AndreaBozzo/ceres-open-data-index huggingface dataset:
Great Plains model development:  gas compression and drying section. Final topical report. [ASPEN model of synthetic natural gas compression and drying flowsheet of the Great Plains Gasification Plant]

An ASPEN model has been developed of the Gas Compression and Drying Flowsheet, Section 1900, of the Great Plains Gasification Plant. The basis for this model is the process description given in section 6.14 of the Great Plains Project Management Plan, and the Lummus Schematic Process Flow Diagram, Dwg. No. SK D-7102-IJ-2. The TEG Drying section is a standard adsorbing and stripping operation. Operating conditions for the towers were obtained from the Gas Condition Fact Book published by the Dow Chemical Company. The ASPEN model that has been developed uses an abbreviated list of components, since not all the components appear in the product. Furthermore, since a Henry's Law model with Wilson activity coefficients is used to predict vapor/liquid equilibrium, it would have required a large effort to enter the Henry's Law parameters for all the components that ultimately would not be used because they are not found in the product streams. The model is primarily a flowsheet simulation that will give the material and energy balances and equipment duties for a given set of process conditions. The model is unable to predict fully changes in process conditions that would result from flow load changes on equipment of fixed sizes, such as a rating model would. The model can be used to simulate the steady-state operation of the plant at or near design conditions, or to design other Gas Compression and Drying Systems. TEG flowrate is varied to meet the water specification in the product gas. No convergence problems were experienced running the model. Several runs were made to study the response of the model to changes in the feed flowrate, product specification, and number of trays in the absorber. 5 references.

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Reaction kinetics between steam and oil shale char

The reaction kinetics between steam and the residual organic carbon (char) in retorted Colorado oil shale (Mahogany Zone) were investigated using both isothermal and nonisothermal methods. The reaction is found to depend on the 0.5 power of the steam partial pressure. The steam-char reaction is found to be faster than the CO/sub 2/-char reaction at temperatures near 700/sup 0/C. The reactivity of the char depends on both the heating rate used to generate the char and subsequent thermal treatment. Removal of mineral matter by acid leaching decreases the reactivity of the car by more than an order of magnitude.

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Theoretical aspects of reverse combustion in the underground gasification of coal

A mathematical model is developed which describes the reverse combustion phase (linking phase) of the underground coal gasification process. The model involves a quasi steady-state linear treatment of reverse combustion in a porous system of coal. A system of four differential equations coupled with an Arrhenius type reaction rate function is solved numerically. The results yield a favorable comparison with experimental data obtained from a field test conducted by the Laramie Energy Research Center near Hanna, Wyoming. With the aid of the model, field tests can be interpreted quantitatively in terms of known chemical and physical phenomena.

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Mathematical-modeling studies of in-situ coal gasification

Commercialization of the in-situ or underground coal gasification (UCG) process has been impeded because of uncertainties with respect to its reliability and predictability. Modeling studies when combined with a well-designed field test program are the only avenue to a proper understanding of this technology. This paper reviews the latest developments in four important facets of the UCG process: reverse-combustion linking; gasification and resource recovery; water influx; and subsidence.

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Underground gasification of coal. [Review with 12 references]

Coal is assuming an important role as an energy source together with hydroelectric power in our country, and in order to supply  energy at low cost coal mining companies and rationalizing the industry in many respects.  Therefore it is necessary not only to promote the mechanized extraction of coal, but to study positively new means of coal extraction, namely "the underground gasification process" and especially to establish methods suitable for the conditions of our country.

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In-situ coal gasification:  a bibliography. [2222 references]

The 2222 references in this bibliography on in-situ gasification of coal were selected from the Energy Data Base (EDB) produced by the Office of Scientific and Technical Information (OSTI). New citations on this subject are announced semimonthly in the bulletin Coal-Based Synfuels and monthly in Fossil Energy Update, both published by OSTI. The Energy Data Base is available for on-line searching using the DOE/RECON system or the DIALOG commercial on-line retrieval system. Abstracts in this bibliography are sorted first by year of publication and then by first author. Five indexes are provided: Corporate Author, Personal Author, Subject, Contract Number, and Report Number.

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Oil shale and evolving national security issues

World and US progress in reducing dependence on sources of energy threatened by deeply rooted disputes are discussed. A future involving shortages in the 1990s is hypothecated based on work done by the International Institute for Applied Systems Analysis. Limitations of the Strategic and Naval Petroleum Reserves are identified. The latest threat to world oil trade, unrest in the wider Caribbean region, is graphically depicted. Finally, the advantages to world stability of developing energy resources other than petroleum are discussed.

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Nitrogen compounds in Colorado shale oils

The nitrogen contents of Colorado shale oils, produced in internally fired retorts, approximate 2% by weight for the oils that have been investigated. The quantity of nitrogen in the oils depends on the conditions in the retort producing the oil. About 2/3 of the nitrogen compounds in the naphtha are pyridines. The other 1/3 is predicted to be C-alkylated pyrroles. A naphtha, produced by destructive hydrogenation of a crude shale oil, contained both pyridines and anilines. A heavy gas-oil fraction consisted of 40% nitrogen compounds. These were one-, two-, and multi-ring compounds. For the multi-ring compounds, the data suggest more than one heteroatom per molecule. Porphyrins are shown to be present in shale oil and to be changed from those present in the oil shale. Groennings'extraction is a satisfactory method for concentration of the porphyrins.

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FY 85 Technology Transfer Program

At the Morgantown Energy Technology Center (METC) of the US Department of Energy (DOE), the Technology Transfer Program is integrated into the Center's fossil energy research programs. The research areas upon which these transfer activities are based include the 13 lead laboratory research and development (R and D) mission assignments for which DOE/METC is responsible: coal gasification, fluidized-bed combustion, gas stream cleanup, heat engines, fuel cells, components, instrumentation and control, low-rank coals, unconventional gas recovery, oil shale, tar sands, underground coal gasification, and Arctic and offshore technologies.

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Underground gasification of coal by oxygen. [By use of O instead of air, calorific value of >1000 Kcal/m/sup 3/ resulted]

"The previous paper described our first laboratory experiments on the underground gasification of coal using only air. This paper reports on the gasification of coal  using oxygen. The purpose of the present experiment was to study the outline of the gasification processes which occurred using oxygen. The author concludes as follows:  1. With oxygen , the gas calorific value is greater than that using air.  2 . The gasified zone is also greater. In our experimental apparatus the amount of oxygen used was 3.2 l/min, the length of borehole was 30 cm and diameter 1.2 mm. A product gas with a calorific value of more than 1000 kcal/N 3 was obtained during approximately 10 hours.  3 . By the use of oxygen, a desirable gas is obtained, but what quantity of gas can be generated and what reduction processes occur in the coal seam?  Can the reaction speed in the gasification process of coal be obtained? A number of experiments concerning such problems were carried cut in our laboratory and they will be reported in next paper ."

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Subterranean gasification of coal in the Soviet Union. [Review]

"The controversial theme is summarized in what follows. No  final assessment of the processes described (exploration,  preparation, and working) and prospects (generation of  electricity, steam, and heat) can be found even in Soviet  reports. Within the whole gas economy underground gas  probably has little significance compared with natural gas  and all artificial fuel gases. It is uneconomical for the  operation of long-distance lines. All this does not exclude  the possibility that in the developing countries without  adequate traffic and supply networks it can be an important local energy source."

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Application of gas-chemical computations for determination of water inflow into areas of underground coal gasification. [Underground waters have great influence]

"Underground gasification of coal (UGC) is a complex technological process which is strongly affected by underground water. During the period of preparation of coal seams for gasification underground water may make drilling difficult, prevent ignition of the coal, and change to a considerable extent the physicochemical properties of the coal a medium for hole linking. These properties  include electrical conductance, gas permeability, and thermal conductivity. Apart from this, flooding of the coals and the rocks during hole linking may involve such phenomena as electrolysis, electrophoresis , electroosmosis , and various thermal changes all having some effect on the linking rate and on the parameters of the linking channel produced. During gasification of a seam, underground water takes part as a chemical reactant in the gas-formation process and acts as a physical factor on the coal structure."

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Underground gasification of coal

"Research and experiments at the largest plants  devoted to underground gasification of coal in the USSR indicate that underground generators will be a very good source of gas. Recently, mining has become an area in which there has been a great deal of mechanization and many of the methods of mining that were difficult, dangerous, and harsh have been replaced. This accounts for the great advantage of underground gasification by the percolation method, in which underground work will be completely replaced by trained work on the surface, with resultant utilization of complex mechanization and automation."

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Gasification in a coal tunnel with a steam-oxygen blast

"The first positive results of operation of the Yuznyi Abinsk Podzemgaz station (Kuzbass ) on an air blast [1] have established the prerequisites for future application of steam- oxygen blast to the underground gasification of  these coals in order to obtain gas suitable for chemical syntheses. The production of technological gas by underground gasification of coal (UGC) is a complex problem whose solution requires, together with an  amplification of experimental work under natural conditions and the solution of general problems for this process (preparation of the coal seam, control of the process, etc.), the performance of a whole set of laboratory investigations, including ones associated with the establishment of the features of gas formation on a steam- oxygen blast for specific fuels."

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Regenerative method of underground gasification process of coal. [Heating value of 900-1000 Kcal/m/sup 3/ increased to 1300-1400 Kcal/m/sup 3/ by increasing O content to 23%; with O and steam it was 2500 Kcal/m/sup 3/; gas composition of CO/sub 2/ 13. 58, O 0. 22, CO 6. 32, H 58. 5, CH/sub 4/ 4. 28, N 17. 1%]

The chemical reactions taking part in an underground gas producer can be divided into exothermic and endothermic processes.  The exothermic reactions entail the evolution of large heat quantities.  Practice shows that during the combustion and gasification of coal seams a large amount of heat is produced, heating and partially melting the immediate overburden.  The problem is to utilize this heat for increasing the quality of the product gases.

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Distribution and state of slag and packing material in the gasification void (according to material on the opening-up of generator No. 1 at Lisichansk)

Generator No. 1 was prepared according to the scheme shown in Fig. 1.  From a sloping shaft 108m long, passing through seam L7, a cross cutting 14m long opened up seam L8 at a depth of 72m vertically from the surface.

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General model of oil shale pyrolysis

A mathematical model for pyrolysis of Green River oil shale is developed from previous experiments on oil, water, and gas evolution and oil cracking over a wide range of pyrolysis conditions. Reactions included are evolution of 5 gas species, oil, and water for kerogen, clay dehydration, oil coking and cracking, and evolution of H2 and CH4 from char. Oil is treated in eleven boiling-point fraction is ordered to treat the competition between oil coking and evaporation, and to evaluate the effect of oil cracking on the boiling-point fractions in order to treat the competition between oil coking and evaporation, and to evaluate the effect of oil cracking on the boiling point distribution of the oil. The kinetics and product yields calculated by the model are compared to experimental results for pyrolysis conditions ranging from isothermal fluid-bed to high pressure low heating rate retorting.

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Investigation of the Geokinetics horizontal in-situ oil-shale-retorting process. Quarterly report, October, November, December 1981

The Geokinetics In Situ Oil Shale Projects a cooperative venture between Geokinetics Inc. and the U. S. Department of Energy (DOE). The project is governed by DOE Cooperative Agreement #DE-FC20-78LC10787. The objective is to develop an in situ process for recovering shale oil using a fire front moving in a horizontal direction. The project is being conducted at a field site, Kamp Kerogen, located 70 miles south of Vernal, Utah, on Section 2, Range 22 East, Township 14 South, Uintah County, Utah.

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Constraints on the commercialization of oil shale

The problems and prospects for the commercialization of oil shale from surface retorting are examined. Commercialization refers to the process of private sector adoption of a technology for general use after most of the technological uncertainties have been resolved. Three categories of constraints and uncertainties can be identified: technical constraints relating to the performance characteristics of the technology; economic constraints on the ability of the technology to yield an acceptable rate of return to investors; and institutional constraints that arise from the organizational and political context in which commercialization takes place. Because surface retorting involves relatively well understood technologies, this study deals almost exclusively with economic and institutional constraints. At the present time, a government commercialization effort for oil shale surface retorting would not be likely to result in a viable industry in this century. Alternative oil shale technologies such as modified in situ processes offer prospects of lower shale oil costs, but are less well developed. Data on modified in situ processes are not abundant enough as yet to permit serious estimates of commercial-scale costs. Consequently, government decisions regarding the commercialization of modified in situ technologies should await the completion of further technical tests and an independent definitive plant design.

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Reaction kinetics and diagnostics for oil-shale retorting

During the past two years, Lawrence Livermore National Laboratory has continued its research on the utilization of oil shale. Although an increasing emphasis has been placed on surface processing (25, 34), most of the work has been conducted on modified-in-situ processing. Six pilot retort runs were conducted in this period to complete the perspective on the relative importance of grade, retorting rate, particle size and inlet gas composition in modified-in-situ retorting (18, 38, 39). The LLNL one-dimensional retorting model has been used to help plan an interpret pilot and field retort experiments as well s conduct parameter studies. A two-dimensional flow model has also been used to analyze the importance of retort geometry and permeability on the sweep efficiency of Occidental and Rio Blanco retorts. Finally, new advances have been made in the understanding of the chemistry involved in oil shale retorting.

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Impacts of synthetic fuels development

The objective was to present some insight into three aspects of synthetic fuels technology. The resource base and the different technical approaches to producing useable fuels from the resource are examined. The potential impacts of various synthetic fuel technologies on air quality, water quality and quantity, environmental safety and health, land use and the socioeconomic stability of affected communities are examined. Existing standards designed to control these risks and mechanisms and approaches which can be taken by synfuel developers to meet these standards are discussed.

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Conversion of kerogen in eastern US oil shale by tetralin and hydrogen

Chemical analyses and tests, petrographic data, hydroretoring tests by thermobalance, and extractions of kerogen by tetralin have been obtained on a suite of eight Eastern oil shales, and except for petrography, on a Colorado oil shale. The organic carbon-hydrogen ratios of the Eastern oil shales ranged from 10.5 to 13.6, compared to 8.36 on the Colorado shale. The petrographic data indicated that the differences among the Eastern oil shales arise mostly from differences in their content of vitrinite. Organic carbon conversion, both to liquid and total, in hydroretorting correlates to some extent with extraction of kerogen by tetralin. Conversion decreases with increase of organic carbon-hydrogen ratio. The scatter of results, however, indicates that additional or different parameters are required for satisfactory correlations of hydroretorting yield. With the exception of one shale, organic carbon conversion by tetralin correlates well with organic carbon-hydrogen ratio.

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Extraction of reference eastern shale with hydrogen donor and nondonor solvents

Oil shale from the New Albany Formation in Bullitt County, Kentucky, was treated with water together with hydrogen-donor and nondonor solvents at 400/sup 0/C and extracted with benzene-methanol. The purpose of the experiments was to measure the amount of liquid organic material recovered with hydrogen-donor and nondonor solvents. Liquid organic material amounting to approximately double that recovered by a Fischer assay experiment was recovered with tetralin, a hydrogen-donor solvent, and with naphthalene, a nondonor solvent. The shale was also treated with tetralin and water for periods of 5 minutes to 60 minutes to measure the effect of time on yield of liquid product. The results showed that yields increased with time and that treatment times of about 30 minutes were required to recover more liquid product than that produced by a Fischer assay experiment. 10 refs., 1 fig., 2 tabs.

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Retorting oil shale with zones of contrasting permeability Runs S76 and S77

Work is under way to develop relationships between yield and permeability distribution to better understand the impact of nonuniform oil shale particle size and void distribution within in situ retorts. Nonuniform permeability causes nonuniform flow which creates uneven retorting fronts that result in low oil yields. This report describes results of tests S76 and S77, the sixth and seventh in a series of nine tests designed to establish relationships between nonuniform rubble properties and shale oil yields from in situ oil shale retorts. Zones of permeability contrast and the resultant nonuniform retorting gas flow patterns are simulated by loading adjacent zones of the test retort with differing size distributions of oil shale particles. Test S76 simulated a small zone with slightly contrasting permeability and S77 simulated a larger zone with greatly contrasting permeability. Retorting gas flow at the reactor inlet and shale grade were held constant over the series of tests making basic particle properties of size, size distribution, and void space the only variables in the test series. This work indicates that even a small amount of permeability contrast has a large impact upon oil yield from modified in situ retorts. A small amount of nonuniformity in distribution of permeability is a more significant determinant of shale oil yield than retorting gas flow rate and composition. 11 refs., 14 figs., 12 tabs.

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Reverse combustion in a horizontally bored coal channel

Reverse combustion along a directionally-drilled horizontal channel 76 mm in diameter will be used in Hoe Creek No. 3. The enlarged channel at the bottom of the Felix No. 2 coal seam produced by the reverse combustion will allow high gas flow rates for the forward combustion phase of gasification. This paper discusses the experimental and mathematical modeling of reverse combustion along a horizontal bored channel in shrinking coal. The purpose of the modeling effort is to provide information to assist in planning the reverse combustion phase of the Hoe Creek No. 3 field experiment. In these experiments at one atmosphere reverse combustion did not propagate with air as the feed gas. Reverse combustion did, however,  propagate when the feed-gas oxygen content was increased to 32%. An existing LLL model of underground coal gasification was modified and used to simulate the reverse combustion process. Preliminary results agree qualitatively with the experimental results. This model indicates that reverse combustion will propagate at a pressure of 5 atmospheres without enrichment of the air with oxygen. Simulations of field scale experiments are also discussed. The experimental and mathematical modeling results have yielded rather negative results to date, which serves as a warning of possible trouble in the Field Experiment. We have hopes that such trouble will not actually be encountered because the conditions for reverse combustion are somewhat more favorable in the field situation than those tested in the laboratory. A number of remedies have been conceived for use in case of trouble: (1) enrich the air with oxygen during reverse combustion, (2) add propane to the air, and (3) heat the air. These remedies and provisions for implementing them are being considered.

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Net energy analysis of in situ oil shale processing. [50,000 b/d]

Although the domestic resources of shale oil are large, there has been some question regarding the magnitude of the energy subsidy that must be committed in order to extract the contained oil. This study shows that for a 50,000 b/d, modified in-situ extraction facility in 20-gal-per-ton Green River Shale, the energy yield is about 8.6 times the energy subsidy and that about 21 percent of the in-place oil can be thus recovered. If the mined-out shale is retorted at the surface rather than being discarded, the recovery factor rises to 37 percent and the net energy ratio should rise significantly as well. It is difficult to compare these figures with those for aboveground retorts because oil burned in place for retorting never enters the energy accounts. However, the resource commitment per unit of recovered energy is more easily compared and is essentially indicated by the reciprocal of the recovery fraction.

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