AndreaBozzo/ceres-open-data-index huggingface dataset:
Stratigraphic variation of oil shale enthalpy of retorting through the Green River formation on the Colorado C-a tract

The importance of mineral enthalpies for oil shale retorting energy requirements has been largely ignored. A differential scanning calorimetry study of 18 alternating rich and relatively lean oil-yield zones from a core from the Colorado C-a tract shows that mineral enthalpies exceed organic enthalpy in each of the 18 zones. In addition, mineral enthalpy variations are greater than the variations produced by the organic contents of oil shales that have potential oil yields from 7.1 to 31.4 gallons per ton oil shale. Oil shale minerals identified in samples for the study are nahcolite, dawsonite, analcime, magnesian siderite, pyrite, dolomite, illite, quartz, and feldspar.

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Study of oil shale by Auger Electron Spectroscopy (AES) and Energy-Dispersive Spectrometry (EDS)

Auger Electron Spectroscopy (AES) and Energy-Dispersive Spectrometry (EDS) were used to examine various oil shales, a spent shale, and a low-temperature ash in order to evaluate the application of these techniques to oil shale research. During preliminary Auger analysis, severe sample charging and electron beam damage were observed, but such effects can be minimized by controlling the instrumental conditions. The organic portion of oil shale appeared to be stable in the ultra-high vacuum system with a base pressure of 10/sup -10/ torr. Analysis of various shale particles indicated that there was a wide variation in the elemental concentrations among particles for all the samples studied. Auger analysis of Israeli and Colorado shales showed a higher concentration of sulfur on the surface as compared to the eastern shales even though the eastern shales were higher in total sulfur. The total sulfur content was also higher in the high-temperature ash of the carbonate-rich shales due to sulfur capture by the carbonates. Elements which were found in high concentration in the bulk were also found in high concentration on the surface. Examples of such elements include calcium in the Israeli and Colorado shales, silicon and iron in the Tennessee shale, and aluminum in the Kentucky oil shale. Sodium was noted on the surface of Colorado shale whereas its peak intensity was very weak for the other shales, despite the similar sodium contents in each of the shales. Vanadium, chlorine, copper, and chronium were detected by EDS and not by AES. Auger depth profile analysis of fresh shale, spent shale, and low-temperature ash indicated that carbon and sulfur were more concentrated on the surface. EDS analysis indicated that some potassium is lost during low-temperature ashing and retorting. 9 refs., 2 figs., 5 tabs.

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In-depth evaluation of LLL's R and D program for the in situ gasification of deep coal seams. [Numerous references]

"The in situ coal-gasification concept of the Lawrence Livermore Laboratory (ILL) has been technically and economically appraised on paper y an industrial team consisting of The Resource Sciences Corporation, Amoco Production Company, E.I. du Pont de Nemours & Co., Inc., Pacific Gas and Electric Company, and Rocky Mountain Energy Company. The evaluation included such considerations as coal-resource assessment: coal-permeability determinations; hydrologic factors; explosive-fracturing technology; drilling programs; site selection; underground reactor design; processing and control; potential water sources and treatment; environmental effects; aboveground processing, including utilities and offsites; and economics.  The economic appraisal of conservative and optimistic cases indicates that pipeline-quality gas produced by in situ coal gasification could compete in price with synthetic natural gas produced by other technologies that are under consideration today. However, technological uncertainties in the areas of explosive fracturing, coal-extraction efficiency, and subsidence control must be eliminated via field testing for this concept to become a viable source of synthetic natural gas from coal."

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Experimental investigation of the steam drive process for the Asphalt Ridge Tar Sands deposit, Utah

A series of laboratory experiments was conducted at the University of Wyoming to determine the steamflood recovery mechanisms for the Asphalt Ridge Tar Sands deposit located near Vernal, Utah. Steam at various temperatures and qualities, hot water and also nitrogen were injected into an adiabatic tube containing the tar sands, and the recovery curves were measured. From the results of the experiments, it was concluded that the Asphalt Ridge steamflood mechanisms consist of viscosity reduction, solvent extraction-enrichment, liquid displacement, and steam distillation. In addition to determining the steamflood mechanisms, it was also shown that, for the Asphalt Ridge Tar Sands steam injection recovered more oil than did a hot waterflood at the same temperature; thick, viscous oil was produced during low quality steam runs, whereas a lighter oil was produced at higher qualities; and intermediate quality steam will recover more of the original oil in place than will either high quality steam or hot water.

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A correlation of United States tar sand bitumen viscosities with NMR spectroscopic parameters

A method has been developed whereby the viscosity of a tar sand bitumen at any temperature can be calculated from nuclear magnetic resonance parameters. The method is semiempirical but is based upon some fundamental theoretical concepts for molecular mobility and intermolecular interactions. Using this method, the viscosities of three United States tar sand bitumens have been correlated to the weighted average spin-spin relaxation rates for the semiliquid, solidlike mobile, and solidlike rigid phases of the bitumens. The results indicate that bitumens with a high viscosity have a greater amount of solidlike rigid phase and lesser amounts of solidlike mobile and semiliquid phases than do the bitumens with low viscosity. It is also shown that the viscosity of a tar sand bitumen over a 100 degree temperature range can be determined from a single NMR experiment conducted near room temperature. 18 refs., 3 figs., 4 tabs.

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Compaction and related properties of retorted oil shale

As part of a project to demonstrate the feasibility of retorting oil shale by the Paraho vertical retort process, laboratory and field tests were performed to determine the physical and chemical properties of retorted oil shale for use as criteria for the design of full scale disposal systems. The material which exits from the retort is classified as a non-plastic silty gravel. The material can be compacted to about 90 to over 100 pcf (1,440 to 1,600 kg/m/sup 3/) depending upon the degree of compactive effort applied. The addition of moisture from the dry state does not improve densification appreciably. When moistened to about optimum moisture and highly compacted, the material is classed as impervious and the material gains strength with time from cementing action. The retorted shale, so treated, can be used to construct stable, impervious retaining structures and impervious linings in valleys for holding the main disposal deposit and provide ground water protection.

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Analysis of stack gas pollutants produced by in situ combustion of oil shale:  a preliminary report from Rock Springs Site 12. [Side-burn experiment]

Monitoring of the in situ oil shale project at Rock Springs, Wyoming, Site 12 was attempted on a sideburn experiment prior to ignition of the main experiment. Although this monitoring would not be entirely representative of a mainburn experiment, it was felt that the results could act as guidelines for our mainburn monitoring effort. This presents the results of the sideburn monitoring effort and discusses some of the problems which were encountered.

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Oil shale oxidation at subretorting temperatures

Green River oil shale was air oxidized at subretorting temperatures. Off gases consisting of nitrogen, oxygen, carbon monoxide, carbon dioxide, and water were monitored and quantitatively determined. A mathematical model of the oxidation reactions based on a shrinking core model has been developed. This model incorporates the chemical reaction of oxygen and the organic material in the oil shale as well as the diffusivity of the oxygen into the shale particle. Diffusivity appears to be rate limiting for the oxidation. Arrhenius type equations, which include a term for oil shale grade, have been derived for both the chemical reaction and the diffusivity.

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Underground oil shale retorting. [Basic principles are outlined]

The basic principles involved in combustion processing of oil shale are outlined. The manual is designed to serve as an introduction to the subject for the support personnel of the LLL Oil Shale Project. The material is presented in a simple two page format with one page devoted to a figure or table and the facing page contains a brief description of that material. Thus, it can serve as a self-study guide. Following a brief description of oil shale, how it was formed, and the extent of the resource, an overview of the concepts and major technical problems of Modified In-Situ (MIS) Oil Shale Retorting is presented. Finally, the liquid product, shale oil, is compared with typical petroleum crudes.

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Synthesis, properties, and identification of sulfur compounds in petroleum:  a report on API research project 48

The formidable problems caused by the presence of sulfur compounds in petroleum, aggravated by the increasing rate of high sulfur crude production, led to the formation in 1948 of API Research Project 48.  This project has as it objective the identification and measurement of sulfur compounds in petroleum and the obtaining of fundamental information concerning the physical properties, thermodynamic properties and other characteristics of synthesized sulfur compounds.  To accomplish these objectives, it is necessary to develop suitable experimental methods and synthetic procedures.

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API research project 52:  nitrogen constituents in petroleum

A study of the fundamental chemistry of nitrogen compounds, especially from the standpoint of developing separation processes which may be used to isolate individual compounds or groups of compounds, will be made by Project 52a at the University of Kansas. Further work of this section will include the development of methods of synthesis for nitrogen compounds. Separation of nitrogen compounds from a Wilmington, Calif., crude oil will be one of the first operations of Project 52b at the U.S. Bureau of Mines at Laramie. In addition, the preparation of highly purified nitrogen compounds for calibration standards and for the determination of physical and spectral properties will be done by this group. Highly specialized measurements of the thermodynamic properties of the pure nitrogen compounds will be made by Project 52c at the U.S. Bureau of Mines at Bartlesville. These data will be used to calculate the heats and free energies of formation of these compounds. As the store of fundamental information on the occurrence and properties of the nitrogen compounds in petroleum increases, industry will have the tools to make significant progress toward solving problems of catalyst poisoning, product instability, and fuel deposits, as well as progress toward the goal of learning how petroleum is formed.

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Impact of geologic parameters on enhanced oil recovery - workshop proceedings

The purpose of this workshop is to identify and develop objectives for future geologic research needed to increase light oil production with the enhanced oil recovery processes and to identify quantitative studies with potential to predict the impact reservoir heterogeneities on the light oil recovery processes. With these goals in mind, four workshop groups were organized to discuss and develop a conceptual R and D program to minimize the geologic constraints to E.O.R. These workshop groups will provide guidance and input into DOE's light oil research program and will help decide where time and resources are most effectively utilized. Working groups studied: (1) rock-fluid interactions; (2) reservoir heterogeneity; (3) reservoir description; and (4) geologic imput into EOR simulation studies. The question addressed is whether the present technology is adequate to quantitatively define each of these areas for predictive uses. If it is not, what techniques and instrumentation is necessary to define these for each EOR process.

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Metals distribution in shale oil fractions

A description is given of a study conducted by the Laramie Energy Technology Center of the U.S. Dept of Energy, to determine the metals distribution in shale oil and shale oil fractions. The shale oil was produced from the Rock Springs Site number 9 field test and was fractionated by distillation. The shale oil fractions (oils, naphtha, light distillates, heavy distillates, and the residuum) were all digested for atomic absorption analysis. Flame and graphite furnace techniques were used to determine the distribution of the alkali earths and the transition metals in the shale oil and fractions. 13 refs.

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Carbonization of semi-anthracitic vitrinite by an analcime basanite sill

The sill is an analcine basanite with phenocrysts of labradorite, two clinopyroxenes, and olivine. The coal is from a bore drilled in the Dirty seam of the Baralaba Coal Measures in the Bowen Basin, Queensland. The intrusive rock was penetrated in the bore from 1514 to 1532 /sup 1///sub 2/ ft depth, directly below the Dirty seam. The phenocrysts in the narrow chilled margins indicate a temperature of intrusion of not more than 1160/sup 0/C. The coal was metamorphosed from semi-anthracite (92% C) to anthracite, meta-anthracite (97% C), and vesicular natural coke towards the contact. The vitrinite shows a progressive increase in mean maximum reflectance from 2 to 12%. Particularly in the meta-anthracites, two distinct types of vitrinite can be distinguished on the basis of reflectance. These are considered to express the different behaviour on carbonization of Vitrinite A and Vitrinite B.

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Status of instrumentation and process control techniques for in situ coal gasification

"In situ gasification of coal is under development as a means of energy extraction from coal resources. In situ coal gasification has enjoyed limited economic success due to process control difficulties; the problem being extreme variability in gas production and caloric content. The Laramie Energy Research Center is presently conducting field tests of underground gasification; in support, Sandia Laboratories is investigation instrumentation and process control techniques.  The Hanna I experiment achieved sustained production of 1.6 million cubic feet per day of a 125 Btu/acf gas. The Hanna II experiment is underway. Experiment phases include: assessment of linkage techniques, efficiency of gasification, and control of a line drive sweep. Extensive in situ diagnostic instrumentation has been emplaced to monitor the experiments. Remote process monitoring techniques are being evaluated.  The status of in situ coal gasification will be reviewed. The instrumentation plan for Hanna II will be presented. Measurement data from Phase I of Hanna II will be discussed."

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Activated carbon adsorption of ground water contaminants from in-situ coal gasification

Previous work has demonstrated the feasibility of adsorbing organic chemicals from aqueous solutions using activated carbon as the adsorbent. These tests were carried out to evaluate the adsorbability of mixed organic contaminants found in ground waters adjacent to in-situ coal gasification sites. Information generated from these tests will be used to determine the feasibility of testing the regeneration or disposal of spent powdered activated carbon and to design an above ground activated carbon treatment system.

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Determination of process yield for oil shale retorting using oil analysis using capillary column chromotography

A method is described for determining the oil yield from a combustion retort using only the capillary column chromotogram of the oil. The heating rate and/or retorting temperature and the resulting yield loss by oil coking is determined from the 1-alkene/n-alkane ratios. The amount of combustion and associated cracking is determined from naphthalene/straight-chain hydrocarbon ratios. The utility of this method is demonstrated using oil samples from several large-scale retorting operations. The possibility of using the oil mist from an in-situ retort for an on-line determination of the current retort performance is discussed.

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Environmental survey - tar sands in situ processing research program (Vernal, Uintah County, Utah). [Reverse-forward combustion; steam injection]

Research will be done on the reverse-forward combustion and steam injection for the in-situ recovery of oil from tar sands. This environmental survey will serve as a guideline for the consideration of environmental consequences of such research. It covers the construction phase, operational phase, description of the environment, potential impacts and mitigations, coordination, and alternatives. (DLC)

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Pacific Project, Garfield County, Colorado, Phase 1. Project data book mine and related facilities - Task 8b, 8d. Volume 2. Project definition

Contents of Volume II are: (1) general which includes flow diagrams, plot plans and elevations, major alternatives and expansion considerations; (2) mine covering system description, mine design basis, preproduction development, mining operations, crushing screening and conveying, and mine production; (3) mine service; (40 raw shale fines and retorted shale disposal; (5) abandonment plan; (6) belt conveyors; (7) equipment list; (8) critical spare parts; (9) drawing list; (10) design and engineering calculations; and (11) vendors equipment data. 9 figs.

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Mineral reactions during high temperature oil shale processing

The important mineral reactions which take place during high temperature oil shale processing are identified and discussed. Kinetic measurements of carbonate mineral decomposition are presented for six different oil shales, including the reversible nature of calcite decomposition. It is concluded that ankeritic dolomite decomposition can be prevented by relatively low over-pressures of CO/sub 2/ up to temperatures of 925 K for dolomites which are closer to ankerite. The catalytic properties of mineral decomposition products (CaO and Na/sub 2/O) relative to char combustion are presented and attributed to their chemisorption properties. Chemisorption phenomena was also found to be important during the recarbonation of CaO to CaCO/sub 3/.

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A fluidized bed--thermal pyrolysis process for the recovery of a bitumen-derived liquid from the bitumen-impregnated sandstone deposits of Utah

The bitumen-impregnated sandstone deposits of Utah are estimated to contain a minimum of 25 billion barrels of oil in place in six major deposits and are the largest known hydrocarbon resource of this type in the United States. The deposits of the Utah Basin are of fresh water origin with bitumen concentrations that range from 4 to 12 percent by weight and contain less than 0.5 to 1.0 percent by weight sulfur. The deposits in southeastern Utah are of marine origin with bitumen concentrations of 4 to 5 percent by weight and contain 4 to 6 percent by weight sulfur. The Sunnyside (fresh water origin) and Tar Sand Triangle (marine origin) were processed in an aboveground, fluidized bed thermal recovery process. The experimental data were obtained in the temperature range 675 K to 900 K at solids retention times in the range 20 to 32 minutes. The light gas and bitumen-derived liquid yields were quite dependent upon the pyrolysis temperature and the solids retention time in the pyrolysis reactor. The amount of bitumen converted to coke on the sand was relatively insensitive to the process operating conditions, the sand particle size, the origin of the sand or the amount of bitumen on the fresh sand. The maximum liquid yield with the bitumen-impregnated sand from the Sunnyside deposit was 70 percent by weight of the bitumen fed to the reactor, was obtained at 773 K and a solids retention time of 20.4 minutes for a feed particle size of 358.5 microns. The maximum liquid yield with sand from the Tar Sand Triangle deposit was 50 percent by weight, was obtained at 798 K and a solids retention time of 27.2 minutes for a feed particle size of 358.5 microns. The liquid yield increased with decreasing sand retention time and it appears 80 percent of the bitumen can be converted to a pipelineable liquid product at sand retention times below 20 minutes.

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Volumetric heating of oil shales by electromagnetic methods. Volume 6. Heat conduction in heterogeneous media and volumetric heating of oil shales by electromagnetic methods

The problem of volumetric heating of oil shales by electromagnetic methods and the effects of layering on heat conduction in oil shales are studied theoretically. This study includes both a detailed examination of heat conduction in composite media, and the development of a numerical model to describe the heating process. A new solution to a heat conduction equation in heterogenous materials is developed which includes both the effects of inclusions and contact resistance. The solution is presented in terms of the associated Green function and numerical results are displayed. A new solution to the heat conduction equation is presented for materials which consist of constituents whose thermal properties vary in a discontinuous manner. This solution is also presented in terms of a Green function and an iteration technique is developed to solve the related eigenfunction problem. Numerical results are exhibited for heat flow in layered materials. A two dimensional numerical model which describes electromagnetic heating of oil shales is developed which 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 organic materials. Calibration of the model is accomplished by comparison of the model results with experimental data obtained by IITRI. 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. Numerical results are included and a preliminary study of the optimization of the heating process is presented. 44 refs., 63 figs.

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