AndreaBozzo/ceres-open-data-index huggingface dataset:
Review of coal-supply models and forecasts:  a critique of the current state-of-the-art

The outputs from various coal supply modeling systems influence decisions in diverse areas (e.g., the Department of Interior's establishment of coal leasing goals for federal lands; the Department of Energy's Fossil Energy Research and Development programs). Widely employed coal supply models combine dependence on data streams of doubtful accuracy and appropriateness with tenuous methodological assumptions. Similarities in the structural assumptions of the models and in assumed values of driving variables have resulted in similar forecasts. Many policymakers feel these models project energy futures with implausibly low coal prices. This report provides an overview of ongoing analyses of coal supply models at the National Center for Analysis of Energy Systems at Brookhaven National Laboratory, and includes discussion of model philosophies, overview of methodologies (comparative anatomy), comparison of conceptual structure, review and evaluation of recent forecasts, and recommendations.

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Sulfur recovery from hot coal gas desulfurization processes. Quarterly progress report, October 15-December 31, 1984

Recovery of sulfur in elemental form from the SO/sub 2/-containing regenerator offgas will, in general, preferably involve three processing steps. These include SO/sub 2/ concentration/purification, SO/sub 2/ reduction/sulfur production, and tail gas treating. The prime candidate processes to date have been operated at near-atmospheric pressure. Based on currently available information, including commercial experience histories, we conclude that Wellman-Lord is the most viable SO/sub 2/ concentration/purification candidate for this study. Although the assessment of the Shell/UOP copper oxide process has not been completed, we recommend that the process selection conceptual designs proceed based on the use of Wellman-Lord technology with the understanding that if the Shell/UOP or other candidate process assessment proves them to be preferred, it will replace Wellman-Lord in the final conceptual design/economic evaluation, i.e., Project Task 3. METC's agreement with this recommendation has permitted us to continue with our process selection process. We have concluded that RESOX, Allied, BSRP and Augmented Claus are the highest potential SO/sub 2/ reduction/sulfur production candidates and should be assessed in more detail as a prelude to selection of the total preferred process configuration. Some five tail gas candidates are recommended for further analysis. These include the BSR/Stretford, BSR/MDEA, BSR/Claus, BSR/Selectox and incineration/recycle to the SO/sub 2/ concentration/purification unit. We have concluded that eleven configurations consisting of combinations of technology candidates should be considered prior to selection of the preferred process configuration to be tested in the Task 2 experimental program and the Task 3 final conceptual design/economic evaluation. 70 refs., 7 figs., 13 tabs.

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First year peat resource assessment in Georgia. Final report

The most extensive peat deposits occur in the southernmost areas of Georgia lying in the Coastal Plain. The Coastal Plain is subdivided into four geologic regions: Coastal Terraces, Tifton Uplands, Dougherty Plains, and Fall Line Hills (see Figures 1 and 2). The size of the deposits and the number of occurrences of deposits decline as one proceeds from the Coastal Terraces toward the Fall Line Hills. While not formed by glaciation, as are the majority of peat areas in the world, the coastal region of Georgia is made up of sands underlain by limestone and is marked with marshy depressions and ponds which support the peat-forming aquatic plants. The climate is sufficiently cool and humid to prevent rapid evaporation and, except for the documented ''25-year drought cycle'', has a few dry periods of greater than seasonal duration. The peat deposits can be classified by the size and number of occurrences of the wetland depressions. In studying the Georgia deposits, three classifications seem appropriate: (1) Fully Developed Swamps, (2) Coastal Sounds and Marsh Regions, and (3) Carolina Bays. The locations of these regions are shown on maps. The Fully Developed Swamps encompass several hundred thousand acres and have the largest potential fuel grade peat deposits. In Georgia, there is only one area in this category, the Okefenokee Swamp. The Swamp covers approximately 440 thousand acres and peat depths range from 2.2 to 7.3 meters (6 to 20 feet). 5 refs., 18 figs., 12 tabs.

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Development of gas analysis systems. [Detailed description, specifications, etc]

Several independent exhaust gas analysis systems are installed at the Grimethorpe Experimental Pressurized Fluidized Bed Combustion Facility for operational and experimental purposes. The constituents measured are O/sub 2/, CO, CO/sub 2/, SO/sub 2/, SO/sub 3/, NO, NO/sub x/, Cl, F, propane and total hydrocarbons. The report describes the design of the systems and assesses their performance. It also describes the modifications that have been carried out since September 1980 to enable the required accuracy and reliability to be achieved.

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Surface acoustic wave deposition sensor

The US Department of Energy's, Morgantown Energy Technology Center (METC) has studied the use of surface acoustic waves (SAWs) in instrumentation systems that monitor deposition level and rate of change in high-temperature, corrosive-atmosphere coal conversion and utilization systems. Such deposition monitoring systems are needed to design and maintain efficient coal conversion systems. This report reviews the development of the deposition sensor and the associated testing system from the first intrusively designed rectangular, stainless steel sensor to the current cylindrical, glass-ceramic, nonintrusively designed sensor. Tests in a laboratory deposition facility have shown that the latter design, after proper calibration, is capable of monitoring deposition up to the design maximum of 3.10 x 10/sup 5/ mg/m/sup 2/ (200 mg/in./sup 2/) at room temperature. Changes from this calibration occur at higher temperatures. Tests at temperatures under 100/sup 0/F above room temperature indicate that further work is needed to permit use of this deposition monitoring technique at elevated temperatures.

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Wet carbonization of lump-size low-rank coals by a Novel Non-Slurry Approach. Progress report, May-July 1985

Work continued this quarter on the design and procurement of equipment to construct the wet-carbonization process research unit(PRU). The PRU is being designed to process about 100 lb/h of as-received coal. Nine batch wet-carbonization tests were conducted this quarter. Tests have now been conducted with all four coals specified in the approved test plan. The four coals are lignites from the Indianhead and Center mines, North Dakota, subbituminous coal from the Rosebud mine, Montana, and lignite from the South Hallsville mine near Martin Lake, Texas. The operating conditions for the tests were temperatures, pressures, and residence times in the range of 400/sup 0/ to 650/sup 0/F, 250 to 3300 psia, and 0 to 60 minutes, respectively. Results to date show that overall component conversions for the two North Dakota lignites are similar for the tests conducted at comparable conditions. The Texas lignite is less reactive and the Montana Rosebud subbituminous coal to significantly less reactive than the North Dakota lignites. Handling characterization tests were conducted with raw and wet-carbonized coals. These tests include drop-shatter tests, bulk and particle density measurements, and particle shrinkage determinations. Particle-size reduction due to drop-shatter testing of wet-carbonized coal was greater than that of the corresponding feed coal and increased with wet-carbonization severity. However, once air-dried, the raw coal decrepitated (crumbled) much more readily than the air-dried wet-carbonized coal. Bulk and particle densities of the wet-carbonized coal products decreased with increasing temperature and residence time. Anaerobic biogasification potential assays were continued this quarter to determine the biodegradability of liquid product samples from the batch wet-carbonization tests. 16 figs., 8 tabs.

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Fixed-bed gasification research using US coals. Volume 11. Gasification of Minnesota peat. [Peat pellets and peat sods]

A single-staged, fixed-bed Wellman-Galusha gasifier coupled with a hot, raw gas combustion system and scrubber has been used to gasify numerous coals from throughout the United States. The gasification test program is organized as a cooperative effort by private industrial participants and governmental agencies. The consortium of participants is organized under the Mining and Industrial Fuel Gas (MIFGa) Group. This report is the eleventh volume in a series of reports describing the atmospheric pressure, fixed-bed gasification of US coals. This specific report describes the gasification of peat pellets and peat sods during 3 different test periods. 2 refs., 20 figs., 13 tabs.

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Fixed-bed gasification research using US coals. Volume 12. Gasification of Absaloka/Robinson subbituminous coal

A single-staged, fixed-bed Wellman-Galusha gasifier coupled with a hot, raw gas combustion system and scrubber has been used to gasify numerous coals from throughout the United States. The gasification test program is organized as a cooperative effort by private industrial participants and governmental agencies. The consortium of participants is organized under the Mining and Industrial Fuel Gas (MIFGa) Group. This report is the twelfth volume in a series of reports describing the atmospheric pressure, fixed-bed gasification of US coals. this specific reports describes the gasification of Absaloka/Robinson subbituminous coal. This volume covers the test period June 18, 1984 to June 30, 1984. 4 refs., 20 figs., 18 tabs.

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Fixed-bed gasification research using US coals. Volume 18. Program data summary and correlations. [C/sub 2/ and C/sub 3/ hydrocarbons]

A single-staged, fixed-bed, Wellman-Galusha gasifier coupled with a hot, raw gas combustion system and scrubber has been used to gasify numerous coals from throughout the United States. The gasification test program is organized as a cooperative effort by private industrial participants and government agencies. The consortium of participants is organized under the Mining and Industrial Fuel Gas Group (MIFGa). This report is the eighteenth volume in a series of reports describing the atmospheric pressure, fixed-bed gasification of US coals. This specific report summarizes the results of eighteen different gasification tests in which fourteen different fuels were gasified from August 1982 to August 1985. The summaries and analyses reported here include correlations of product yields and compositions with coal analyses and gasifier operating conditions. Also included here are discussions of limitations to throughput, transient response of the gasifier, the grate performance model, and a discussion of electrostatic precipitation in coal gas medium. 25 refs., 41 figs., 6 tabs.

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Fixed-bed gasification research using US coals. Volume 19. Executive summary

A single-staged, fixed-bed, Wellman-Galusha gasifier coupled with a hot, raw gas combustion system and scrubber has been used to gasify numerous coals from throughout the United States. The gasification test program is organized as a cooperative effort under the Mining and Industrial Fuel Gas Group (MIFGA). This report is the nineteenth volume in a series of reports describing the atmospheric pressure, fixed-bed gasification of US coals. This volume briefly summarizes the results of eighteen different gasification tests in which fourteen different fuels were gasified from May 1982 to August 1985. The design gasification performance of all coals evaluated are summarized. In addition, summary design and economic data for industrial coal gasification systems are presented. 28 refs., 2 figs., 22 tabs.

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Design, construction and operation of a coal gasification process development unit. Final report

A 30 tons per day high rate, dry feed, entrained coal gasification process development unit was designed, constructed and operated to demonstrate the scale-up ability from an existing one-half ton per day design and to provide data for further scale-up system components. The unit was operated for a total of 2177 hours, the longest continuous operation being 129 hours. Controlled continuous dry-feeding of pulverized coal into the gasifier at pressures between 100 to 260 psia was achieved. A highly redundant and rapid response control and safety system was developed through extensive analytical studies and operational tests. Operational problems with equipment are described and discussed. Gasifier performance data were obtained with six different feedstocks, two Utah bituminous coals, an Eastern bituminous coal from Pittsburgh Seam, a Wyoming subbituminous coal, a North Dakota lignite, and a green petroleum coke. Reactor throughputs of up to 754 lbs/hr/ft/sup 2/ or 317 lbs/hr/ft/sup 3/, gas yields of 32 SCF/lb coal and gas heating values of 294 Btu/SCF were achieved. Data from steady state test periods with Utah coal from the SUFCO mine were correlated with a computer model. Preliminary design and economic studies were completed for three different sizes of scaled-up plants in which coal would be gasified and the gas used to synthesize methanol. Production costs were shown to be competitive with the cost of producing methanol from natural gas. A new sulfur-tolerant, combined shift and methanation catalyst developed by Haldor Topsoe was successfully tested for a total of 1080 hours with gas from the gasifier. 16 refs., 100 figs., 82 tabs.

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Analysis of options for management of spent Stretford solution. [Purge of Stretford solution]

During each cycle of the Stretford process a small percentage of the sulfide present in the feed gas is irreversibly converted to thiosulfate and sulfate, and cyanide is irreversibly converted to thiocyanate. The accumulation of sulfates in the Stretford solution reduces the solubility of the active Stretford chemicals (i.e., sodium vanadate and anthraquinone-disulfonic acid (ADA)). This decreases the rate of oxidative regeneration. To maintain the thiosulfate, sulfate and thiocyanate concentrations at acceptable levels, a continuous purge, or blowdown, of the Stretford solution is required. The continuous purge of Stretford solution results in a loss of active chemicals which must be replaced and ultimately increases Stretford operating costs. In addition, the blowdown must be reclaimed, treated, and/or disposed which also adds to the operating costs. This report presents an analysis of waste-management alternatives for handling the blowdown stream produced from the Stretford process. The objective of this study is to evaluate the relative economics of the most promising alternatives available for managing spent Stretford solution by comparing technical feasibility, performance, and costs associated with the alternatives. The available Stretford solution-characterization data and waste-management options were identified by reviewing literature sources. The waste-management options identified were then screened based on technical, economic and environmental criteria to identify the most promising set of alternatives. Finally, a comparative economic analysis was performed on the most promising set of alternatives using the Stretford process at the Great Plains Gasification Associates (GPGA) facilty as the basis for comparison. 23 refs., 5 figs., 29 tabs.

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Re-completion in the Devonian shale. Final report. [Foam frac and nitrogen frac]

As a result of a jointly sponsored Mitchell Energy Corporation/USDOE program, two different stimulation techniques were applied to the Devonian shale in a non-historically producing area. The two types, namely a foam frac and a nitrogen frac, were incorporated because of the low reservoir pressure and the lack of information of the sensitivity of the shale in this area to water; as no core information was available. The foam frac (consisting of 75% nitrogen and 25% water) used in the lower shalezone emplaced 60,000 pounds of sand; with a maximum sand concentration in the reservoir of 1 1/2 pounds per gallon. The 100% nitrogen frac utilized in the upper shale zone did not have proppant associated with it. In both cases, insufficient gas production rates resulted. Due to the fact that essentially only one test was performed, no definite conclusions about the potential of the Devonian shale in this area can be made. However, it was found that gas does occur in the shale, but at what quantities could not be determined. With regard to the stimulations conducted, it is suggested that the nitrogen frac is somewhat of an inefficient technique in that essentially no hydrocarbons were produced as a result of it. On the other hand, the foam frac; which emplaced 60,000 pounds of sand (at low concentrations,5388 ); yielded some hydrocarbon recovery and suggests that proppant placement into the shale reservoir may be required to maintain the induced fracture.

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Analysis of fracturing mechanisms in naturally fractured rocks. Fifth quarterly report, 1 October 1984-31 December 1984. [Hydrostone]

Progress reports are presented for tasks 1 through 4. Task 1 - Hydraulic/Natural Fracture Interaction. This task was completed in this reporting period. The primary result is a criterion that can be used to predict hydraulic/natural fracture interaction in Devonian shale gas reservoirs. Task 2 - Dynamic/Natural Fracture Interaction. Work during this reporting period focused on development of a scaled down dynamic stimulation tool. Task 3 - Flow Characteristics of Natural Fractures. An initial test matrix was formulated during this period. The testing has been delayed as discussed in item 5 below. Task 4 - In Situ Stresses in the Appalachian Basin. As mentioned in the last report, the milestone regarding a critique of techniques available for measuring stresses is being kept open pending the results from some parallel projects on stress measurement: LLNL's S-wave anisotropy approach, wireline work being done by Columbia University, and borehole elongation work being done for Sandia by SAIC. The theoretical part of the borehole work has been completed and is included in this document along with a detailed analysis of the influence of pore pressure on strain recovery methods in general. 44 refs., 25 figs., 3 tabs.

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Industrial scale peat use demonstration at Syl Laskin Steam Electric Station: Final report

Minnesota Power and the Minnesota Department of Natural Resources conducted the Industrial Scale Peat Use Demonstration in 1985 at the Syl Laskin Steam Electric Station. The Station is located near Hoyt Lakes, Minnesota. The two unit station commissioned in 1951 was designed to fire bituminous coal. Its current capacity is 88 MW (2 units of 44 MW each) fired with western subbituminous coal. The Demonstration focused on two areas: the Syl Laskin Station and the Fens Bog areas northwest of Cotton, Minnesota. Two past producers were contracted to produce and stockpile up to 25,000 tons of sod peat. One trucking company was contracted to transport the peat to the Station, where it was received, mixed with coal in various proportions, and burned between June 1985 and January 1986. The results of this demonstration are provided in this report. 9 figs., 10 tabs.

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Chemical coal cleaning process and costs refinement for coal-water slurry manufacture

This report describes the results of process and cost refinement studies for the manufacture of ultra-clean coal-slurry fuel for direct-fired gas turbines. The work was performed as an extension to an earlier contract in which AMAX R and D supplied METC with two lots of highly beneficiated coal slurry fuel for use in the Heat Engines program. A conceptual design study and cost estimate supplied to METC at that time indicated that a combined physical and chemical cleaning process could produce ultra-clean  fuel at a competitive price. Laboratory and pilot plant studies performed for the contract extension further defined the process conditions and operating and capital costs to prepare coals containing from 0.2 to 1.0% ash as slurry fuels. A base-case fuel containing coal cleaned to 0.5% ash in a 1000 cp slurry containing 55% coal was $4.16 per million Btu when produced in quantities required to fuel a 500 MW gas-turbine generating station. Coal slurry fuel production costs as low as $3.66 per million Btu were projected for coals cleaned to 1.0% ash. 12 refs., 23 figs., 63 tabs.

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Differential optical-absorption techniques for diagnostics of coal gasification. Technical progress report, January-March 1983

The application of differential optical absorption (DOA) techniques for the in-situ determination of the chemical composition of coal gasification process streams is investigated. Absorption spectra of relevant molecular species and the temperature and pressure effects on DOA-determined spectral characteristics of these species will be determined and cataloged. A system will be configured, assembled, and tested. 87 references, 1 figure, 1 table.

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A study of combustion spectra from an entrained-flow gasifier: Final report

The objective of this study was (a) the development of a measurement technique designed to obtain real-time information on several optical emission characteristics from reactors of entrained-flow gasifiers; and (b) demonstration of the applicability of this technique in the field. The gasifier chosen for field demonstration was the Mountain Fuel Resources, Inc. (MFR) pilot plant located near Salt Lake City, Utah. The MFR plant is an oxygen-blown entrained-flow unit with the capacity of 3000 lb/hr of coal at pressures up to 300 psig. The approach chosen in this study was to make simultaneous measurements of optical emission both from the gas and from coal particles in the interior of the gasifier reactor. These measurements were selected because they provide direct information from the reaction zone, and therefore should provide the most rapid response to changes within the reactor. Characterization of gas emission spectra was made by means of an optical multichannel analyzer (OMA) over the spectral range from about 300 to 850 nm. The intensity of continuum radiation from particles was measured at two wavelengths, and used for time-resolved temperature measurements by two-color pyrometry (TCP). The present study confined itself only to the development of the required diagnostic system and the demonstration of feasibility of such simultaneous (OMA and TCP) measurements in the MFR unit. However, the obvious rationale for the choice of this advanced instrumentation was its usefulness for the future development of reliable on-line monitors for gasifiers.

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