays resulted in oil being released from the blocks into an oil degrading environment in the rubble matrix. The combination of high interior block and matrix temperatures and oxygen presence at block surfaces during oil release caused the oil produced in block interiors to be degraded either in transport from the block interiors or in the rubble matrix. For three of the blocks, the fraction of generated oil that was degraded to light (C/sub 1/-C/sub 4/) hydrocarbons was determined from analysis of retort offgas produced during block retorting. The offgas ethene/ethane ratio was a sensitive indicator of oil degradation for all the blocks. High ethene/ethane ratios of intra of intra-retort gas sampled near the blocks the correlated with oxygen presence. The ethene/ethane ratios increased with both block size and matrix heating rate. This last factor was influenced by matrix size distribution, the bulk heating rate tending to be lower for the broader size range material.

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Tar sand occurrences in the Bush Butte Quadrangle, Wyoming, with emphasis on the Trapper Canyon Deposit

The Trapper Canyon Tar Sand Deposit is located in the eastern Bighorn Basin, approximately 25 miles east of Greybull, Wyoming. This project not only involved detailed geologic mapping of the Trapper Canyon Tar Sand Deposit, but also sampling and describing the tar zone as well as the bounding barren zones. Samples were analyzed for porosity, permeability, oil saturation, and characteristics of the oil. Thin sections from both the tar zone and barren zones were made and examined to determine textural characteristics and kinds of pore-filling cements. In addition, samples were analyzed using the scanning electron microscope to gain insight into the diagenesis of the reservoir rock and trapping mechanisms. The Trapper Canyon Tar Sand Deposit was investigated because it was considered potentially commercial, and the results of the study could aid in forming an economical plan of development for this deposit and similar deposits elsewhere in the State. Also, the area provided an excellent opportunity to examine surface exposures of a tar sand deposit. The final phase of the study involved mapping the Bush Butte quadrangle and looking for additional tar sand deposits in the quadrangle. The search for additional deposits was carried out based on a model developed by examination of the Trapper Canyon Deposit. 16 references, 14 figures, 3 tables.

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Bibliographic data base on trace elements in oil shale and its products

A computerized bibliographic data base has been developed by Western Research Institute for storage and retrieval of literature references pertinent to trace elements in oil shale and its products. It provides a means to assist researchers obtain oil shale trace element literature references in their specific area of interest. Over 500 references have been obtained and evaluated. Three hundred and seventy five of these references have been entered in the data base. They may be retrieved on several combinations of topics. 3 figures.

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Inorganic solute profiles of waters related to Rio Blanco oil shale project retort 1

Water samples were taken from the Rio Blanco oil shale project retort 1 site approximately three- and one-half years after the shutdown of the oil recovery phase. Intermittent flooding and pumpdown of the retort occurred in the interval between shutdown and sampling for this study. Waters from within the retort and from downgradient and offsite locations were compared using a battery of analyses for inorganic and general water quality parameters. Inorganic solute species were selected as potential key indicator species if the particular species concentration inside the retort was greater than that outside the retort. Six inorganic parameters were found to qualify as potential key indicators for retort water migration from the site: potassium, lithium, ammonia, fluoride, thiosulfate, and boron. Except for ammonia, these indicators differ from those selected by other researchers at other modified in situ retorting sites. Ion chromatographic techniques were shown to be applicable for five of the six potential key indicators - all except boron which was detected spectroscopically. Low part-per-billion ion chromatographic analyses were demonstrated for lithium and ammonia. Fractional part-per-million ion chromatographic analyses were demonstrated for potassium and fluoride. Thiosulfate detection limits were in the low part-per-million range and only allowed detection of this indicator inside the retort. Five of the indicators (all except thiosulfate) were detected at slightly elevated levels in the Mahogany Zone ''B''groove completion of the downgradient well. However, insufficient historical baseline data are available at the low detection levels required to allow positive identification of communication between this well and the retort. The potential for enhancement of sensitivity of the ion chromatographic methods beyond that already achieved for the selected indicators is discusses. 11 refs., 1 fig., 9 tabs.

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Plant responses to aqueous effluents derived from in situ fossil fuel processing. I. Development of screening methods. [Effects of oil shale waste water on plant growth and seed germination]

Possible mechanisms for bioeenvironmental contact of aqueous effluents derived from in situ oil shale processing include accidental, episodic exposure resulting from failure of a containment, leakage during transfer or treatment processes, or contamination and subsurface migration of ground waters to a surface outlet. The magnitude of plant responses and phytotoxic effects resulting from such exposure has not been but needs to be quantified for purposes of risk assessment. The development of control technologies for aqueous effluents looks forward to the potential of using suitably treated process waters for land reclamation purposes. A research project to address plant and process water relationships has been developed. The initial objectives of the project are to: (1) develop quantitative, short-term, cost-effective, diagnostic screening procedures for vegetation; (2) using such procedures, to quantitate the response of selected plants to process waters derived from in situ oil shale processing; (3) provide information for developing control technology. Results meeting the first-stated objective are presented. Two screening procedures, a seed germination assay and growth and development response assays, have been developed using an in situ oil shale process water. (ERB)

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Adsorption analysis by displacement techniques - applied to shale-oil distillates

Several applications of the displacement technique for adsorption analysis are described, the analysis of small samples boiling from 200 to 325 Degrees C, and containing olefins and nonhydrocarbon materials; a dilution procedure that aids in the analysis of samples for which the adsorptogram shows a poor separation between adjacent groups of compounds; and a procedure for the separate determination of paraffin's and cycloparaffins using a combination of refractive index and adsorption techniques.

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Using broad-line nuclear magnetic resonance spectrometry to estimate potential oil yields of oil shales

A technique has been developed utilizing proton, bo=road-line nuclear magnetic resonance spectrometry to estimate the organic carbon contents and the potential oil yields of five domestic oil shale's. The quantity of organic hydrogen in the oil shale's is mathematically related to the organic carbon contents and to the potential oil yields so that the proton, broad-line nuclear magnetic resonance signal strength can be correlated with both the Fischer assay oil yield and the organic carbon contents of the oil shale's from the Colorado, Utah, Wyoming, and Kentucky. The experimental data indicate that calibration curves need be determined but once for a limited oil shale area under development. The method is rapid, can be applied without extensive calibration, and gives good estimates of oil yields and organic carbon contents on as many as 30 samples per hour.

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BX in-situ oil-shale project. Quarterly technical progress report, June 1, 1981-August 31, 1981

June 1, 1981-August 31, 1981 was the third consecutive quarter of superheated steam injection at the BX In Situ Oil Shale Project. Injection was continuous except for the period of July 14th to August 1st when the injection was suspended during the drilling of core hole BX-37. During the quarter, 99,760 barrels of water as superheated steam were injected into Project injection wells at an average well head temperature of 752/sup 0/F and an average wellhead pressure of 1312 PSIG. During the same period, 135,469 barrels of fluid were produced from the Project production wells for a produced to injected fluid ratio of 1.36 to 1.0. Net oil production during the quarter was 38 barrels.

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