AndreaBozzo/ceres-open-data-index huggingface dataset:
Selective dissolution and characterization of trace elements in hydrated and recarbonated retorted oil shale

A laboratory study was conducted at the Western Research Institute to evaluate the influence of hydration and recarbonation on the solid phase distribution of trace elements in retorted oil shale. The oil shale samples were retorted by the Paraho direct heating process and equilibrated in the laboratory under controlled carbon dioxide conditions. A sequential extraction technique was then used to fractionate trace elements into soluble, KNO/sub 3/-extractable, H/sub 2/O-extractable, NaOH-extractable, EDTA-extractable, HNO/sub 3/-extractable, and residual (nonextractable) phases. This procedure is purported to identify trace elements that reside in the soluble, easily exchangeable, adsorbed, organic, carbonate, sulfide, and silicate phases, respectively. The chemical fractions present in retorted oil shale and hydrated and recarbonated retorted oil shale are compared to identify trace element mineralogical changes that may occur in retorted oil shale disposal environments. The trace elements examined in this study included barium, cobalt, chromium, copper, lithium, manganese, molybdenum, nickel, lead, antimony, strontium, vanadium, and zinc. The extractabilities of the major elements - aluminum, calcium, iron, magnesium, and silicon - were also examined to provide evidence of solid phase elemental associations with trace elements. A significant result of this study is that the mineralogical residencies of trace elements in retorted oil shale were altered in response to hydration and recarbonation. Thus, the behavior of trace elements in retorted oil shale disposal environments may not be adequately predicted through the application of extraction procedures that assess potential trace element leachability. The results of this study also justify the further characterization of trace element selective extractabilities using procedures that partition trace elements residing in the HNO/sub 3/-extractable and residual fractions. 21 refs., 16 figs., 3 tabs.

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Contaminant control in hot coal derived gas streams:  proceedings

The purpose of this meeting was to provide a forum for the exchange of information based on presentations reflecting recent progress in the technology development, device and instrumentation testing. The sessions focused on where Pressurized Fluidized Bed Combustion and Coal Gasification Systems are, where they are going, and the role cleanup technology does and will play so as to place the work in perspective. A panel discussion and an open forum were held on Wednesday evening to explore formation and control of alkali compounds in pressurized fluidized bed combustion systems. All papers (24 total) have been processed for inclusion in the Energy Data Base.

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Low-rank coal study. Volume 5. RD and D program evaluation

A national program is recommended for research, development, and demonstration (RD and D) of improved technologies for the environmentally acceptable use of low-rank coals. RD and D project recommendations are outlined in all applicable technology areas, including extraction, transportation, preparation, handling and storage, conventional combustion and environmental control technology, fluidized bed combustion, gasification, liquefaction, and pyrolysis. Basic research topics are identified separately, as well as a series of crosscutting research activities addressing environmental, economic, and regulatory issues. The recommended RD and D activities are classified into Priority I and Priority II categories, reflecting their relative urgency and potential impact on the advancement of low-rank coal development. Summaries of ongoing research projects on low-rank coals in the US are presented in an Appendix, and the relationships of these ongoing efforts to the recommended RD and D program are discussed.

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One-dimensional, three-phase multicomponent numerical simulation of underground coal gasification

In this report we present the modeling of the process of underground coal gasification in case of a permeable, porous coal bed. In our earlier reports, we have modeled the gasification process by stream method. In all of the previous reports we assumed that the coal bed consists of 100% carbon. In this simulator, it is assumed that the coal may consist of ash and tar and may produce gases (CO/sub 2/, CO, H/sub 2/O, H/sub 2/ and CH/sub 4/) as a result of pyrolysis. The numerical simulator was written in FORTRAN IV. The mathematical formulation consists of thirteen equations containing thirteen unknown variables. The equations were divided into three different groups. The equations in each group were solved simultaneously. This program is the result of several other programs written in the early stages of this investigation. All the programs written earlier were rejected because of the development of instability at the last node of the coal bed. This was very dominating in the energy balance equation. To avoid this two solution approaches for the energy equation were used, one by back substitution, the other by direct solving of the energy equation, once the pressure of the system is determined.

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Conversion of solvent refined lignite into premium liquid fuels. Annual report, January-December, 1980

Comparison of three preasphaltene samples separated from three lignite derived samples obtained from GFETC prepared at 404, 460 and 480/sup 0/C shows that increased temperature tends to produce higher molecular weight preasphaltene fractions containing more aromatic carbons with fewer acid (phenolic) sites per molecule. Ether cleavage studies of the model compounds; diphenyl ether, bibenzothiophene, dibenzofuran and anisole, show that partial or complete ether cleavage was obtained with sodium in hexamethyl phosphoramide solvent. Thus a careful consideration of acidity before and after cleavage can now give a measure of the diaryl ether content of a mixture. This reaction may be useful in coal liquid analysis. Denitrification of N,N-Dimethylamine without aromatic ring reduction occurs with CO-H/sub 2/O and H/sub 2/ at 425/sup 0/C in about 13% conversion. The optimum of 21 conditions gave a 19% conversion which occurs at 150 psi H/sub 2/S and 750 psi H/sub 2/. Thus, H/sub 2/S enhances nitrogen removal from this model compound. Using ESR dispersion techniques we have shown the presence of a second CO radical species on MgO, probably CO-.. observed by ESR, treatment of carbon monoxide radical species on both CO and MgO with CO/sub 2/ or H/sub 2/O causes a destruction of one of the radical species at a rate greater than that of the other.

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Determination of valuable metals in liquefaction-process residues. Final report

Feed coals, corresponding solid residues, and 18 sample sets representing the SRC, H-Coal, Synthoil, Lignite, Clean Coke, and COED liquefaction processes were investigated chemically, mineralogicaly, and petrographically. The data were evaluated from an economic viewpoint. Most of the 71 elements determined chemically, with the exception of Hg, As, B, S, Ti, Mg, and N, are generally retained in the residues. X-ray diffraction and electron microscopy analyses indicated that most mineral species remain unchanged during the liquefaction process. Mineralogical changes observed included the conversion of pyrite to pyrrhotite, the probable formation of metakolinite from kaolinite, and the collapse of some expandable clay minerals to a 10 A basal spacing. Microscopy of selected samples indicated that small amounts of solid organic particles, mostly vitroplast, are left in the residues. The chemical and mineralogical data, in conjunction with certain economic criteria, were utilized in a hypothetical economic evaluation of the minerals present in the residues as possible secondary sources for some metals. On the basis of 50 million tons of coal conversion, the value of 17 economically and strategically important metals was calculated, of which Al, V, and Ge were the most important.

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Modeling and optimizing surfactant structure to improve oil recovery by chemical flooding at the University of Texas: First annual report for the period October 1985-September 1986. [Sodium dodecylbenzene sulfonate, sodium chloride, water, n-decane and n-butane]

The objectives of this research program are (1) to characterize mineral oxide surfaces and to relate these parameters to surfactant adsorption, (2) to study chromatographic effects resulting from use of surfactant blends, (3) to understand the properties of microemulsions as related to surfactant structure, and (4) to develop a thermodynamic theory of microemulsions which includes surfactant structure, cosolvents, and surfactant blends as well as the properties of the system oil and water. Progress reports are presented for the following tasks: (1) thermodynamic stability of microemulsions; (2) surfactant adsorption from aqueous solutions; (3) dielectric relaxation in microemulsions; and (4) diffusion in microemulsions. 28 refs., 19 figs., 1 tab.

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Proceedings:  high-temperature, high-pressure particulate and alkali control in coal-combustion process streams

This document contains papers presented at the Department of Energy's Contractor Review Meeting on High Temperature, High Pressure Process Particulate and Alkali Control in Coal Combustion Process Streams. It was sponsored by the Morgantown Energy Technology Center and was held in Morgantown, West Virginia on February 3-5, 1981. The purpose of the meeting was to provide a forum for the exchange of information based on presentations reflecting recent progress in the technology development, device and instrumentation testing. The initial sessions focused on where PFBC power systems are, where they are going, and the role cleanup technology does and will play so as to place the work in perspective. In addition, the most recent large-scale PFBC work was reviewed to establish the current level of development for PFBC in general and the cleanup technology in particular. The problems involved in alkali formation and control were also assessed. Forty-one papers have been entered individually into EDB and ERA. (LTN)

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Unconventional gas resources. [Eastern Gas Shales, Western Gas Sands, Coalbed Methane, Methane from Geopressured Systems]

This document describes the program goals, research activities, and the role of the Federal Government in a strategic plan to reduce the uncertainties surrounding the reserve potential of the unconventional gas resources, namely, the Eastern Gas Shales, the Western Gas Sands, Coalbed Methane, and methane from Geopressured Aquifers. The intent is to provide a concise overview of the program and to identify the technical activities that must be completed in the successful achievement of the objectives.

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Western gas sands: Technology status report

Western gas sands research is conducted by the US Department of Energy's (DOE's) Morgantown Energy Technology Center to encourage the development of very low permeability, lenticular gas sands in the western US. This research is an integral part of DOE's Unconventional Gas Recovery Program, which is a multidisciplinary effort to develop the technology for producing natural gas from resources that have been classified as unconventional because of unique geologies and production mechanisms. The purpose of this research is to demonstrate to private industry the feasibility of economically producing natural gas from these low-permeability reservoirs. The reservoirs, which are found within a resource area that covers 311,000 square miles, contain an estimated several thousand trillion cubic feet (Tcf) of gas-in-place. The western gas resource base continues to be updated as part of the US Geological Survey (USGS) research described in this report. 15 refs., 10 figs., 3 tabs.

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Economics of enhanced oil recovery. Final report

The analysis of enhanced oil recovery economics shows, under conventional financial standards (15% return on investment), field scale, and successful operations, that the extraction and production costs in a representative sample of domestic reservoirs range from $21 to $46 per barrel of incrementally recovered oil. Steam drive, when using lease crude, and polymer flooding, conducted as part of an ongoing waterflood, are financially the most attractive, with costs ranging from $21 to $28 per barrel of oil. Carbon dioxide and chemical floods, particularly when conducted in less ideal reservoir settings, have upper-bound costs of $39 to $46 per barrel of recovered oil. Because of the low primary/secondary recoveries in heavy oils, the thermal techniques, steam drive and in situ combustion, have the highest recovery efficiencies, up to 64% of the remaining oil in place. Polymer flooding is at the other extreme with recovery efficiencies of only 4% of the oil in place after primary and secondary. Currently, the carbon dioxide and surfactant/polymer technologies are in the lower part of this range, with recovery efficiencies of 15% to 43% of the remaining oil in place. However, advances in mobility control and an improved scientific understanding of the interaction between the reservoir and crude oil and the injected materials can appreciably increase the efficiencies of these two promising enhanced oil recovery technologies.

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Development of molten carbonate fuel-cell power plant. Quarterly technical progress report, August 1, 1980-October 31, 1980

The major objective of the program for development of a Molten Carbonate Fuel Cell Power Plant is to establish and demonstrate readiness for fabrication and test of full-scale prototype stacks. Coal-fired utility central station and industrial cogeneration power plant requirements will be defined and plant options evaluated, leading to selection of a single reference design. Cell and stack design and development will be guided by requirements based upon the reference plant design. The specific program objectives derived from the contract work statement are as follows: (1) to define a reference power plant design for a coal-fired molten carbonate power plant; (2) to develop and verify cell and stack design based upon the requirements of the reference power plant design; (3) to establish and demonstrate readiness to fabricate and test full-length stacks of full-scale cells, hereafter called prototype stacks; and (4) to quantify contaminant effects and establish a program to verify performance of molten carbonate fuel cells operating on products of coal gasification. Progress is detailed. (WHK)

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Development of a predictive, underground coal gasification model for eastern bituminous coal: Technical note

This report describes a channel-type, underground coal gasification (UCG) model for eastern coal. Previous studies have indicated that it is technically and economically feasible to use a UCG process to obtain medium-heating-value gas in the Illinois Basin and its vicinity. A reliable, predictive model is needed to support the research and development of UCG. Modeling studies are less expensive than field tests and they help researchers compute the process characteristics for a range of parameters and conditions. The concepts and approaches of developing a model for eastern coal are based on existing models for western coal, while recognizing the differences between the physical and chemical phenomena in the UCG of eastern and western coals. The interactions among different parts of a UCG system and the irregular system dimensions are the major difficulties in solving equations of a channel-type, thin-seam UCG model. Possible ways of resolving these difficulties are suggested and incorporated into the proposed model. 55 refs., 15 figs., 3 tabs.

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Analysis of coal tars collected from Rocky Mountain 1 ELW and CRIP modules

Coal tars were sampled as composites from the Extended Linked Well (ELW) and the Controlled Retracting Injection Point (CRIP) product streams of the Rocky Mountain 1 underground coal gasification field test. Analyses were performed for the following chemical and physical properties: (1) density, (2) elemental composition, and (3) simulated distillation. Heating value and molecular weight for each coal tar sample were estimated from the elemental and simulated distillation analyses. Major organic compounds in the coal tars were determined by glass capillary gas chromatography. The following chemical types were extracted from the coal tars: (1) bases; (2) strong acids; (3) weak acids; and (4) neutrals, the non-extractable portion. Each neutral fraction was separated into: (1) saturates, (2) aromatics, and (3) polar aromatics using silica gel column chromatography. 12 refs., 3 figs., 12 tabs.

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Direct observation of a sand-propped hydraulic fracture

An experiement has been conducted in which a sand-propped hydraulic fracture is created and then mined back to observe fracture behavior and proppant distribution. Three stages of different colored, different concentration sand transported by a water-based gel were injected into a volcanic ash fall tuff formation at a depth of 1400 ft near an existing tunnel complex. The resultant fracture was subsequently mined back for direct observation and photographed and mapped. This particular region was highly faulted and exhibited significant changes in in situ stress magnitudes across the faults; it is felt that this stress distribution resulted in very complex fracture behavior and growth processes. The fracture was bounded on one wing by a fault which was only a few feet from the wellbore. The fracture terminated on top at an unbonded bedding plane. Most of the injected volume of sand and fluid was forced downward, considerably below the elevation where the fracture was initiated. The different colors of sand were randomly distributed, although they were usually found in distinct layers, but this may have been due to the complex growth process. At different locations the fracture was found to have considerable variations in width; from several sand grains wide (1 cm) to devoid of sand altogether (2 to 3 mm average).

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Support Research on Chemical, Mechanical, and Environmental Factors in Underground Coal Gasification

The general goal of this research has been to develop basic data and mathematical models in order to better understand information obtained from large scale field experimentation in underground gasification of Texas lignite. The chemical engineering research has focused on the topics of combustion tube studies of water influx, investigation of cavity growth mechanisms, cracking of pyrolysis products, and analysis of flow patterns in UCG. The petroleum engineering research has focused on subsidence analysis, creep testing and modeling, and effects of overburden drying. Good agreement between subsidence model predictions and data from the Hoe Creek No. 2 field experiment has been obtained. Environmental effects of UCG have been studied both for surface processing of wastewater as well as subsurface phenomena. Activated sludge processing of wastewater seems feasible and pertinent laboratory data have been acquired. Adsorption characteristics and microbial activity for different species in contaminated groundwater have been determined for the Tennessee Colony, Texas, field test site. 100 references, 95 figures, 10 tables.

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Peat resources of Maine. Volume 1. Aroostook County

In July 1979, the Maine Office of Energy Resources, in conjunction with the Maine Geological Survey, began the Maine Peat Resource Evaluation Program. The Program, which was funded by the US Department of Energy (DOE, was undertaken to determine the amount and location of fuel-grade peat in Maine. Two hundred thirty three areas containing peat deposits were evaluated under the Program. A total of 42 deposits covering 11,498 acres and containing 18,851,400 short tons (dry weight) of peat in Aroostook County have been evaluated under the Maine Peat Resource Evaluation Program. These deposits range in size from 30 to 1936 acres and in estimated resources from 48,000 to 3,872,000 short tons. Maps of individual deposits showing the distribution and depth of peat, core sites, and the surficial geology of the area adjacent to the deposits are shown in Figures 4-41. Cores showing the vertical distribution of peat and sediments as well as sample locations, and results of laboratory analyses are also included. 22 references, 41 figures, 3 tables.

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Peat resources of Maine. Volume 4. Southern and western Maine

In July 1979, the Maine Office of Energy Resources, in conjunction with the Maine Geological Survey, began the Maine Peat Resource Evaluation Program. The Program, which was funded by the US Department of Energy (DOE), was undertaken to determine the amount and location of fuel-grade peat in Maine. Two hundred thirty-three areas containing peat deposits were evaluated under the Program. A total of 46 deposits covering 11,853 acres and containing 21,930,200 short tone (dry weight) of peat in southern and western Maine have been evaluated under the Main Peat Resource Evaluation Program. These deposits range in size from 55 to 732 acres and in estimated resources from 55,000 to 1,864,000 short tons. Maps of individual deposits showing the distribution and depth of peat, core sites, and the surficial geology of the area adjacent to the deposits are shown in Figures 4 to 49. Cores showing the vertical distribution of peat and sediment as well as sample locations, and the results of laboratory analyses are also included. 22 references, 45 figures, 3 tables.

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Development potential of coalbed methane in the Warrior Coal Basin of Alabama. Chapters 1, 2, and 3

From its modest beginnings as a mine degasification R and D effort in 1971, the coalbed methane industry in Alabama is now poised for major development. As of July 1984, 135 wells were producing gas and an additional 52 were in various stages of development. A characteristic of most development thus far has been its association with underground coal mining. Mine degasification wells now comprise over 85% of the total of producing wells. Commercialization is underway with about 123 wells selling either to pipelines or to local industry. It is believed that coalbed methane could supply as much as 50% of the in-state demand for natural gas by the year 2000. This, of course, is contingent upon the development of favorable market conditions to provide incentives. At present, it appears that gas deliverability will begin to fall short of demand by the late 1980s. The coalbed methane industry in the Warrior Coal Basin would then have the necessary impetus to increase the pace of development. The Center for Economic and Business Research at The University of Alabama projects that the benefits to Alabama of a moderately paced development would include direct and indirect taxes of over $40 million, new business investments of $200 million, and direct employment increases of 6000 by 1990. 12 references, 40 figures, 56 tables.

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Development of advanced, continuous mild gasification process for the production of co-products addendum to technical evaluation

This report contains the material balance data for Wyodak, Indiana No. 3, and Cannelton coals that were tested in the mild gasification program. Data include tests conducted using the 1- to 4-lb/hr continuous fluid-bed reactor (CFBR) and the 100-lb/hr Process Research Unit (PRU). All raw analysis data were reduced to calculate product yields as a percentage of the product mass divided by the maf coal feed. The material closure was then determined, and losses were assigned to one or a combination of the three product streams: char, condensate (includes condensed steam), and gas. Mass was added proportionally to each constituent of the stream until the closure was 100%.

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