AndreaBozzo/ceres-open-data-index huggingface dataset:
User information manual. SUBSID:  a nonlinear, two dimensional finite element program for static evaluation of mining subsidence

In modified in-situ (MIS) oil shale retorting, large chambers of rubblized oil shale are formed by mining out about 20% to 40% of the in-place shale and blasting the balance into the created void. The mined-out material is brought to the surface and oil is recovered from it by surface retorting. The in-place material is pyrolyzed to recover oil, leaving large numbers of abandoned retort chambers underground. This type of oil shale processing may result in a number of environmental problems, including in-situ leaching of the abandoned retorts, low resource recovery (large pillars are required to support the overburden), and subsidence. These problems may be mitigated by filling abandoned retorts with a grout that would fill the void space, thus improving retort structural strength and stiffness, and reducing retort permeability to groundwater flow. If sufficient strength and stiffness can be developed, it may be possible to design retorts so that the pillars can be retorted and resource recovery improved. This document describes a computer program that was developed and used to evaluate the strength and stiffness required in a grouted retort to support the overburden and to improve resource recovery. The program SUBSID was developed to predict subsidence over a field of MIS retorts under various conditions of retort backfill. Where subsidence must be prevented or limited, backfilling retorts can permit retort design with a higher extraction ratio than would otherwise be possible. SUBSID can be used to relate the desired increase in extraction ratio to the required structural properties of the retorts after backfilling, thus allowing costs and benfits to be balanced against each other.

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Thermal recovery of oil from tar sands by an energy-efficient process

A total of 75 runs was made under thermal processing conditions at near-ambient pressure with tar sands from three different deposits: Tar Sand Triangle, Sunnyside, and Asphalt Ridge. Data from representatives runs for feed materials from each of the three deposits are given. A complete accounting of all the bitumen in the feed material was not achieved because of difficulties in removing oil product from the product recovery equipment. Thus, values reported for oil yield are believed to be low. Based on the best runs, it is estimated that for Sunnyside and Asphalt Ridge materials, a typical yield structure for near-optimal operating conditions would be: 70 wt % oil, 10 wt % gas, and 20 wt % coke. Conclusions from this study are: the basic concept of a thermal process using pyrolysis and combustion stages coupled by heat pipes is workable and eliminates the need to recycle large amounts of sand; tar sands containing as low as 8% bitumen can be thermally processed without external energy input to get satisfactory yields of oil; and tar sand with even lower bitumen content can be processed with good oil yield if a portion of the gas or oil products or some cheaper external fuel, such as coal, can be added to the combustion stage to provide energy; modifications of the process, such as introducing recycle of gas and oil, allowing for purge of some combustion gas, etc., can improve the energy efficiency of the process and the yields of oil and gas; and  the process developed during the course of this work is simple, direct, and efficient. It is capable of wide application to processing of tar sands in Utah, Canada, and perhaps other deposits. The concept of using heat pipes is of even broader applicability in the process industries in general and in energy-related industries in particular. The basic processing concepts investigated here may have potential for application in the processing of oil shale and coal.

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Results of a groundwater quality study near an underground coal gasification experiment (Hoe Creek I)

Groundwater sampling and analysis have been carried out at the site of an underground coal gasification experiment conducted by the Lawrence Livermore Laboratory near Gillette, Wyoming. Water from more than 12 wells in the vicinity of the experiment has been sampled before, during, and up to 10 months following gasification. Water samples were analyzed for a variety of characteristics, including the presence of 70 inorganic compounds and elements, phenolic materials, and volatile and semi-volatile organics. We find a greatly increased concentration of organic materials, particularly phenols, just outside the burn boundary and a variety of inorganic species issuing from within the residual ash bed. All detectable contaminants rapidly decreased in concentration with distance, although above-background levels of some species were detected 100 ft from the burn zone. Several important contaminants showed a large decrease in concentration with time due, probably, to absorption. From these data a simple physical picture is generated of the time-development of groundwater pollution near an underground coal gasifier.

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Plant response to aqueous effluents derived from in-situ fossil-fuel processing. Part I. Eight plant species and their response to Omega 9 oil-shale retort water. [Wildrye; wheatgrass; alkali sacaton; sandreed; pointvetch]

Growth response to water collected from an in situ oil shale retort experiment was studied. The purposes were to: (1) evaluate effect of retort water on plants; (2) document effective parameters for detecting differences in plant growth by species. A self feeding hydroponic system was utilized to subject different dilutions of oil shale retort water to plants grown in horticulture grade perlite under greenhouse conditions for 10 weeks. Parameters measured included: (1) leaf area, (2) total dry weight, (3) shoot weight, (4) root weight, (5) root/shoot ratio, and (6) shoot/leaf area ratio. Seven grass and one forb species were utilized as test plants. Results showed growth to be impaired, species to respond differently to retort water, and parameters measured to vary as to their ability to detect change in growth response.

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The /sup 1/H CRAMPS (combined rotation and multiple-pulse spectrometry) NMR investigation of the organic surface composition and organic mineral interactions of chemically and thermally treated asphalt ridge tar sand: Final topical report

An exploratory investigation was conducted using the advanced NMR technique CRAMPS (combined rotation and multiple-pulse spectrometry) to provide information on the types of organic functionality via hydrogen types present on the surface of tar sand residues. The solvents hexane, toluene, and methylene chloride were used to extract the bitumen from the native tar sand. All three solvents removed essentially all of the bitumen from the mineral matrix. However, the solid-state /sup 1/H NMR and diffuse reflectance infrared have shown the presence of a small amount of organic material still in contact with the mineral matrix. Tar sand residues after extraction with methylene chloride contain less organic material than the tar sand residues obtained after solvent extraction with hexane. The hydrogen spectra of the residues show a greater amount of aromatic hydrogens than aliphatic hydrogens. Of interest were the relatively large amounts of hydrogen caused by (1) alkyl hydrogens adjacent to ketone carbonyl functionality, (2) hydrogens of methylene groups bridged between aromatic rings, and/or (3) hydrogens of methyl and ethyl substituents on aromatic rings. The infrared data on the extracted tar sand residue also show a relatively large amount of ketone functionality. The spectra of the residues obtained from the isothermal and nonisothermal pyrolysis of the native tar sand show that a relatively large amount of bitumen still remains with the mineral matrix even at a temperature of 380/degree/C (716/degree/F). Above 400/degree/C (752/degree/F) the /sup 1/H spectra changed dramatically but still do not have the /sup 1/H resolution that was apparent in the spectra of the tar sand residues from solvent extraction. The major change in the /sup 1/H spectra of the tar sand residues after pyrolysis above 400/degree/C was the loss of paraffinic hydrogens. 75 refs., 10 figs., 2 tabs.

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Oil shale process water evaporation

The primary objectives of this research program were to study chemical, microclimatological, and interactive effects on the evaporation of low-quality oil shale process wastewaters to develop more applicable evaporation models and evaporation design criteria for the disposal of oil shale process waters and to analyze the processes associated with the release of potentially toxic emissions from these low-quality effluents. The research program incorporated field and laboratory studies analyzing microclimatic and chemical effects on the evaporation of oil shale process wastewaters. Field studies at Laramie, Wyoming were designed to continuously monitor microclimatological conditions and the evaporation from three low-quality effluents using Class A evaporation pans. Fresh water evaporation was monitored as a control. Process waters were routinely monitored for concentrations of organic and inorganic constituents. Laboratory studies were designed to isolate and describe significant climatic, chemical, and interactive effects on evaporation rates. Results from the above studies were utilized to develop a regression model to predict evaporation from these low quality effluents. This model was then compared to commonly utilized models to estimate evaporation. A stochastic model was developed using a first order markov process to generate 1000 20-year climatological records. Mass balance techniques were then used to evaluate the new data sets for evaporation processes and determine critical design parameters for evaporation disposal ponds. Laboratory studies were conducted to determine significant effects on the Henry's Law Constant for eight organic compounds in two process waters. 69 refs., 16 figs., 51 tabs.

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Lawrence Livermore National Laboratory oil shale project. Quarterly report, July-September 1980

Settling bed oil shale retorts can be operated on a small scale without internal equipment (such as air distributors) provided that there are sufficient instruments and controls to determine what is happening in the retort, permitting adjustment of the various flow rates. Variation of retorting rate from 38 to 73 m/d had little effect upon the oil yield or properties. Decreasing the air content of the feed gas reduces retorting temperatures and heating rates, which results in less mineral carbonate decomposition, less organic char reaction, lower oil pour points and lower oil viscosities. Problems in solids flow occur using finer shale particles, due presumably to excessive oil holdup and coking.

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Integrated plan for off-gas environmental control technology research and development in in-situ oil shale retorting

The following major observations were made in the study. The gas stream from modified in-situ (MIS) retorting of oil shale has a very low heating value, approximately 40 to 60 Btu/SCR. Sulfur appears in the gas primarily as H/sub 2/S, at a concentration of around 700 to 1400 ppMv, dry basis. The primary candidates for control of sulfur emissions from MIS retorting are direct liquid-phase oxidation ot elemental sulfur (the Stretford process), or combustion of the gas followed by flue gas desulfurization (FGD) to remove the sulfur oxides. Selective acid gas removal followed by Claus sulfur recovery does not appear to be a viable sulfur emission control process for MIS retorting, as it may be for some above-ground retorting processes. A better use of liquid acid gas removal solvents appears to be that of non-selective amines to remove both H/sub 2/S and CO/sub 2/ from the gas. The acid gas is sent through a Stretford unit smaller than would be required on the primary gas stream, and upgrades the heating value of the primary gas stream itself, raising the theoretical combustion temperature and reducing ancillary fuel requirements. An overall research plan for environmental aspects of in-situ retorting has been developed and is described in this report. Gas stream controls can be investigated as part of this plan. The specific sulfur control program proposed for OXY's proposed Retorts 7 and 8 at Logan Wash involves installation and testing of skid-mounted units on a slip-stream of retort gas. Units proposed are: (1) Stretford, (2) Incineration with SO/sub 2/ Scrubbing, (3) Non-selective Acid Gas Removal, (4) Molecular Sieves with upgraded particulate removal ahead of the sieves. Including EPA's furnishing of a skid-mounted SO/sub 2/ Scrubbing test unit, the preliminary estimated order-of-magnitude investment for this program is about $1.8 million, versus $3.0 million for a full-flow Stretford unit.

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Development of the Bureau of Mines gas-combustion oil-shale retorting process

Results are presented from research and development carried out by the Bureau of Mines on the gas-combustion oil-shale retorting process. Effects of the process variables, results of gas and shale distribution studies, tests on shale particle size, and other details of experimental programs are discussed. Various auxiliary information and problems associated with the retorting process also are included. Tabulations of the retorting test data and detailed oil recovery flow diagrams for the 6-, 25-, and 150-ton/day retorts, and drawings relating to retorting equipment are given.

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Meteorological and climatological investigation:  review of January-June 1979

The specific goals of the meteorological and climatological investigations on the Geokinetics Incorporated (GKI) field research site in Uintah County, Utah, are to collect, reduce and analyze meteorological and microclimatological data for the purpose of: (1) obtaining knowledge of the structure and flexibility of the local microclimate; (2) evaluating any trends associated with the locale; and (3) monitoring for project induced changes in the local microclimate. These goals, while functionally discrete, are to be treated as a whole in this and all subsequent reports as data and interpretations become available. The findings summarized reflect the results of the collection, reduction and analysis of raw data acquired from January 01, 1979 through June 30, 1979.

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Resource assessment naval oil shale reserve No. 1

Resource data were obtained from coreholes drilled between 1945 and 1978 on NOSR-1 and on surrounding private lands owned by Mobil Oil Company, Union Oil Company, and Colony Development Operation. The data consist of modified Fischer assay results from 24 cores on NOSR-1 and 21 cores on the private lands. The raw data were stored in the computer data bank for processing and are included as oil-yield histograms in Appendix A and as a data-file listing in Appendix B. Data from eight of the private coreholes used in this study are classified as proprietary and are therefore not included. Core logs and geologic reports for the three coreholes drilled on NOSR-1 in August and September, 1978, are provided as Appendix E. Brief descriptions are presented of the physiography, stratigraphy, structural geology, and resources of the Piceance Creek basin and the NOSR-1 area. All assay data were computer processed, utilizing Tosco and US Geological Survey programs, to determine oil shale resources and reserves. Resource values were computed for average oil shale grades, and isoresource contour maps were computer plotted. Eleven conceptual mine cases were studied and from these five scenarios were selected as best meeting resource and engineering requirements.

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Unconventional petroleum resources in California

The distribution, physical characteristics, and potential of some of the more significant unconventional deposits in California are described in this report: diatomaceous oil shale in southern San Joaquin Valley and Casmalia area-Santa Barbara County; oil and tar sands in Oxnard oil field, Arroyo Grande, Santa Maria Valley, Sisquoc area, Salinas Valley, Richfield tar sand; and minor deposits in Santa Cruz County, Point Arena area-Mendocino County, and McKittrick tar sands. (DLC)

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Tar sands permeability enhancement:  proceedings of a 1980 workshop

A workshop was held on 8 and 9 May 1980 to identify problems in the enhancement of the permeability of tar sands. The first day was devoted to a series of review papers of current methods of permeability enhancement being applied to other hydrocarbon-bearing resources. The second day's round-table discussion was restricted to tar sands permeability enhancement, with only a brief discussion of recovery processes. It was concluded that the use of standard commercial explosives was not productive. A slow-burning propellant delivering a tailored pulse would require careful study before being useful. Problems were seen with hole completion and stability if directional drilling techniques are used. The most promising approach appears to be hydraulic fracturing. Considerable effort needs to be devoted to understanding fracture behavior in cohensionless tar sands. Separate abstracts were prepared for seven of the ten papers; the remaining three had been previously abstracted. (DLC)

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Oil shale project:  run summary for small retort Run S-11

Results are reported on retort run S-11 conducted to observe the effects of combustion retorting with undiluted air at relatively rapid burn (retorting) rates and to provide a base case for retorting small uniform shale (Anvil Points master batch -2.5  - 1.3 cm) with undiluted air. It was found that a 0.6 m/sup 3//m/sup 2//minute superficial gas velocity gave an average rate of propagation of the combustion peak of about 2.7 m/day and an average maximum temperature on the centerline of the rubble bed of 1003/sup 0/C. Oil yield was 93 percent of Fischer assay. For small uniform shale particles (-2.5   1.3 cm) it is concluded that only small losses in yield (92 percent vs 96 percent in Run S-10) result from high retorting rates. Maximum temperature considerations preclude going to higher rates with undiluted air. Without diluent, a larger air flux would give excessive bed temperatures causing rock melting and potential closure to gas flow. In experimental retorts, another problem of excessive temperatures is potential damage to metal walls and in-situ sensors. No advantage is seen to using recycled off-gas as a combustion gas diluent. Inert diluents (e.g. nitrogen or steam) may be necessary for process control, but the fuel values in the off-gas should best be used for energy recovery rather than burned in the retort during recycle. Another consideration from model calculations is that the use of recycle gas containing fuel components retards the retorting rate and so is undesirable. No further recycle experiments are planned as the results of this run proved satisfactory.

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Shale oil upgrading: effect of catalytic hydrotreatment on nitrogen compound types

In this study nitrogen compound-type distributions in shale oils produced by direct retorting (direct-heat mode) and hydroretorting of eastern and western US oil shales were determined by characterization techniques. Differences in the distribution of nitrogen types in catalytic hydrotreated oils and in the retorted oils provided information as to relative hydrodenitrogenation reactivities of different nitrogen types under hydrotreating conditions. A method for predicting the extent of catalytic hydrotreatment as a function of the nitrogen-type composition in the retorted shale oil is presented.

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UCG (underground coal gasification) contaminant control program: simulation of post-burn UCG contaminant production. Final report, October 1986-September 1987

This report presents the results of laboratory and modeling research directed towards minimizing the adverse impact of UCG on local ground-water quality. The Clean Cavern Concept was investigated using laboratory reactor simulations. Operating recommendations for UCG field testing were made based upon the results of the laboratory and numerical analyses of the simulations. The results of the research indicate that the adverse impact of UCG on local ground-water quality can be substantially reduced by following simple low-cost operating procedures when gasification of the coal has ended and by minimizing gas lost during gasification. Steam flushing of the hot UCG cavity immediately after gasification and sustained venting of the UCG cavity as it cools are the operating procedures recommended.

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BX In Situ Oil Shale Project. Annual technical progress report, March 1, 1978-February 28, 1979 and quarterly technical progress report, December 1, 1978-February 28, 1979

Februrary 28, 1979 marks the end of the second year of work on the Bx In Situ Oil Shale Project. Work accomplished during the year included the drilling and testing of all project injection and production wells; the installation and construction of project surface facilities the installaation and construcion of laboratory research equiptment and the implementation of an environmental monitoring plan at the Project site.

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Degradation of (carbonates in) oil shale by sulfur-oxidizing bacteria

Degradation of carbonates in oil shale by sulfur-oxidizing bacteria can solubilize about 40 percent of the oil shale. Thiobacillus thiooxidans and Thiobacillus concretivorus are equally effective. Continuous leaching experiments show that this process can be completed within 14 days. The growth of Thiobacillus and the production of acid were measured under several conditions. Almost all of the calcium magnesium carbonate was removed by this process, leaving a complex of silica and kerogen that could be burned as low-energy fuel. The silica-kerogen complex had not yet been biologically degraded.

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Effects of space velocity on quality and quantity of gas from oil shale retorting

The effects of gas injection rate, water injection rate, and retort pressure on offgas quality and quantity were studied using a small laboratory retort. There are interactions between these variables and oxygen injection and oil shale grade which affect total energy recovery, oil recovery, and energy content of the offgas. Prediction equations were developed describing the effects of these interactions. The study shows that with a low gas injection rate of 0.5 scfm/ft2 at 100 psig with a water injection rate of 0.0201 lb/ft2-min 50 percent of the potential oil revovery can be obtained together with 250 btu/ft3 gas.

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