AndreaBozzo/ceres-open-data-index huggingface dataset:
Factors influencing formation of alkali sulfates in fossil fuel combustion

Alkali metal sulfates are known to be the principal corrodants of heat transfer surfaces in boilers and gas turbines. An experimental study of the gas phase reaction of alkali metals and sulfur oxides was made using a combustion chamber that simulated gas temperatures, velocities and residence times in a large pulverized-coal-fired boiler. The effects of physical mixing patterns generated by altering the burner configurations, as measured by stimulus-response residence time distribution measurements, were correlated with the conversion of alkali to sulfates in various portions of the furnace. Results established that nearly equilibrium levels of alkali sulfates form in the flame zone, dependent only on the physical mixing within the flame. The stimulus-response method of residence time distribution measurement correlated well with the extent of reaction achieved under three mixing conditions produced in the flame, and a prediction equation was developed relating the extent of reaction to holdback and the calculated equilibrium concentrations of alkali sulfates. The principal quantities of alkali sulfate were found to form in the primary flame zone of the furnace with the intensity of physical mixing controlling the near approach to calculated equilibrium levels. This result establishes the importance of vapor phase reactions and leads to the conclusion that successful combating must take place in this region. Additives, including kaolin, mica and calcium oxide, providing varying degrees of inhibition of sulfate formation in the flame with kaolin showing a definite beneficial effect.

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Low interfacial tension and miscibility studies for surfactant tertiary enhanced oil recovery processes. Final report, December 1980-September 1981

The main purpose of this project is to develop an improved basic understanding of how ultralow interfacial tensions arise in oil-brine-surfactant systems. Such tensions must be achieved and maintained during tertiary oil recovery processes if they are to be successful. The effects of temperature and of divalent ion concentration on the structure of aqueous surfactant solutions have been determined. As temperature increases, the salinity range where liquid crystalline phases exist is narrowed. At sufficiently high temperatures the liquid crystal melts and only isotropic phases are observed. These are an aqueous phase and, when partial immiscibility of alcohol and brine occurs, an alcohol-rich phase as well. The effect of divalent ions on aqueous solution structure is basically the same as that of monovalent ions, but smaller quantities of divalent ions are needed to bring about the same phase changes. In the particular system studied addition of one mole of Ca/sup  2/ was equivalent to addition of about 11.5 moles of Na/sup  /. The model of drop size in microemulsions has been extended to include the effects of drop dispersion. A hard sphere model was used to describe dispersion effects. With dispersion, drop size is slightly smaller for both oil-continuous and water-continuous microemulsions than predicted by the previous analysis which considered film properties alone. Further work on the proposed scheme for reducing microemulsion sensitivity to salinity changes is included in an Appendix.

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Fluidized-bed combustion:  combustion of run-of-mine coal in a 12-inch-diameter pressurized fluidized-bed combustor

Direct feeding of run-of-mine (ROM) coal into a pressurized-fluidized bed combustor was performed at the Coal Utilization Research Laboratory; Leatherhead, United Kingdom (U.K.). A twelve-inch diameter rig was operated at 6 atmosphere pressure and 1650/sup 0/F for a period of eighteen hours. Two coals were used, i.e., a U.K. washed coal for initial proving tests and a Pittsburgh No. 8 coal, both sized one inch to zero. Results were encouraging and are presented.

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Performance of fuel feeding rotary valves

During the initial operation up to and including Test Series 1 at the Grimethorpe Experimental Pressurized Fluidized Bed Combustion Facility, a critical problem was maintaining stable fuel flow and resultant temperature stability. Rotary valves were installed in the fuel feed system after the completion of Test Series 1 for operation during the Hot Commissioning Tests in preparation for Test Series 2. The report outlines the successful operational history of the rotary valves up to the end of 1982. Details of the valve design and control system are given as well as a description of the modifications made to the valves following operational experience gained during the Hot Commissioning Tests.

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Studies of the New Albany Shale (Devonian and Mississippian) and equivalent strata in Indiana

A formation of black carbonaceous shale, later named the New Albany Shale, was first recognized in 1837 and reported in 1839 by David D. Owen. Since then, the New Albany has been the subject of numerous investigations by individuals affiliated with the Indiana Geological Survey and others. The present comprehensive investigation, involves petrology, mineralogy, stratigraphy, geomorphology, organic and inorganic geochemistry, and physical properties. The lower part of the New Albany Shale is late Middle Devonian in age, and the upper part is Early Mississippian in age.

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Laboratory data in support of hydraulically fracturing EGSP OH Well No. 3. Final report

Geologic and geophysical interpretations of data from the EGSP OH Well No. 3 show that an organically lean shale has a gradual transition with depth to an organically rich shale and that two layers (bound each shale formation. The laboratory test program was designed to understand the containment and productivity of a hydraulic fracture induced in this well to enhance gas production from the shale. The porosity in the formations of interest, including the upper barrier, the lower barrier, and the organic shales, varied from 6 to 10 percent. The porosity of each formation averaged about 8%. Densities and ultrasonic velocities were used to evaluate dynamic moduli. Over the tested intervals moduli consistently increased with depth. This indicates the possibility of upward migration of an induced fracture. Perforations, therefore, should be limited to the lower portion of the pay sand and it is also advisable to use low injection rates. Of the four fracturing fluids tested, the two code-named Dow II and Hal I caused, respectively, the least amount of matrix permeability damage to the organically lean and organically rich shales. However, the damage caused by the other fracturing fluids were not severe enough to cause any significant permanent reduction in well productivity. The fracture conductivity tests under the influence of fracturing fluids indicated that Hal I and Dow I caused, respectively, the least amount of multilayered fracture conductivity damage to the organically lean and organically rich samples. For monolayer fracture conductivities Dow I caused least damage to the organically lean shale. With the exception of Dow III all other fluids showed good results in the monolayer tests for organically rich shales. In the situation where both the lean and the rich shales are to be fractured together, the use of either Hal I or Dow I is indicated.

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Cliffs Minerals, Inc. Eastern Gas Shales Project, Ohio No. 6 series:  Gallia County. Phase II report. Preliminary laboratory results

The US Department of Energy is funding a research and development program entitled the Eastern Gas Shales Project designed to increase commercial production of natural gas in the eastern United States from Middle and Upper Devonian Shales. On September 28, 1978 the Department of Energy entered into a cooperative agreement with Mitchell Energy Corporation to explore Devonian shale gas potential in Gallia County, Ohio. Objectives of the cost-sharing contract were the following: (1) to select locations for a series of five wells to be drilled around the periphery of a possible gas reservoir in Gallia County, Ohio; (2) to drill, core, log, case, fracture, clean up, and test each well, and to monitor production from the wells for a five-year period. This report summarizes the procedures and results of core characterization work performed at the Eastern Gas Shales Project Core Laboratory on core retrieved from the Gallia County EGSP wells, designated OH No. 6/1, OH No. 6/2, OH No. 6/3, OH No. 6/4, and OH No. 6/5. Characterization work performed includes photographic logs, fracture logs, measurements of core color variation, and stratigraphic interpretation of the cored intervals. In addition the following tests were performed by Michigan Technological University to obtain the following data: directional ultrasonic velocity; directional tensile strength, strength in point load; trends of microfractures; and hydraulic fracturing characteristics.

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Evaluation of fracturing methods for the stimulation of Devonian shale in northern Ohio. Final report

A comparison of core analyses from Lorain and Trumbull Counties with those from gas producing areas showed that the shale sections in both areas contain adequate matrix gas for commercial production. Although we observed large natural gas shows in Lorain County and measured high concentrations of matrix off-gas in the core from both project areas, no significant gas production resulted from 15 individual stimulations in the Devonian shale sections of 10 wells in Trumbull and Lorain Counties, Ohio. These results indicate that hydraulic fracturing treatments using a foam medium (as performed under this contract) were unsuccessful in achieving commercial production in either area. We obtained similarly unproductive results using a CO/sub 2/-water medium for fracturing in Lorain County. Two operational failures prevented our obtaining a valid test of the displaced explosive fracturing concept. These negative experiences could result from a combination of: (1) failure to effectively contact the target horizons with the stimulations, (2) formation damage due to the completion operations, and (3) a limited extent of natural permeability planes, but not from the level of matrix gas concentrations in the treated formations. Core samples from both counties gave little evidence of natural fracture development. Permeable zones within silty horizons may control the location of the local gas shows. Further shale research in northern Ohio should first focus on actual producing areas, and attempt to delineate the permeability trends. Future tests of stimulation methods should include borehole shooting. Although shooting may not induce extensive fractures, it should ensure at least some contact with nearly all of the treated section. In so doing, it may serve as a reasonable basis of comparison with other treatment techniques.

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Geological evolution and analysis of confirmed or suspected gas hydrate localities. Volume 4. Offshore of Newfoundland and Labrador

This document is Volume 4 of a series of reports entitled ''Geological Evolution and Analysis of Confirmed or Suspected Gas Hydrate Localities.''Volume 4 is an analysis of the ''Formation and Stability of Gas Hydrates Offshore of Newfoundland and Labrador.''This report presents a geological description of the offshore regions of Newfoundland and Labrador, including regional and local structural settings, geomorphology, geological history, stratigraphy, and physical properties. It provides the necessary regional and geological background for more in-depth research of the area. Detailed discussion of bottom simulating acoustic reflectors, sediment acoustic properties, and distribution of hydrates within the sediments. The formation and stabilization of gas hydrates in sediments are considered in terms of phase relations, nucleation, and crystallization constraints, gas solubility, pore fluid chemistry, inorganic diagenesis, and sediment organic content. Together with a depositional analysis of the area, this report is a better understanding of the thermal evolution of the locality. It should lead to an assessment of the potential for thermogenic hydrocarbon generation. 183 refs., 64 figs., 1 tab.

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Characteristics of possible methane gas hydrate reservoirs: the Cretaceous Nanushuk and Colville groups, National Petroleum Reserve in Alaska

Methane gas hydrates are known to exist in nature and represent a resource of large potential. Conditions necessary for methane hydrate formation occur in a wide variety of environments, including the permafrost regions of the National Petroleum Reserve in Alaska (NPRA). Water and methane gas are required to form methane gas hydrates, and their presence is dependent, in part, on the porosity and permeability of the potential reservoir rocks in the NPRA. Fifty-two very-fine- to medium-grained sandstone samples from 19 wells and core tests in the NPRA were examined. Gas producing and nonproducing strata from both the Cretaceous Nanushuk and Colville groups strata were sampled. Visual and statistical examinations indicated significant differences in petrologic constituents, grain size, porosity, and permeability between the Nanushuk and Colville samples. Differences also existed between gas producing and nonproducing units. High clay content, severe compaction, and the presence of swelling clays have reduced the porosity, permeability, and reservoir potential of the sampled strata. The inability to test extremely friable material from the Simpson Wells and Core Tests may have reduced the mean values of porosity and permeability of the samples. Further study should be focused on reservoir characteristics of the rocks in the methane gas hydrate stability zone in the Simpson area of the NPRA. Consideration should be given to swelling clays and the possibility that their presence in a well may mimic the characteristics of methane gas hydrate. 36 refs., 9 figs., 12 tabs.

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Experimental evaluation of the steady state and dynamic performance characteristics of the interactive units of a coal gasification process. Quarterly report, 27 December 1982-3 April 1983

A Test Plan Report has been prepared which details all the tests proposed for the 1983 operational season. One of these tests evaluates the thermal recycle mode which would be employed in a commercial configuration. In this mode, the condensate stream en route to the resaturator is passed back to the first gas cooler. The gas to liquid heat exchanger heats the condensate prior to resaturation. The analytical system simulation model, developed under this program, has been used to assess the operation of this mode and to select baseline conditions for the proposed test. Analysis of the data and results from tests conducted during the 1982 season has continued. In specific application, particularly power generation, the need exists to accommodate unanticipated contingency conditions. The response of the gasifier to such an occurrence was tested in 1982. Validation of the component models for the gasifier and the acid gas removal system has continued. Several enhancements to the gasifier model in the devolatilization zone are being added to increase accuracy. Improvements in the representation of the CO/sub 2/ absorption rate in the acid gas removal system model are being incorporated. A simplified combined cycle system model, integrated control system, and operator interface software modules are being installed on the PEF system data acquisition and control computers. This will permit system operation and model validation under a simulated end-use configuration. 15 figures, 3 tables.

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Pacific Project. Design assurance engineering single retort facility, Task 2. Final report

During development of the single retort plant design, engineering activities were undertaken to provide assurance that each major element would perform satisfactorily. Various tasks were assigned to Cliffs Engineering Incorporated, Davy McKee Corporation, H.K. Ferguson Company and Superior Oil Company. Elements indicating the design sensitivity have been summarized and presented by its plant functional area. Functional areas reviewed were: mining of raw shale; crushing and screening shale to required sizes; shale retorting; power generation; collecting and disposing of retorted shale; disposing of raw shale fines; and support facilities. In the reviews of expected design performance, the major equipment items and systems were identified from the mechanical and process standpoints. Where applicable, the analysis covers items, such as excess capacity, installed component or system redundancy, warehouse spare units and components, and the expected maintenance requirements. Items that are considered critical to the facility's successful operation are described. The critical items are monitored with instrumentation and/or operating labor to predict or sense failure of a critical item or system. Many of the monitoring devices also serve to automate process control. Where major cost or design alternatives existed in systems and items, trade-off studies were conducted. These studies include considerations such as energy conservation, profitability, state-of-the-art of development, future expansion and automation. This report includes a review of these trade-off studies. Design assurance procedures were followed in performing the design of the retort module to assure that satisfactory quality was maintained. Included in this task report are descriptions of the checking, reviewing and quality assurance procedures employed during the Phase I activities.

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Methane recovery from Coalbeds Project. Phase II report and annual report, 1979

Work under the TRW Methane Recovery from Coalbeds Project (MRCP) is defined by three discrete tasks: (1) to provide engineering and technical assistance to the methane from Coalbeds Project in planning, review and analysis of technical proposals, documentation and technical transfer and project evaluation; (2) to provide technical assistance and subcontracting support for resource delineation activities. The objectives of the resource delineation effort are threefold: to estimate more reliably the methane resources contained in the nation's coalbeds; to estimate the recoverable resource; and to determine exploration and production technologies that allow extrapolation from test sites to larger resource areas. Field work in this area is given in the report; (3) to provide design/development analyses, implementation, and evaluations of technology test projects: implementation of a test to demonstrate the recovery of methane from multiple horizontal wells in an active mine and the utilization of the gas for the production of LNG or other purposes; implementation of a test to demonstrate the feasibility of recovering methane from multiple production zones in a single well and utilizing the gas in a local distribution system pipeline; and implementation of a test to demonstrate the feasibility of recovering methane from multiple, vertically drilled wells with multiple production zones in unminable anthracite coal and utilizing the gas by pipeline injection.

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Evaluation of data gathered from unmineable coal seams. Final report

As part of the US Department of Energy's (DOE) programs directed at gas recovery from unconventional sources INTERCOMP Resource Development and Engineering, Inc. (INTERCOMP) is under contract to the Morgantown Energy Technology Center (METC) to provide for the reduction of uncertainties in critical parameters related to the methane recovery from unmineable coals in the United States. To accomplish this objective INTERCOMP has assisted in test site selection, planning, and monitoring when requested and evaluated the results of test in terms of methane production potential and economics for selected well sites, geologic settings, and geographical areas. This is a continuation of two earlier contracts in which an optimized test program was specified and in which the results of that program were partially implemented and evaluated. In this report INTERCOMP's effort in assisting the Bureau of Mines to understand the nature of a communication problem between the vertical dewatering hole and the three horizontal degasification legs in the Emerald Mines Horizontal Drilling project is described. Recommendations made by INTERCOMP on how to determine the amount of communication and the answers to several other questions asked are given in the section Assistance in Test Planning. The use of INTERCOMP's numerical simulation model was necessary in this effort. The section entitled Resource Assessment gives the evaluation of each specific well site tested for methane production that furnished to INTERCOMP by METC.

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Volume II:  main body of semi-annual report for the unconventional gas-recovery program

This semi-annual report is presented in two separately bound volumes. Volume I, which is this Executive Summary, provides an overview of the Unconventional Gas Recovery projects. Volume II, which is the basic Semi-Annual Report for the Unconventional Gas Recovery Program, describes the four project activities in detail. Both Volumes I and II are divided into the same five major sections: Introduction; Methane Recovery from Coalbeds Project; Eastern Gas Shales Project; Western Gas Sands Project; Geopressured Aquifers Project.

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Chemical effect of entrained particles in coal conversion streams. 4th quarterly technical progress report, May 1-July 31, 1982. [Laser induced fluorescence spectra]

A major objective of the US Department of Energy is to increase coal utilization through the development of combustion stream cleanup technologies. Many of the existing cleanup devices as well as advanced concepts rely on heterogeneous processes (i.e. gas-solid interactions) to achieve efficient stream removal. Examples of such devices include particle injection and granular bed filters for alkali removal, limestone injection for SO/sub x/ removal in fluid bed combustors, dry injection for SO/sub x/ removal in entrained combustion, and trace metal adsorption and removal on fly ash. Recent studies indicate that the successful use of turbines in combined cycle processes may depend on understanding the interaction between the gas phase alkali and particles in the combustion stream to substantially reduce turbine corrosion. This report documents progress in efforts to model the heterogeneous chemistry of coal combustion streams as well as laboratory studies to obtain critical input data for the model. Task 1. Exercise PACKAGE Code. During this reporting period, the PACKAGE Code solution model has been used to investigate the combined effects of sulfur dioxide and chlorine on alkali gettering using kaolinite. Task 2. Model Development. Work on this task has focused on implementing the combined segregation, evaporation, and adsorption code. In this report the evaporation terms in the code are characterized and the interaction between segregation and evaporation processes is described. Task 3. Measure Alkali Vaporization Rates. During this quarter, experiments were performed which demonstrate the feasibility of using LIF to measure alkali vaporization rates. As a result of these studies the LIF spectrum has been obtained for sodium vaporized from the surface of sodium silicate to our knowledge, these are the first such spectra to be obtained in this manner. 3 references, 11 figures.

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