AndreaBozzo/ceres-open-data-index huggingface dataset:
Pyrochromatographic study of Michigan antrim shale

Pyrochromatographic analyses were performed on samples of Antrim shale from 35 wells and nine outcrops in the Michigan Basin. Hydrocarbon components from C/sub 5/ to C/sub 30/ were measured. The majority of the analyses indicate the Antrim to be potentially gas productive. The total hydrocarbon count for each well was divided by the number of samples analyzed to obtain the average hydrocarbon count per sample. Hydrocarbon counts per sample generally increase with depth and toward the center of the Michigan Basin. A bar graph for each well, showing the total hydrocarbon count for each sample, by depth, was plotted and compared with the gamma ray log. A correlation coefficient of 0.696 between increased hydrocarbon counts and increased radioactivity was calcuated based on data from five wells.

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API Research Project 48:  synthesis, properties, and identification of sulfur compounds in petroleum

API Research Project 48 has made excellent progress during the past 2 years in achieving its objectives of obtaining data on sulfur compounds found in petroleum, and in identifying individual and type sulfur compounds in a typical (Wasson) high sulfur crude oil.  The fundamental-research program has developed methods for the synthesis of thiols by the addition of thiolaectic acid to olefins, followed by hydrolysis.  By the use of this approach with halo olefins, an excellent synthetic route for the preparation  of cyclic sulfides has been developed.  Studies on the synthesis and chemistry of benzothiophenes and on the chemistry of the oxidation of sulfides have yielded important data regarding these types of sulfur compounds.  Fifteen samples were synthesized and contributed to the small-scale program.  Since 1952 ten high-purity (99.9 %) sulfur compounds have been prepared in large volume and 35 additional compounds have been obtained in smaller volume.  The large volume compounds have been made available for distribution through the API samples and data office.  These additions make a total of 30 very pure compounds prepared by the project.  Complete physical properties and spectra are available on these.  The total of small samples on which spectral data have been obtained is mow 91 and for these, 212 spectra have been determined, which are available through API Project 44.

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Underground gasification for steeply dipping coal beds. Part one. Version D, process and hydrology wells. Rawlins Module No. 2, UCG/SDB master drilling and well completion plan. [Rawlins No. 2]

The Rawlins Test 2, UCG/SDB Master Well Drilling and Well Completion Plan consists of two separate reports. Part 1 consists of the Process Well Drilling and Completion Plan (Version D). This program was accomplished during the Fall 1980 drilling campaign. Four of the HFEM wells described in Part 2 were also drilled during that campaign due to early completion of the process well drilling. General program objectives are stated in this report. Part 2 consists of the Instrument Well Drilling and Completion Plan (Version B). This program is presently being accomplished in the Spring 1981 drilling campaign. Due to many changes in the types, numbers and locations of the instrument wells it was written in a more general fashion to retain flexibility in the plan. The only significant changes to date from the plan are that the four HFEM wells completed during Fall 1980 were completed with 92'of  Fiberglass at the bottom instead of the 210'now specified.

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Underground gasification for steeply dipping coal beds. Part two. Version B, (instrument wells and extensometers). Rawlins Module No. 2, UCG/SDB master drilling and well completion plan. [Rawlins No. 2]

Gulf Research and Development Company is implementing a DOE-sponsored Underground Coal Gasification project in Steeply Dipping Coal Beds (UCG/SDB) in order to assess the economic and technical viability of UCG in SDB. In the Fall 1980 drilling program, 2 vertical and 2 slant process wells; 3 hydrologic and 1 exploratory well and 4 HFEM wells were completed. The Spring, 1981 program will consist of drilling the remaining instrumentation wells necessary to track the progress of the underground reactor in real time. These will consist of: 6 additional High Frequency Electromagnetic wells (HFEM) and 3 extensometer wells (X). These wells will be installed vertically with an expected deviation of two degrees or less.

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Coal-Gasification Modeling Workshop proceedings

This document contains the proceedings of the US Department of Energy sponsored Coal Gasification Workshop held in Morgantown, West Virginia, on January 18-20, 1982. The primary objectives of the Workshop were to: summarize the stage of development and availability of models and computer codes of gasifier and downstream process modeling efforts in surface gasification; review experimental efforts in gasification and determine the applicability and availability of data for model testing and validation; establish a responsive dialogue and feedback loop (through the Morgantown Energy Technology Center) between modelers and experimentalists to improve the synergism between these complementary areas of effort; and provide information concerning requirements to obtain gasifier and downstream process models and computer codes which have been verified and validated over known operating ranges. Twenty-six papers from the proceedings have been entered individually into EDB and ERA. (LTN)

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Occurrence and reactions of oil shale sulfur

We first discuss the nature and abundance of sulfur forms in Green River oil shale. A previously reported correlation between sulfur and grade does not work well over a very large geographical region. We next discuss the distribution of sulfur in the pyrolysis products, including trace sulfur species in the gas, and the reactions of steam and air with iron sulfides in the shale. Steam reactions increase H/sub 2/S generation in both laboratory and pilot retort experiments. There is a related decrease in COS production with steam. We also discuss the contribution of sulfur to process heat and demonstrate the effectiveness of sulfate-forming reactions to minimize SO/sub 2/ emissions during combustion of retorted shale under conditions simulating lift-pipe burners. The information presented should be of value for properly considering the effects of sulfur when designing oil shale processes.

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Improved solvent extraction recovery of shale oil. [DOE patent application]

An improved process for solvent extraction of organic matter from shale by two extraction steps in sequence. The extraction steps are: (1) treating a kerogen-containing shale with a solvent system comprising a combination of water and an alcohol at a temperature of about 375 to 425/sup 0/C; and (2) treating the product of (1) with a solvent system comprising a combination of an alcohol and another organic solvent at an elevated temperature, but not above about 425/sup 0/C. The organic matter is recovered by separating the liquid which results from step (2) from the shale solids.

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Technical and economic feasibility of proposed oil-shale beneficiation techniques for surface-retorting processes

Removal of the non-oil producing inorganic fraction from the oil shale would require less material to be heated per barrel of oil produced. Thermal efficiency of a retorting operation would be improved in this way, by not having to heat the inorganic minerals. Reduction in the volume of material that must be retorted would allow saving in the number or scale of retorting vessels required for a specified shale oil production.

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Nuclear in situ recovery of oil from oil shale

"A plan is presented for production of oil by retorting oil shale in situ    after breaking it with underground nuclear explosives.  Reserves of oil shale of    thickness and grade suitable (greater than 20 gal/ton) for this process occur in    the Piceance Creek Basin of Colorado, and are estimated to contain 640 billion    barrels of oil in place.  Cost projections indicate that this oil could be    produced at a price ranging from     00 to     30 at the wellhead with a 20% rate    of return on investment (discounted cash flow).  The price and production rate    vary with oil shale thickness.  At a rate of 32 nuclear chimneys per year in oil    shale ranging in thickness from 1000 to 2000 ft, production varies from 28    million bbl/yr (    30/ bbl) to 121 million bbl/yr (P2.O0/bbl).  Capital    requirements for this in situ process are estimated to be 20 times less than    those reguired by a surface retorting process.  Environmental problems such as    the need to dispose of large volumes of waste rock associated with conventional    mining and surface retorting of oil shale would be largely avoided.  Problems of    seismic ground motion and possible contamination of the oil and groundwater    appear manageable.  The necessity for government action arising from federal    ownership of the resource as well as the requirement for a significant government    contribution to the development of the nuclear in situ retorting technology    requires either government development of the resource or a policy defining how    industry and government may jointly develop it.  The potential contribution to    the energy resources of the nation is so large that this method of recovery from    oil shale must be considered.  (auth)"

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Beneficiation-hydroretort processing of US oil shales, engineering study

This report describes a beneficiation facility designed to process 1620 tons per day of run-of-mine Alabama oil shale containing 12.7 gallons of kerogen per ton of ore (based on Fischer Assay). The beneficiation facility will produce briquettes of oil shale concentrate containing 34.1 gallons of kerogen per ton (based on Fischer Assay). The beneficiation facility will produce briquettes of oil shale concentrate containing 34.1 gallons of kerogen per ton (based on Fischer Assay) suitable for feed to a hydroretort oil extraction facility of nominally 20,000 barrels per day capacity. The beneficiation plant design prepared includes the operations of crushing, grinding, flotation, thickening, filtering, drying, briquetting, conveying and tailings empoundment. A complete oil shale beneficiation plant is described including all anticipated ancillary facilities. For purposes of determining capital and operating costs, the beneficiation facility is assumed to be located on a generic site in the state of Alabama. The facility is described in terms of the individual unit operations with the capital costs being itemized in a similar manner. Additionally, the beneficiation facility estimated operating costs are presented to show operating costs per ton of concentrate produced, cost per barrel of oil contained in concentrate and beneficiation cost per barrel of oil extracted from concentrate by hydroretorting. All costs are presented in fourth quarter of 1988 dollars.

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Oil shale project large retort run summary run L-3

Large retort Run L-3 was a combustion experiment in the 6.0 Mg metort conducted on May 7-12, 1979. The shale charge was composed of two different grades of oil shale to stimulate the effects of a step grade change during retorting. The shale grade in the top half of the rtort (3.05 m) was 73.2 Mg (17.6 gal/ton) Fischer assay oil yield and that in the bottom half was 152 l/Mg (36.4 gal/ton) Fischer assay oil yield and that in the bottom half was 152 l/Mg (36.4 gal/ton) heretofore expressed as 18 and 36 gal/ton. The top half of the bed also contained two cylindrical blocks whose combined mass was 1.4 wt% of the top half shale charged and whose grades were 131 and 136 l/tonne (31.3 and 32.5 gal/ton). The bottom half of the bed contained one block, 0.93 wt% of the bottom half charge, 131 l/Mg. These blocks provided data on the effects of nonunform flow. The following table summarizes the major characteristics of Run L-3.

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Selected elemental distributions as determined by reference retorting of oil shale and possible correlation with Fischer assay oil yield

In previous work, the concentrations and distribution of selected elements in oil shale retort products were reported for the Department of Energy interim reference shales and Mahogany zone shale from Colorado corehole No. 1. As an extension of this work, the distribution of the same elements for a new shale group was investigated. The new shale group was composed of rich and lean shale pairs from other Mahogany zone coreholes in the Piceance Creek and Uinta Basins. This report summarizes graphically the distribution data collected to date, including data for the reference shales, Colorado corehole No. 1, and the rich and lean shale pairs. Also included are elemental concentrations by product stream for the new shale group. The data previously reported for Colorado corehole No. 1 were combined with the data from the new shale group to develop a capability for predicting the distribution of these elements in the different product streams. The data collected for the reference shales were not considered in the development of this predictive capability. The empirical data were collected for the new shale group using the same experimental approach as previously reported. Briefly, the general experimental design was to use mass balance Fischer assay as a reference retorting method, with subsequent analysis of the feedstock and all retort products for the elements of concern by instrumental analysis. The elements examined were arsenic, barium, cadmium, chromium, copper, lead, mercury, nitrogen, selenium, silver, sulfur, and zinc. Initially, data analysis also remained the same. Unlike the previous work, statistical analysis was used to test for differences between shale groups for the distribution of a given element in a given product stream. 42 refs., 61 figs., 27 tabs.

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Design and shakedown of an inclined liquid fluid-bed reactor system

This report describes the design and shakedown testing of an inclined liquid fluid-bed reactor system. The system is being developed for processing tar sand with a recycle oil pyrolysis and extraction process to produce a high yield of specialty products. Also reported are the results of cold-flow model tests, which were used to assist in the design of the reactor system. Shakedown tests showed the potential of the process to recover the majority of the bitumen from Asphalt Ridge tar sand and also provided data for the future modifications to improve the reactor performance. Recommendations based on shakedown test results are made for improvements in the tar sand feed, product collection, and disparger components of the reactor system to permit better reactor control and operation. 2 refs., 4 figs.

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Nonhydrocarbon components of a California petroleum

The American Petroleum Institute fundamental research program through various projects has accumulated an appreciable knowledge of he composition  of a sample of Wilmington, California crude oils.  Information from various investigations can be combined to form a more complete knowledge of this crude oil.  The classes of components that have been investigated are sulfur compounds, nitrogen compounds, oxygen compounds, hydrocarbons, porphyins and metals.

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Pressurized fluidized-bed combustion

After a brief background review of fluidized bed combustion, the objectives and status of six pressurized fluidized bed (PFB) projects are described. There are several key technical issues and problem areas concerning the PFB combustor and support components and the gas turbine. The program also studies advanced combustion systems, advanced feed handling, and advanced hot-gas cleanup. 18 references, 8 figures, 4 tables. (LEW)

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Design and initial operation of a slagging, fixed-bed, pressure-gasification pilot plant. [Design for eventual operation at pressures from 400 to 600 psig to gasify lignite or other low-rank, noncaking coals; 25 references]

This report describes the design and initial operation of a slagging gasification pilot plant installed by the Bureau of Mines at the Lignite Research Laboratory, Grand Forks, N. Dak., in 1958- 59. The tests covered in this report were conducted over a period of about 2 years, beginning in April 1959. The pilot plant was designed for eventual operation at pressures ranging from 400 to 600 p.s.i.g. (pounds per square inch gage) ; however, for the preliminary test reported here, the gasifier was fitted with a low- pressure slagging section and operated at atmospheric pressure and at 80 p.s.i.g.. The reason for using a low- pressure slagging section for initial operation was to facilitate modifications in design during the development of a reliable slagging procedure .

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Characterization of in situ synthetic fuels conversion by-products for indicator species, contamination potential, interaction with mineral strata, and amenability to treatment. Final technical report

Assessment of the environmental chemical impact of underground coal gasification requires a thorough knowledge of the chemistry of in situ (underground) coal gasification, particularly as it applies to the production of organic pollutant species and the generation and mobilization of trace element species. To obtain such knowledge, small-scale laboratory coal gasifiers simulating in situ coal gasification have a role to play. Compared to the alternatives - large-scale simulated gasifiers and pilot plants - these laboratory gasifiers offer orders of magnitude lower costs, much shorter time scales, wide variation of the chemical conditions of gasification, capability to modify experimental parameters quickly in response to results, and much greater ease of observing the gasification process. Trace elements were added to the coal by surface sorption from aqueous solution, as coal-humic acid complexes, and as solid sulfides. The elements that were found to be mobilized to the greatest extent during gasification were arsenic, boron, antimony, tin, and selenium.

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Single-column ion chromatography for sulfur-containing anions in oil shale by-product waters

The chemical species of inorganic sulfur in oil shale by-product waters determine its potential environmental fate. Volatile species such as sulfide may take one path and nonvolatile such as sulfate another. Research in sulfur collection, concentration, confinement, or utilization of sulfur in retort water depends on the ability to analyze unstable sulfur species in near real time during oil shale retorting. Five principal sulfur-containing anions were separated and detected in oil shale retort by-product waters using a simple high-performance liquid chromatograph with a mercury emission (254 nm) photometric detector. The anions - sulfide, sulfite, sulfate, thiosulfate, and thiocyanate - were studied on a silica-based anion exchanger and on a resin-based anion exchanger over a range of conditions with two types of eluents. The eluent systems were phthalate/borate or gluconate/borate to accommodate indirect photometric detection or direct photometric detection respectively. The photometric detection systems were compared with conventional conductivity detection and electrochemical detection. Indirect photometric detection for general or universal detection was shown to be comparable to conductivity detection. Direct photometric detection of sulfide was superior to electrochemical detection in the oil shale retort by-product water analyses because of electrode poisoning effects caused by the organic-laden by-product waters on the electrochemical detector. 56 refs., 27 figs.

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Second three-dimensional physical simulation of forward combustion in tar sand triangle material

In situ recovery technologies for tar sand and heavy oil are experimentally simulated at the Western Research Institute to develop a technological base for understanding in situ processing of these resources. Wide ranges of process parameters are tested in one-dimensional reactor tubes in which the tar sand or heavy oil sand is uniformly reconstituted to nearly the same permeability and porosity as the field resource. Three-dimensional process performance is evaluated by testing the most promising operating parameters in consolidated blocks of the field resource. A three-dimensional test of in situ combustion was conducted on a block of material from the Tar Sand Triangle. This test was the second such test conducted on the Tar Sand Triangle material and incorporated several design features to overcome problems identified in the first test. Although combustion was established in the block, the maintenance and advancement of the combustion front was not successful. The problem with sustaining combustion appears to be excessive heat loss to the surrounding refractory and the sweep gas. These heat losses reduce the temperature in the combustion zone and inhibit utilization of the oxygen in the injected gas. Poor oxygen utilization leads to lower combustion temperatures and less driving force for the combustion front. 6 refs., 7 figs.

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Application of thermally-activated gas canisters in MIS oil-shale retorts

Thermally-activated gas canisters, were developed and field tested for use as temperature sensors during modified in-situ (MIS) oil shale retorting. These instruments allow one to determine when known retort bed positions reach a predetermined temperature. From this information, the degree of flow uniformity through the bed can be determined. The main advantage of this concept is that the thermal sensors need no physical connection to their respectivce data acquisition instruments. A metal canister is filled with compressed freon (or other easily detectable gas) and sealed with a temperature sensitive cap. This cap is designed to open at a specific temperature. The released gas is then detected by analyzing the retort offgas using conventional gas chromatographic methods. The canisters are emplaced in the retort during construction. For the field test described, we simply lowered them downhole onto the rubble pile. They are ruggedly designed to survive subsequent blasting operations. 6 figures, 1 table.

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Trace element distribution and oil yield data from the Parachute Creek Member of the Green River Formation, Colorado

The determination of trace element concentrations in oil shale before mining and retorting is required for proper solid waste management planning. Using routine Fischer assay oil yield data collected during resource characterization as indicators of potential trace element concentrations could lead to a standard method of identifying strata containing high trace element levels. In order to determine a correlation between trace elemental concentrations and oil yield, shale samples were selected from four statigraphic zones of the Parachute Creek Member of the Green River Formation for analysis. All samples were analyzed for total elemental concentrations, mineralogy, and Fischer assay oil yield. The results of these analyses demonstrated that the Mahogany zone shales contain significantly greater trace element concentrations (antimony, arsenic, cadium, chromium, copper, lead, lithium, mercury, molybdenum, nickel, selenium, silver, and vanadium) than the other three shale zones. These high trace element concentrations have been identified within well-defined interbedded tuff deposits in the Mahogany zone. In addition, all trace elements evaluated, except boron, show either increasing or decreasing concentrations as oil yield increases within all oil shale zones. With an increased number of analyses of existing oil shale cores, oil yield data will be correlated to specific stratigraphic units containing high trace element concentrations. 33 refs., 4 figs., 5 tabs.

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