AndreaBozzo/ceres-open-data-index huggingface dataset:
Rawlins UCG Demonstration Project. Final technical progress report, May 10, 1988--August 9, 1988

The US Department of Energy and Energy International, Inc. have entered into a Cooperative Agreement to conduct a cost-shared field test demonstrating the operation of commercial-scale steeply dipping bed underground coal gasification (UCG) modules to provide the synthesis gas for a small-scale commercial ammonia plant. The field test and the commercial ammonia plant will be located near Rawlins, Wyoming. During this demonstration test, two or more modules will be operated simultaneously until one module is completely consumed and an additional module is brought on line. During this period, the average coal gasification rate will be between 500 and 1,200 tons per day. A portion of the raw UCC product gas. The UCG facility will continue to operate subsequent. to the demonstration to provide feedstock for the commercial plant. Energy International is responsible for accomplishing specific objectives in accordance with the Statement of Work by designing, installing, operating and monitoring the performance of the UCG modules as the feedstock source for the small-scale commercial ammonia plant. During this period, the project activities focused on project structuring, financing, and project management activities. Because the negotiations with investors were not completed on the schedule anticipated, adjustment of the schedule and activities was necessary. All major activities requiring the expenditure of funds were halted and work was suspended pending the availability of funds and new schedules. These changes have dictated the level of progress or delays for all of the tasks of the project throughout the period of this report.

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Molten carbonate fuel cell technology improvement

The overall objective of this program is to define a competitive Coal Gasification/Molten Carbonate Fuel Cell power plant and the associated technology development requirements and to develop an improved cell configuration for molten carbonate fuel cans which has improved performance, has reduced cell creep and electrolyte management consistent with 40,000 hour projected life, reduces existing cell cost, and is adaptable to a range of power plant applications.

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Pinedale unit MHF experiments. Final report. [Northern Green River Basin in Wyoming]

Three MHF experiments have been performed in a tight reservoir in the Northern Green River Basin at a depth interval between 8,000 feet and 12,000 feet. A total of 894,190 gallons of fluid and 2,715,000 pounds of sand were pumped in three stages in two wells with the limited entry technique. Fluid viscosities were designed to give propped lengths of 1,000 to 1,500 feet and proppant sand beds having heights greater than 50 percent of the thickness of each sandstone fractured. The experiments included laboratory research to design limited entry with perforations through one and two strings of casing. Field data analysis to determine fracture gradients and extent of perforation erosion has been complicated by a dependence of friction pressure in tubular goods upon sand concentration and by an apparent large variation in minimum principal in-situ stress between sandstones simultaneously fractured with the limited entry technique. A high proppant concentration was used to assure that production would be limited to reservoir characteristics, rather than fracture conductivity. A comparison was made with results of prior hydraulic fractures propped with partial monolayer. Resulting production capacity to date has been only about one-fifth that projected in the National Gas Survey report. Evaluation of the resulting production capability and the cost of the hydraulic fracture treatment indicates that the stimulation technique employed is not commercially feasible at this time for the reservoir conditions tested..

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Depositional sequence analysis and sedimentologic modeling for improved prediction of Pennsylvanian reservoirs (Annex 1)

Interdisciplinary studies of the Upper Pennsylvanian Lansing and Kansas City groups have been undertaken in order to improve the geologic characterization of petroleum reservoirs and to develop a quantitative understanding of the processes responsible for formation of associated depositional sequences. To this end, concepts and methods of sequence stratigraphy are being used to define and interpret the three-dimensional depositional framework of the Kansas City Group. The investigation includes characterization of reservoir rocks in oil fields in western Kansas, description of analog equivalents in near-surface and surface sites in southeastern Kansas, and construction of regional structural and stratigraphic framework to link the site specific studies. Geologic inverse and simulation models are being developed to integrate quantitative estimates of controls on sedimentation to produce reconstructions of reservoir-bearing strata in an attempt to enhance our ability to predict reservoir characteristics.

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Lithologic description of cored wells No. 20402 and No. 20403 in the Devonian shale in Lincoln County, West Virginia

A detailed lithologic description of the Upper Devonian Shale as observed in cores taken from two wells near Ranger, Lincoln County, West Virginia is presented. One of the cored wells, No. 20402 (West Virginia Permit No. 1636), is located approximately three miles southwest of Ranger, West Virginia on Ten Mile Creek while the second cored well No. 20403. (West Virginia Permit No. 1637), is located near the first well, but is located on Fourteen Mile Creek. Analysis of the core material is providing information to be used in designing stimulation techniques for the improvement of gas production from the Devonian Shale. (JRD)

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Field verification of CO sub 2 -foam

The objectives of this project are to: (1) conduct reservoir studies, laboratory tests, simulation runs, and field tests to evaluate the use of foam for mobility control or fluid diversion in a New Mexico C0{sub 2} flood, and (2) evaluate the concept of C0{sub 2}-foam in the field by using a reservoir where C0{sub 2} flooding is ongoing, characterizing the reservoir, modeling the process, and verifying the effectiveness. Seven tasks were identified for the successful completion of this four-year project: (1) evaluate and select a field site, (2) develop an initial site-specific plan, (3) conduct laboratory C0{sub 2}-foam mobility tests, (4) perform reservoir simulations, (5) design the foam slug, (6) implement a field test, and (7) evaluate results. Accomplishments for the following topics are presented: project planning; surfactant selection; foam slug design; project monitoring; and reservoir simulation studies.

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On-line measurement of the alkali and particulate loading of the process stream of a fixed-bed gasifier: Research report. [Two-color laser transmissometer]

On-line analytical instrumentation developed at the US Department of Energy's Morgantown Energy Technology Center (DOE/METC) to monitor particle and alkali loading was successfully used on the process stream of a coal gasifier to measure contaminant levels before and after combustion of the coal gas in a turbine-simulator combustor at the General Electric Research Laboratories in Schenectady, New York. A two-color laser transmissometer was designed and built to simultaneously measure particle median size and number density in situ in a highly loaded gas process stream. Four of the instruments successfully monitored particle number density at different locations on the coal gasifier-combustor system. The particle loading measurements ranged from 150 ppM to greater than 1000 ppM. Temporal variations observed in the particle loading data correlated with physical events perturbing the gasifier system. A fiber-optic flame atomic emission spectrometer was designed and built to measure sodium and potassium concentrations in gas samples extracted from the process stream. Two of the instruments and an earlier system built at Ames Laboratory at Iowa State University successfully measured alkali levels before and after the combustor using an extractive probe. The alkali monitors found contaminant levels in the fuel gas lower than values determined from extractive filter samples, the average value being 48 ppB total alkali. The ratio of sodium to potassium was constant across the combustor. 8 refs., 12 figs., 3 tabs.

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Hydrogen separation by ceramic membranes in coal gasification. Final report

The general objective of this project was to develop hydrogen permselective membranes for hydrogen production from coal gas. The project consisted of the following tasks: (i) membrane preparation and characterization, (ii) membrane stability testing, and (iii) analysis and economic evaluation of a membrane-assisted ammonia from coal process. Several oxides (SiO{sub 2}, TiO{sub 2}, Al{sub 2}O{sub 3}, B{sub 2}O{sub 3}) in dense (or nonporous) form were identified to be permselective to hydrogen at elevated temperatures. To obtain reasonable permeance it is necessary that the membrane consists of a thin selective layer of the dense oxide supported on or within the pores of a porous support tube (or plate). Early in the project we chose porous Vycor tubes (5mm ID, 7 mm OD, 40 {Angstrom} mean pore diameter) supplied by Corning Inc. as the membrane support. To form the permselective layer (SiO{sub 2}, TiO{sub 2}, Al{sub 2}O{sub 3}, B{sub 2}O{sub 3}) we employed chemical vapor deposition using the reaction of the chloride (SiCl{sub 4}, etc.) vapor and water vapor at high temperatures. Deposition of the selective layer was carried out in a simple concentric tube reactor comprising the porous support tube surrounded by a wider concentric quartz tube and placed in an electrically heated split tube furnace. In one deposition geometry (the opposing reactants or two-sided geometry) the chloride vapor in nitrogen carrier was passed through the inner tube while the water vapor also in nitrogen carrier was passed in the same direction through the annulus between the two tubes. In the other (two-sided) geometry the chloride-containing stream and the water-containing stream were both passed through the inner tube or both through the annulus.

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Surface adhesion of low-rank coal ash: Quarterly report, April 1986-June 1986

The adhesive properties of ion-exchanged Center lignite ash were evaluated using the sticking apparatus. ASTM ash from ion-exchanged Center lignite was suspended on a platinum and heated in a methane-oxygen flame of adiabatic temperature between 1650/sup 0/ and 1750/sup 0/C. The resultant molten slag was dropped onto an oxidized carbon steel surface. The ion-exchanged Center lignite ash had a sticking temperature of 550/sup 0/C. The sticking temperature of the raw Center lignite ash was considerably lower (approx.375/sup 0/C) as reported previously. The higher sticking temperature of the ion-exchanged ash was probably due to removal of sodium and calcium from the Center lignite. The gas-fired vertical tube furnace was used to form deposits with Center lignite, San Miguel lignite, Rosebud sub-bituminous coal and Navajo sub-bituminous coal. The objectives of these tests were to evaluate (1) the effect of oxygen partial pressure during combustion on deposit characteristics of the four coals and (2) the effect of hot zone temperature on deposit characteristics of Rosebud and Navajo sub-bituminous coals. Increasing the furnace oxygen partial pressure from 20 to 60% O/sub 2/ was generally found to decrease the deposit formation rates and strengths. X-ray diffraction analyses of deposits formed during the 60% O/sub 2/ tests indicated that less alkali/silica interactions had occurred compared to the tests performed with 20% excess air. Decreasing the furnace hot zone temperature was found to decrease deposit formation rate and strength for the Rosebud coal. These trends were also observed for Rosebud coal which had been ion-exchanged. 3 refs., 5 figs., 6 tabs.

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Extractors manual for Oil Shale Data Base System: Major Plants Data Base

To date, persons working in the development of oil shale technology have found limited amounts of reference data. If data from research and development could be made publicly available, however, several functions could be served. The duplication of work could be avoided, documented test material could serve as a basis to promote further developments, and research costs could possibly be reduced. To satisfy the engineering public's need for experimental data and to assist in the study of technical uncertainties in oil shale technology, the Department of Energy (DOE) has initiated the development of a data system to store the results of Government-sponsored research. A technology-specific data system consists of data that are stored for that technology in each of the specialized data bases that make up the Morgantown Energy Technology Center (METC) data system. The Oil Shale Data System consists of oil shale data stored in the Major Plants Data Base (MPDB), Test Data Data Base (TDDB), Resource Extraction Data Base (REDB), and Math Modeling Data Base (MMDB). To capture the results of Government-sponsored oil shale research programs, documents have been written to specify the data that contractors need to report and the procedures for reporting them. The documents identify and define the data from oil shale projects to be entered into the MPDB, TDDB, REDB, and MMDB, which will meet the needs of users of the Oil Shale Data System. This document addresses what information is needed and how it must be formatted for entry to the MPDB for oil shale. The data that are most relevant to potential Oil Shale Data System users have been divided into four categories: project tracking needs; economic/commercialization needs; critical performance needs; and modeling and research and development needs. 2 figs., 31 tabs.

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Performance evaluation of a ceramic fabric bag filter on a bench-scale coal gasifier: Final report

The objective of this project was to demonstrate the technical and economic feasibility of using high-temperature ceramic filters for particulate control in combined cycle coal gasification power plants. The overall program strategy involved three major tasks: (1) investigation of alternate designs; (2) bench-scale gasifier filter evaluation; and (3) economic assessment of a commercial-scale gasifier filter. This report presents detailed descriptions and conclusions for each task. The tests and preliminary economic assessment show that ceramic bag filters are potentially attractive candidates for gasifier particulate cleanup. 70 figs., 33 tabs.

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National benefits/costs of enhanced oil recovery research. Final report

This analysis, an updating of an earlier analysis performed in mid-1974 for the Bureau of Mines, is an assessment based upon available information of the benefits/costs of planned Federal R and D programs in enhanced oil recovery technologies. The primary type of benefit quantified is the national savings to be realized as a result of having cheaper supplementary oil available from enhanced recovery than would be otherwise available under uncertain alternative futures. Alternative types of benefits are also reviewed, including those associated with avoiding more expensive re-entry of stripper wells at a later time, with the balance of payments value of enhanced recovered oil, and with enhanced recovered oil becoming part of a national emergency stockpile. Other benefits unquantified are those associated with insurance and portfolio values. Assuming ''upper tier''prices ($11.28/Bbl) and a discount rate of 6 percent per year the estimated benefit/cost ratios are: between 3 and 7 assuming that enhanced recovered oil will delay the requirement for more expensive oil from offshore sources, or, alternatively, between 2 and 8 assuming that enhanced recovered oil will delay the requirements for more expensive imported oil. Sensitivity of the benefit/cost ratios to alternative assumptions is illustrated through a number of sensitivity analyses. These analyses indicate that the expected benefits from the development of enhanced oil recovery technology substantially exceed Federal program costs. (DLC)

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Gas separation applications to METC-supported technologies

The objectives of this study were to catalog both hot and cold gas separation technologies, to identify the status and the developers of each, and to identify how these separation processes might be applied to METC-supported technologies for removal of trace contaminants, or purification of gases used in or generated by coal processing. Discussions on gas separation process names, typical feeds, process developers, and operating conditions are provided in the following sections of this report, as well as descriptions of how these gas cleanup techniques would be used in developmental coal conversion technologies. 82 refs., 22 figs., 14 tabs.

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Applications of advanced petroleum production technology and water alternating gas injection for enhanced oil recovery -- Mattoon Oil Field, Illinois. First quarterly technical progress report, 1993

For work during the first quarter of 1993, American Oil Recovery, Inc. targeted completion of the following specific objectives: Convene meetings of Mattoon Project subcontractors in order to plan and coordinate Project activities. Confirm organizational arrangements and plans for implementation of Mattoon Project. Complete most work on detailed analysis of reservoir geology of productive leases in the Mattoon Project. Identify first Facies Defined Subunit for initial injectivity testing to be commenced near the beginning of the second quarter. Identify additional Facies Defined Subunits for injectivity testing and characterization during the second and third quarters. Award subcontract to the Illinois State Geological Survey and commence work on preparation of a geostatistical model (STRATAMODEL) of more than 100 wells on 1,000 acres within the Mattoon Project Area. Obtain oil samples from wells in the identified Facies Subunit for reservoir rock, fluid, and CO{sub 2} compatibility testing by the Illinois State Geological Survey. Design CO{sub 2} injection pumps and injection monitoring equipment configuration. Obtain bids for required pumps and diesel motor. Accomplishments for this quarter are reported.

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Annual report of research and technologic work on coal, fiscal year 1937

The work of various divisions of the Technologic Branch during the fiscal year is reviewed: including a study of the properties and composition of American coals, which has been expanded to meet the needs for information on the suitability of coals for the production of coke, gas, and byproducts; coal-mining investigations covering mining, ventilation, permissibility and use of explosives, movement of strata, permissibility and efficiency of electrical and mechanical equipment, tests of gas and dust explosions and development of means for their prevention, origin of mine fires and methods for their detection and control, and training of miners with reference to safe practices, mine rescue methods, and improvement and maintenance of healthful conditions; preparation of coal (dewatering, drying, clarifying coal-washery water, and dustproofing with oil,7961 ); and coal-utilization research (combustion, carbonization, liquefaction, and complete gasification).

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Plugging techniques that should allow mining through wells. Final report

Research carried out since 1971 on plugging oil wells penetrating minable coal seams has allowed for safe underground mining through wells and recovering heretofore unrecoverable coal reserves. Work conducted under this research has consisted of plugging 27 wells and mining through 7 of them. This report covers the day-to-day record of plugging 23 of these wells and mining through 6 of them.

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Preparation characteristics of anthracites in the Santa River Valley, Peru

Anthracite from beds being developed in the Santa River Valley of northern Peru closely resembles that found in Pennsylvania and is an important factor in the proposed industrial and agricultural development of the valley. A Bureau technical mission visited the area in 1945 to study methods by which coal could best be prepared for local industrial use and general marketing. Experimental work by the mission is described, and test data are presented and interpreted. Recommendations and conclusions with regard to handling coal in mines and preparation plants, preparation of commercial coal, rescreening at the destination, preparation of anthracite for metallurgical use, and the problem of fine coal are presented.

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Drilling rate changes when air drilling is switched to mist drilling. [Claystone]

Eight shallow (30-foot-deep) holes were drilled in four formations to determine if the reduction in penetration rate that usually occurs when air drilling is changed to mist drilling might be due to the physical action of drilling a wet, soapy rock. The results showed an average loss of 9.3%, with the greatest loss occurring in limestone. The softest formation (claystone) showed only a 1.2% reduction in penetration rate; the two sandstones averaged 10.0-percent loss; and the limestone showed a significant 15.8% loss. This indicates that the loss of penetration rate due to wetting the rock while mist drilling is small but would be significant when drilling a long interval. The findings indicate that when drilling hard rocks at the surface with mist instead of air, a penetration rate loss of approximately 12% (compared to the drilling rate with air) will occur due to the effect of jetting the soapy water through the bit onto the formation being drilled.

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Sulfur removal in fluidized-bed combustion. [36 references]

Equilibrium partial pressures of sulfur dioxide over some metal oxides were calculated in order to qualitatively assess the ability of the oxides to absorb SO/sub 2/. At higher temperatures, CaO, SrO, MgO, Li/sub 2/O, and Na/sub 2/O were found to be efficient absorbers, while CoO, CdO, La/sub 2/O/sub 3/, MgO, and Mn/sub 2/O/sub 3/ were found to be borderline absorbers. Decomposition of Li/sub 2/SO/sub 4/, MgSO/sub 4/, MnSO/sub 4/, La/sub 2/(SO/sub 4/)/sub 3/, and CoSO/sub 4/ was studied at higher temperatures. In the range of fluidized-bed combustor operating conditions, Li/sub 2/SO/sub 4/ is very stable while MgSO/sub 4/ and La/sub 2/(SO/sub 4/)/sub 3/ are fairly stable. However, MnSO/sub 4/ and CoSO/sub 4/ are very unstable. The presence of SO/sub 2/ in the gas stream retards the decomposition of MgSO/sub 4/, MnSO/sub 4/, and La/sub 2/(SO/sub 4/)/sub 3/, but has no effect on the decomposition of CoSO/sub 4/. (36 refs.)

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