AndreaBozzo/ceres-open-data-index huggingface dataset:
Lumped mass modeling of overburden motion during explosive blasting

The in situ extraction of oil from most oil shale beds is highly dependent upon explosive fracturing and rubbling of rock in a controlled and predictable manner. Besides the rubbling requirement, it is also important that the surrounding rock remain competent to minimize fluid leakage during processing. For rubbling concepts in which the overburden is explosively lifted to provide the required void in an oil shale zone, an engineering lumped mass model has been devised to describe the motion of the overburden. The model simulates the overburden as an array of interacting lumped masses which are loaded from below with a time-dependent force to approximate the explosive load. Correlation with experimental data obtained from field blasting operations shows that this model will provide an adequate approximation of overburden behavior. The basic features of the model are described in the report along with the correlations with field data. Results from several parametric studies are also presented which were used to aid in blast design. This lumped mass model can be extended to include other parameters and has potential for the study of other related blasting situations.

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Minimum bed parameters for in situ processing of oil shale. Fourth quarterly report, July 1-September 30, 1980

Oil shale retort run 030, consisting of a 7.6 cm diameter by 28 cm long competent shale core drilled axially with seven 0.95 cm holes in a hexagonal pattern (i.e., a borehole retort), was completed. Model calculations were made using Sandia's block retorting code for comparison with experimental data. The observed retorting rate was 9.7 cm/h, while the calculated rate was 9.0 cm/h. Peak temperatures ranged from 670 to 790/sup 0/C, while calculated peak temperatures ranged from 780 to 820/sup 0/C. The observed yield was 69% compared to a calculated value of 78%. The success of the borehole retorting experiment has demonstrated the technical feasibility of borehole retorting. The generally good agreement between observed and calculated temperature profiles, char boundary location, retorting rate, local heating rate, and yield has constituted an important contribution to model validation efforts.

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Remote sensing in drilling and production applications

Remote sensing is a century-old conglomeration of technologies that because of recent advances and successes has become a standard operating technique in hydrocarbon exploration. Remote sensing's economies and proved advantages do not stop, however, with exploration well siting activities, a fact presently appreciated by too few producers. On major, international producer tried remote sensing for post-exploration activities, and now applies the technique in over 40% of its oil patch logistics work, alone. This article briefly describes four diverse case histories in successful post-exploration application of remote sensing, in order to stimulate readers to consider the technique for solving problems in their hydrocarbon activities domain.

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Shale oil thermal degradation

Isothermal pyrolysis tests have been run on a high boiling distillate cut of Paraho direct-fired whole oil. The distillate products were collected and the residuum was further characterized by solubility in chloroform and n-heptane. Distillate production is found to be a pseudo-first order process (E/sub a/ = 57 kcal/mole). However, the chloroform insolubles are generated only after a delay. This delayed formation of a coke-like material may occur because of a limited solubility of asphaltenes in the residual oil. Kinetic parameters for the decomposition of heavy oil heptane asphaltenes and maltenes are presented. In four hours at 425/sup 0/C only 27% of the heavy oil formed chloroform insoluble material. This corresponds to only 13% of the whole oil. Although cracking occurred, degrading 60% of the heavy oil, most of the cracked product condensed at -78.5/sup 0/C. 10 refs., 6 figs., 4 tabs.

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Role of spent shale in oil shale processing and the management of environmental residues. Final technical report, January 1979-May 1980

The adsorption of hydrogen sulfide on retorted oil shale was studied at 10, 25, and 60/sup 0/C using a packed bed method. Equilibrium isotherms were calculated from the adsorption data and were modeled by the Langmuir, Freundlich, and Polanyi equations. The isosteric heat of adsorption was calculated at three adsorbent loadings and was found to increase with increased loading. A calculated heat of adsorption less than the heat of condensation indicated that the adsorption was primarily due to Van der Waals'forces. Adsorption capacities were also found as a function of oil shale retorting temperature with the maximum uptake occurring on shale that was retorted at 750/sup 0/C.

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Synthetic fuels from US oil shales:  a technical and economic verification of the HYTORT Process. Project 61040 quarterly report, April 1-June 30, 1980

Progress is reported on the HYTORT Process development work conducted from April 1 through June 30, 1980. Thermobalance tests have been conducted on samples of shale from each large multiton sample prior to large-scale tests and these test results have been fit with specific kinetic expressions. Approximately 80% of the instrumentation for the laboratory-scale reactor has been received. Fabrication of the reactor, feed hopper, and residue receiver is about 95% complete. Two successful moving-bed tests were conducted in the bench-scale reactor during this quarter. A large, 50-ton sample of the Lower Huron member of the Ohio Shale was mined and readied for shipment to IGT. Modification of the bench-scale steam-oxygen unit was completed. Spent shale from PDU tests was prepared for use in these tests. A set of five screening runs on New Albany shale oil and a set of four screening runs on Sunbury shale oil were conducted during this quarter. The nitrogen content of these oils was reduced to the 0.16 to 0.30 weight percent range in the bench-scale hydrotreating unit. Design of the laboratory test system for mist-size control studies was completed. Methods are being studied for measuring mist particle size. Shakedown and initial testing of the liquid-sealed lockhopper were performed during this quarter. Two runs were made in the PDU with Kentucky shales using a sample of the Cleveland member of the Ohio shale and a sample of New Albany shale. Samples for environmental analysis were taken during the PDU runs discussed above. On-line sampling equipment was installed prior to the PDU run with New Albany shale and samples were taken of the Stage 2 raw product gases.

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Groundwater quality monitoring of western oil shale development: monitoring program development

This report presents the development of a preliminary design of a groundwater quality monitoring program for oil shale operations, such as proposed for Federal Prototype Lease Tracts U-a and U-b in eastern Utah. A preliminary decision framework for monitoring design for this type of oil shale operation is presented. Included under the broad topic of the monitoring plan are recommendations for developing background data bases on pollutant source characteristics, the hydrogeologic framework of the study area, existing water quality, and infiltration, as well as recommendations for monitoring pollutant quality, and infiltration, as well as recommendations for monitoring pollutant mobility.

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Fossil-Energy Waste General Sampling Guideline

In preparing the Fossil Energy Waste General Sampling Guideline, the authors have attempted to review the best available scientific procedures for collecting samples of solid fossil energy wastes. Those procedures deemed applicable to the sampling of waste streams from conventional coal-fired utilities were included in the initial draft. Procedures applicable to wastes from emerging energy technologies (coal gasification, liquefaction, etc.) were to be added as further information became available. The procedures set forth in the initial draft have now been applied in a sampling program which encompasses 18 conventional coal-fired utilities and 7 emerging energy facilities. As a result of that program, several refinements concerning conventional utilities have been incorporated into this final draft. Because the emerging energy technologies are just beginning to be commercialized, facilities employing the same technology are not yet as standardized in physical construction as are conventional coal-fired facilities. Experience gained from sampling wastes from these facilities indicates that, while many of the sampling techniques described for conventional facilities are applicable, the uniqueness of these facilities prohibits the development of general procedures that are applicable to these new technologies. However, when procedures for the sampling of conventional facilities may be applicable to the emerging technologies, that fact is noted in the text. Also, safety considerations which relate to these facilities are addressed.

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System for utilizing oil shale fines

A system is provided for utilizing fines of carbonaceous materials such as particles or pieces of oil shale of about one-half inch or less diameter which are rejected for use in some conventional or prior surface retorting process. Maximum utilization of the energy content of the fines is obtained and  a waste is produced which is relatively inert and of a size easy to dispose. The system includes a cyclone retort  which pyrolyzes the fines in the presence of heated gaseous combustion products, the cyclone retort having a first outlet  through which vapors can exit that can be cooled to provide oil, and having a second outlet  through which spent shale fines are removed. A burner connected to the spent shale outlet of the cyclone retort, burns the spent shale with air, to provide hot combustion products that are carried back to the cyclone retort to supply gaseous combustion products utilized therein. The burner heats the spent shale to a temperature which forms a molten slag, and the molten slag is removed from the burner into a quencher that suddenly cools the molten slag to form granules that are relatively inert and of a size that is convenient to handle for disposal in the ground or in industrial processes.

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Analysis of Hanna II in-situ coal gasification experiments

Two interesting results are evident from the material balances presented: (1) A large, unreacted CHAR zone is calculated to remain following gasification, in both cases, and, (2) very little water is calculated to enter into the overall reaction. For Phase I a total of 1143 tons of coal were affected with 493 tons gasified and 649 tons carbonized only. For Phase II, a total of 2124 tons of coal were affected with 830 tons gasified and 1293 tons carbonized. In view of the heterogeneous nature of Hanna coal, the apparent conclusion of a large char zone may be partially offset by differences in the composition of coal actually entering into gasification. However, since coal composition is one of the few parameters which can be measured in a field experiment, uncertainties in this area should be eliminated, so that more abstract parameters such as unreacted char formed may be addressed.

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Analysis of selected trace metals in leachate from reference fly ash. Phase II. Supplemental leaching program. Final report

An inter-laboratory testing program was conducted to isolate and measure the primary components of variability in the American Society for Testing and Materials'(ASTM) and Environmental Protection Agency's (EPA) extraction procedures for testing the leaching potential of solid wastes. The program is a continuation of the Collaborative Test Programs undertaken jointly by ASTM Subcommittee D19.12 and the US Department of Energy (DOE). The National Bureau of Standards was retained by DOE to design the program and analyze the results. Engineering-Science provided initial program coordination, and Webster and Associates coodinated the data analysis and preparation of the report, both under contract to DOE. Thirteen laboratories participated in the program, all on a voluntary basis. In carrying out the program, specially prepared samples of a Reference Fly Ash were utilized in order to minimize sample heterogeneity. Each laboratory preformed both the ASTM and EPA extraction procedures on the Reference Fly Ash in duplicate, split the extract into two equal portions, completed duplicate analytical determinations on one portion, and shipped the other portion to a central laboratory. The central laboratory performed duplicate analytical determinations on all extracts. The main observations and conclusions from the test program are: (1) sampling may be a large variable in field situations; however, with the use of the Reference Fly Ash, sample heterogeneity was controlled, allowing analysis of effects other than sampling variability; (2) the cooperating laboratories demonstrated acceptable analytical reproducibility based on analytical quality control data; (3) poor reproducibility of the trace metal results on the extracts from the Reference Fly Ash was shown to be primarily due to variability in the leaching process rather than analytical technique.

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Paraho Oil Shale Module:  environmental, safety and health plan. Topical report, Task 8. Part II. Construction and operating program; hygiene plan

This manual establishes the general safety requirements for all plant activities and operations. The safety rules and regulations prescribe safe methods and procedures for insuring continuity of operations, safeguarding personnel, and preventing property damage. All plant safety programs will be continuously evaluated to insure that the minimum requirements of the program are always present.

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Underground gasification for steeply dipping coal beds. Phase I report:  feasibility study and program plan, September 30, 1977--February 28, 1978

The first phase of the DOE project for gasification of steeply dipping coal beds consisted of site selection activities, a concept feasibility study and program planning. A test site was selected at North Knobs near Rawlins, Wyoming. This site has the best potential for a successful first UCG-SDB test. Analysis of the concept suggests air emission and aquifer degradation as possible areas of environmental impact. A monitoring plan has been established to determine the environmental effect of the tests. The detailed technical approach for the project is being developed based on present DOE field experiences and previous Russian work. Emphasis will be on resolving technical areas where the DOE experience is not transferrable (i.e., process modeling, well configuration, and installation). Using a proprietary cost estimating model, the parameters of greatest sensitivity were product gas quality, gas leakage, and yield of product gas per unit volume of injection air. A facility and equipment design was established for cost projection and to serve as a basis for detailed design work during the second phase. A cost analysis of the project indicated that the original costs projections still hold but that the spending curve will require revision.

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Bodcau In Situ Combustion Project. Final report, June 1976-June 1982

The primary objective of the Bodcau In Situ Combustion Project was to demonstrate the operations and economics of a commercial scale in situ combustion project utilizing simultaneous air and water injection. This report includes pre-contract work, field facilities, injection and production performance, remedial work, monitoring, research support, a performance evaluation, and economics covering the contract life. The project was conducted on five patterns of Cities Service Company's Bodcau Fee B Lease. The five patterns were part of an eight-pattern expansion of Cities'combustion operations in the field. Thirty-eight producers, five injectors, and five observation wells were included in the patterns. Injection for the combustion phase (August 1976 through April 1981) was 10.1 BCF of air and 2.64 MM BBL of water. Cumulative water injection over project life was 5.15MM barrels. The combustion phase resulted in recovery of 626 M barrels of 19/sup 0/ API crude. Cumulative oil production amounted to 685 M barrels or 35% of the oil in place. Total expenditures for the project through June 30, 1982, were $10,450,790. Development costs for wells and equipment were $1,710,779.36; production and research services have amounted to $1,075,311; and lease operations and maintenance were $4,382,228. Decontrol tax amounted to $1,300,784. Total cost per barrel of oil produced was $17.37 based on net production assuming one-eighth royalty. Net income based on net production was 26.7% of the revenue. Based on the data taken during the six year contract life, the Bodcau In Situ Combustion Project has proven to be both an economical and technical success.

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Site visit report:  Duke Power Company, Allen Steam Station, Belmont, North Carolina. Final report

This report details the activities, facilities, and equipment used to sample raw feedstock and waste solids at Duke Power Company's Allen Plant. Explanation of sampling locations, deviations from the test plan, sampling techniques (in accordance with the Fossil Energy Waste General Sampling Guideline Document), and plant design are reviewed. Versar Inc.'s responsibility in this project involves the sampling, containerization, labeling, and distribution of samples. Distribution of samples was coordinated through the Versar Office in Springfield, Virginia; therefore, no detailed description of distribution procedures is given in this document.

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Stickiness of retorting oil shales on stainless steel

The stickiness of oil-shale particles was measured as the angle of tilt required to cause a thin layer of 6.4-mm particles to slide from rest on a stainless-steel surface. The test tray was enclosed in a heating chamber within an electric furnace and was heated through the retorting temperature range, 350 to 450/sup 0/C, in an argon atmosphere at a rate of about 4/sup 0/C/min. We tested three grades of raw shale: 20, 93, and 197 L/Mg; also tested were blends of one part of each of the two richer shales with 3.5 parts of previously burnt shale. Surprisingly, we found that the mean 50% slide angle decreased with increasing grade, the values being 27.7, 21.7, and 20.4 deg, respectively, for the raw shales. The trend was the same, but less steep, for the shales diluted with burnt shale.

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Compound-type distribution in shale oils produced by flash hydropyrolysis of eastern US oil shale

Rockwell Internation has been developing technology for the flash hydropyrolysis (FHP) of carbonaceous feedstocks under U. S. Department of Energy (DOE) sponshorship since 1975. FHP is based on the high temperature (1100 to 1900 degrees F) reaction of pulverized soild carbonaceous feedstocks with hydrogen in a single-stage, short-residence-time, entrained-flow reactof. Gases and liquids are produced in the reactor and unreacted material forms a dry. Free-flying char. Following product gas quench, liquid products are seperated and gases are processed for recycle and product recovery. By varying the reactor operating conditions, the makeup of the product slate can be controlled over a broad range - from predominately a sycrude oil with SNG byproduct, to SNG with a relatively pure benzene byproduct, to SNG alone as the sole hydrocarbon product.

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Background data on utility sector fossil fuel-fired facilities: Final report

An analysis is provided of the range of potential impacts on utility and industrial fossil fuel-fired facilities and specific emerging technologies resulting from the implementation of regulations under the Resource Conservation and Recovery Act of 1976 (RCRA). The impact analysis includes the estimation of the costs associated with the implementation of RCRA for non-hazardous and hazardous material disposal in the utility industry. The study also includes an assessment of other Federal environmental regulations as they pertain to RCRA and fossil fuel-fired facilities.

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Bureau of Mines apparatus for thermal analysis. Simultaneous DTA--TG--EGA for oil shale and solid fuels

Apparatus providing simultaneous differential thermal analysis, thermogravimetry, and evolved gas analysis, has been developed by the Burewa of Mines specifically fof thermal sutdy of oil shale and other solid, natural fuels. The apparatus is described in detail, and simultaneous analyses on a single sample of an oil shale mineral, nahcolite, and a thermal analysis demonstaation compound, calcium oxalate monohydrate, and presnted to demonstrat the instruments capabilities.

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Investigation of the extraction of hydrocarbons from shale ore using supercritical carbon dioxide. Final technical report

Using supercritical carbon dioxide as a solvent, hydrocarbons were extracted from oil shale at low temperature under moderate pressure. Operational variables were studied. The average amount of oil removed corresponded to about 1% of the organic matter of the shale. The maximum yield was 0.73 gallons of oil per ton of shale or about 1.3%. Water was extracted from the shale in greater amounts than was oil. Extraction at temperatures below 400/sup 0/F did not produce high enough yields for the process to be commercially viable. Yield did increase with smaller particle size, increased time of extraction, increased temperature, and increased density of the solvent.

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Research and information needs for management of tar sands development. Interim report Apr-May 83

The report discusses important research and information needs for federal lease management of lands with tar sands resources. Short-term needs include more complete definition and characterization of deposits, hydrology, and regions downwind from tar sands areas. Longer-term needs include demonstration-scale operations to resolve production, waste management, and reclamation problems and to provide opportunities for measurement, analysis, and assessment of mining and processing wastes and emissions. Most of the known federal tar sands resource is in eastern Utah and contains about 25 billion barrels of bitumen. Recent legislation provides that existing mining claims and oil and gas leases may be converted to combined hydrocarbon leases including tar sands. Federal approval, which must be applied for by November 1983, is a condition for conversion.

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Geology of Eocene rocks and oil yields of Green River oil shales on part of Kinney Rim, Washakie Basin, Wyoming

Geology and oil-yield data are presented for a 58-sq-mile area encompassing the U.S. Department of the Interior oil-shale leasing program tracts in the W. Washakie Basin. Sweetwater County, Wyoming. Lithology and oil yields of samples from 3 Bureau of Mines coreholes are evaluated and correlated with Kinney Rim surface sections measured and sampled by the U.S. Geological Survey. Minable sections of oil shale averaging up to 25 gal of oil per ton crop out on Kinney Rim in the Laney Member of the Green River Formation. Thick oil-shale sections in the Laney Member that average 15 gal per ton represent 155 million bbl of oil in place per sq mile. In the lower part of the Green River Formation, the Tipton Shale Member contains a 20-to 40-ft section averaging 15 gal per ton. Beds of high-volatile C bituminous coal up to 6 ft thick are present in intertongued parts of the lower Green River Formation and upper Wasatch Formation. (13 refs.)

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