AndreaBozzo/ceres-open-data-index huggingface dataset:
Enhanced oil recovery by CO/sub 2/ foam flooding. Final report, October 1, 1981-December 31, 1985

The objective is to identify commercially available additives which are effective in reducing the mobility of carbon dioxide, CO/sub 2/, thereby improving its efficiency in the recovery of tertiary oil, and which are low enough in cost to be economically attractive. During the course of the project significant progress has been made in developing a commercial method of reducing the mobility of carbon dioxide in enhanced oil recovery processes. Experiments on gas mobility control, conducted in linear sand-pack models, show only a general correlation with the static foam test. The static test, which utilizes a blender to generate foam from an aqueous surfactant solution, is useful mainly for studying the effects of pH, temperature, salinity and crude oil on the relative foamability of any given surfactant. Surfactants that produce reasonable quantities of foam in the blender test also impart some degree of mobility control to gas during two-phase flow. The best mobility control additives however, are only modest foam volume producers. In addition, the best additives spontaneously produce a viscous foam under flow conditions and rates typical of petroleum reservoirs. Three basic chemical structures listed below appear to show most promise for gas mobility control: (1) ethoxylated adducts of C/sub 8/ to C/sub 14/ linear alcohols; (2) sulfate esters of ethoxylated C/sub 9/ to C/sub 16/ linear alcohols; (3) low molecular weight co-polymers of ethylene oxide and propylene oxide. For an immiscible CO/sub 2/ flood, reducing CO/sub 2/ mobility by a factor of 10 increased overall recovery by 20 percent. More importantly, incremental oil production was more than doubled during the early phase when only CO/sub 2/ was injected. Attempts to simulate the mobility controlled miscible CO/sub 2/ process were not successful. More work is planned. 98 refs., 73 figs., 23 tabs.

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Assessment of thermodynamic data and needs, including their economic impact, for development of new fossil fuel refining processes

This report is an assessment of the thermodynamic data available and data needs for the processing of heavy petroleum, shale oil, tar sands, and coal liquids. It has been produced in partial fulfillment of the plan for thermodynamics research outlined in the NIPER FY86 Annual Research Plan. The assessment contains two background chapters on Energy Outlook and Future Refinery Needs as an overall introduction to the subject matter. Two chapters on economics follow: one on the previous economic impact of thermodynamics on the petroleum industry and the second on the possible economic impact of thermodynamics on the processing of alternate crudes. Chapters 5 through 9 detail the thermodynamic properties needed, their present status and future needs, including some details of compound types and problems to be solved for processing heavy petroleum, shale oil, tar sands, and coal liquids. After a chapter detailing the relationships between thermodynamics, kinetics, and catalysis, the final two chapters in the assessment are devoted to details of previous assessments of the need for thermodynamic measurements in this general field and a listing of the active laboratories making this type of measurements. This report does not cover thermodynamic data needs for (1) coal gasification, and (2) enhanced oil recovery (EOR). The former has been the topic of a recent similar report by the Gas Research Institute (GRI). The latter is the research topic of a separate group within NIPER that would be more competent to make a review of data available and future needs for EOR via thermodynamics research. 2 figs., 15 tabs.

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Pacific Project, Garfield County, Colorado. Phase 1. Project data book mine and related facilities - Task 8b, 8d. Volume 1. General conditions and engineering standards

The scope of work for the Phase I Pacific Project Mine and related Facilities encompasses a preliminary design package and cost estimates for an underground oil shale mine and related facilities which support a commercial-sized, 18,000 barrel-per-day surface retorting module. The Project design is presented in four major parts: the mine; mine services; raw shale fines and retorted shale disposal; and abandonment. Contents of Volume I include: (1) site description; (2) design basis data package; (3) other general descriptions (geology, rock mechanics, resource analysis, soils investigation and summary tabulation of overall project criteria and data,4807 ); (4) acceptable bidders list; (5) design considerations; and (6) appendices for rock mechanics report and mechanical properties testing of Pacific oil shale. 2 figs., 2 tabs.

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Pacific Project, Garfield County, Colorado, Phase 1. Project dadta book mine and redlated facilities - Task 8b, 8c. Volume 3. Cost estimates and schedules

The scope of work for the Phase I Pacific Project demonstration module encompasses a preliminary design package and cost estimates for an underground oil shale mine and related facilities which support a commercial-sized 18,000 barrel-per-day surface retorting module located on the Pacific Property in Garfield County, Colorado. The work includes preparation of cost estimates with an accuracy of plus or minus 20 percent for development, capital, operating, and abandonment costs derived from a preliminary design package. For estimating purposes, the project costs were broken down into the following five components. Mine, crushing and screening, mine services, raw shale fines and retorted shale disposal, and abandonment plan. Volume III contains: (1) scope of work on which the estimate and schedule are based; 92) schedules; (3) estimates; and (4) schedule of expenditures.

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Pacific Project, Garfield County, Colorado, Phase 1. Project data book auxiliaries and related facilities - Task 8c. Volume 2. Project definition

Phase I of the Pacific project covers design engineering of a single retort, 18,000 bbl per day shale oil plant. Volume II includes the following: (1) general which covers process description, drawing index, flow-diagrams, property, plant site and plot plan drawings, electrical single line diagrams, mechanical equipment layout drawings and tradeoff studies; (2) equipment data sheets and design specifications; (3) future design considerations; (4) engineering design calculations; and construction factors report.

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Development of an advanced, continuous mild gasification process for the production of co-products (Task 1), Volume 1

Under US DOE sponsorship, a project team consisting of the Institute of Gas Technology, Peabody Holding Company, and Bechtel Group, Inc. has been developing an advanced, mild gasification process to process all types of coal and to produce solid and condensable liquid co-products that can open new markets for coal. The three and a half year program (September 1987 to June 1991) consisted of investigations in four main areas. These areas are: (1) Literature Survey of Mild Gasification Processes, Co-Product Upgrading and Utilization, and Market Assessment; (2) Mild Gasification Technology Development: Process Research Unit Tests Using Slipstream Sampling; (3) Bench-Scale Char Upgrading Study; (4) Mild Gasification Technology Development: System Integration Studies. In this report, the literature and market assessment of mild gasification processes are discussed.

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Review of stiffness and implicit finite difference methods in combustion modeling

Stiffness is a mathematical characteristic which is exhibited in combustion models when some components of their solutions respond quickly to system perturbations whereas others respond slowly. This paper presents a physical interpretation of stiffness in chemical kinetics modeling. Implicit finite difference methods are known to be effective in finding solutions to stiff problems, and we present here a general overview of the mathematical concepts important to the implementation of implicit methods.

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Pressurized fluidized-bed combustion

The US DOE pressurized fluidized bed combustion (PFBC) research and development program is designed to develop the technology and data base required for the successful commercialization of the PFBC concept. A cooperative program with the US, West Germany, and the UK has resulted in the construction of the 25 MWe IEA-Grimethorpe combined-cycle pilot plant in England which will be tested in 1981. A 13 MWe coal-fired gas turbine (air cycle) at Curtis-Wright has been designed and construction scheduled. Start-up is planned to begin in early 1983. A 75 MWe pilot plant is planned for completion in 1986. Each of these PFBC combined-cycle programs is discussed. The current status of PFB technology may be summarized as follows: turbine erosion tolerance/hot gas cleanup issues have emerged as the barrier technology issues; promising turbine corrosion-resistant materials have been identified, but long-term exposure data is lacking; first-generation PFB combustor technology development is maturing at the PDU level; however, scale-up to larger size has not been demonstrated; and in-bed heat exchanger materials have been identified, but long-term exposure data is lacking. The DOE-PFB development plan is directed at the resolution of these key technical issues. (LCL)

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Performance evaluation of a ceramic cross-flow filter on a bench-scale coal gasifier, Volume 2

This final report describes work conducted on the development of the ceramic cross flow filter for high temperature gas cleaning. This work was conducted from October 1984 through December 1988. Volume 1 provides an overall discussion of the program results. Volume 2 consists of Appendices that are referenced in Volume 1. Electricity costs, flow diagrams of the gasifier, and a model which describes the cleaning of the filter is included.

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System heat rate calculations for combustion island concept power generation system. [17 cases]

Performance calculations have been completed for 17 cases that examine the sensitivity of the heat rates from combustion island concept power generation systems to various changes in the process configuration. A combustion island is loosely defined as a combined-cycle system that uses either dry or slurried coal for direct firing in a gas turbine. In this concept, slagging off-base combustors and sorbent injection are being considered as possible modifications to conventional oil-fired gas turbine systems. The purpose of this Technical Note is to define feasible system configurations. No systems economics have been included. All cases discussed in this Technical Note were based on an approximately 100 MW combined-cycle power plant, which consisted of one gas turbine that produced approximately 75 MW of power (General Electric Frame 7 size range), and a steam turbine bottoming cycle. The major results from this study are: (1) The heat rate is reduced by approximately 400 Btu/kWhr by changing from a coal water fuel (CWF) feed with a 60% coal concentration to a dry feed. (2) Thermodynamic calculations show system performance is relatively insensitive to coal ash content. (3) Each 1% change in pressure loss through the gas turbine combustion section (i.e., the section between the compressor exit and turbine inlet) changes the system heat rate by approximately 33 Btu/kWhr. Conventional gas turbines typically have approximately a 4% pressure loss through the combustion section. Sorbent injection will have a relatively small effect on system performance, provided the combustion section pressure drop remains the same. 4 refs., 9 figs., 8 tabs.

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Continuing development of regenerable sorbents for fluidized-bed combustion. Semiannual technical progress report No. 3, October 1, 1980-March 31, 1981

During the period October-March, efforts were directed primarily to preparation of revised test and cost plans, following guidelines established by the Morgantown Energy Technology Center (MERC) for a revised scope of work. The basic deviation from the original proposal was the deferral of large-scale sorbent testing in the fluidized-bed coal combustion system. The new proposal was reviewed with appropriate DOE personnel at MERC in December. Operations of the laboratory-scale hot fluidized bed system (LSHFB) were resumed with a newly-fabricated second reactor. The second test sequence in the LSHFB system was performed with a fluidized bed of 100 grams of calcium aluminate cement synthetic sorbent. As in the first test sequence, the sorbent bed was alternately sulfated and regenerated five times. Sulfation was accomplished at 900/sup 0/C with a synthetic flue gas mixture comprising 10.1% CO/sub 2/, 4.9% O/sub 2/, 2435 ppM SO/sub 2/ and 84.8% N/sub 2/. Regeneration was performed with a gas containing 7.1% CO and 92.9% N/sub 2/.

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Supplemental report to Congress on Emerging Clean Coal Technologies

On May 1, 1985, the Secretary of Energy submitted a Report to Congress on Emerging Clean Coal Technologies which in part assessed the usefulness of the emerging coal technologies under development by DOE. On May 8, 1985 in testimony before the House Committee on Science and Technology Subcommittee on Energy Development and Applications, the Department of Energy committed to a follow-on report aimed at further characterizing these emerging clean coal technologies. This report has been prepared in response to that commitment. The characterizations consist of an evaluation of the technologies against four measures including environmental performance, technical maturity, applicability, and cost effectiveness. The technology categories addressed in this report are those encompassed by the previous Report to Congress. In some technology categories, more than one individual technology is assessed. In turn, each technology may encompass several different processes. In addition, most of the technologies are, in fact, subsystems in various large energy systems. Generally, the clean coal technologies can be divided into three broad groups according to primary function: fuel production, energy production, and environmental emissions reduction. Fuel production technologies convert coal into a more useful form such as fuel gas, hydrocarbon liquids, or coal-water mixtures. Energy production technologies convert coal into electric power and/or steam for industrial process use. Environmental emission-reducing technologies mitigate the emissions of SO/sub x/, NO/sub x/, and particulate emissions caused by, for example, coal burning in a boiler. The descriptions and ratings of technologies in this report against various appropriate measures will allow the reader to gain a sense for the relative performance of each technology for each evaluation measure.

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Fabric filter blinding mechanisms

This discussion of various bag/cloth filter degradation mechanisms is mostly common sense. However, this information is occasionally lost in the subtleties of real-system operation. Although this paper is written with reference to fluidized-bed combustion (FBC) applications, the insights are generally applicable. For enumeration of particular filter fabric and baghouse experiences in FBC applications, the reader is referred to a report by Davy McKee Corporation (no date). A fabric filter is a composite matrix of fibers oriented to retain the dust particles from dust-laden gas. The cleaned gas passes through the fabric filter; the retained dust particles are deposited on the surface of (and within) the fiber matrix. The retained dust can be later removed through mechanical means. The fabric may be made of any fibrous material, spun in yarn, and then woven, impacted, needled, or bonded into a felt. Deep penetration of aggregated fine particles, lack of dust removal during filter cleaning, and chars or condensed aerosols may contribute to the increase in pressure drop across the filter. This increases the filter operation power consumption and, consequently, reduces the filtration capacity. The phenomenon of building a high-pressure drop in spite of filter cleaning provisions is known as blinding. In order to maintain an acceptable gas throughput, blinding problems must be addressed. Recommendations are given: maintain temperature above dew point, use filter aids, by-pass filter during start-up or operational upsets, etc.

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Conceptual design and cost estimate for zinc ferrite plant section

For a number of years the US Department of Energy's Morgantown Energy Technology Center (METC) has been involved in developing coal gasification processes to produce electricity from coal. Coal gasifiers produce raw synthesis gas at temperatures ranging from 700{degree} to 3,000{degree}F. Before these gases can be fed to a combustion gas turbine, hydrogen sulfide and particulates in the raw gas must be removed. To improve the efficiency of coal gasification processes, METC has been actively involved in the development of hot gas cleanup technologies for coal gasification processes. One of these technologies is the zinc ferrite process for hydrogen sulfide removal. The zinc ferrite process has been studied extensively at METC, and is now at the stage of demonstration testing. The objective of this study was to determine the cost of a zinc ferrite plant section within {plus minus}30 percent accuracy. The approach taken was to develop a detailed design for the zinc ferrite section for a given coal gasification plant and prepare a factored capital cost estimate for the section. Section 2.0 of this report describes the zinc ferrite process design and Section 3.0 presents the factored capital cost estimate for the section. The appendices include the section mass balance, an equipment list, major equipment specifications, and capital cost estimates. 1 ref.

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Recent developments in granular bed filters

Granular-bed filters in various modes (fixed, fluidized, and moving) have been used for particulate and vapor filtration from gas streams for a long time. In recent years, their exploitation in coal conversion processes for removal of fine dust and traces of metal vapors has been pursued with good success. Exxon, Westinghouse, Combustion Power Company, General Electric, EFB, and Air Pollution Technology are engaged in developing such filters for the purification of hot and compressed flue gas from pressurized fluidized-bed combustors for power generation. In each mode of granular-bed filter operation, the particulate collection efficiency improves by the application of an external electric field and even further enhancement is possible if the dust particles are charged. A granular bed consisting of an admixture of magnetic and nonmagnetic particles in a magnetic field is found to be a very attractive filter, and its complete promise and potential is under investigation. All these continuing recent efforts are reviewed and examined, and recommendations are made for future research in this particular area of coal combustion technology.

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Dispersivity as an oil reservoir rock characteristic

The main objective of this research project is to establish dispersivity, {alpha}{sub d}, as an oil reservoir rock characteristic and to use this reservoir rock property to enhance crude oil recovery. A second objective is to compare the dispersion coefficient and the dispersivity of various reservoir rocks with other rock characteristics such as: porosity, permeability, capillary pressure, and relative permeability. The dispersivity of a rock was identified by measuring the physical mixing of two miscible fluids, one displacing the other in a porous medium. 119 refs., 27 figs., 12 tabs.

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Gravity flow of solids engineering databook: measurement of surface moisture of coal. Final technical report

The purpose of this work was to search out different methods for determining surface moisture and to select the most promising for trial on three coal samples. At the same time these coals - a lignite, a western sub-bituminous and an eastern bituminous - were tested for flowability. All of the tests have been analyzed looking specifically for a good method of determining surface moisture and for any possible correlation between measured flow behavior and moisture measurements. None of the ''typical''surface moisture measurement techniques correlated with the measured cohesive behavior of the coals tested. In the case of the lignite and sub-bituminous coal tested the inherent moisture content (that is the total moisture content not affecting flow properties of coal) appears to be high. This means that the partial drying tests typically used to indicate surface moisture give high surface moisture values when none is present. Consequently there is little if any agreement in the values of surface moisture determined with the various techniques. In general, the only semi-reliable moisture measure of coal is the total moisture content. The only reliable way of determining the effect of moisture content on flow properties of a coal is to measure these properties at the total moisture content under consideration. If this is done for a range of total moisture contents it is possible to determine a maximum total moisture below which flow properties are unaffected by moisture. This total moisture then represents the zero surface moisture level of the coal. Surface moisture is any moisture above this level. 19 refs., 12 figs., 6 tabs.

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Gasifiers in industry program, University of Minnesota - Duluth Campus gasifier project. Final report, October 1976-August 1982

The University of Minnesota installed and operated a three ton/h low Btu coal gasifier for the generation of boiler fuels at the Duluth Campus with partial funds provided by a Cooperative Agreement with the United States Department of Energy, Gasifiers in Industry Program. The primary objective of the project, that started in 1976 and ended in 1982, was to evaluate the technical and economic aspects of the operation of a state-of-the-art low Btu coal gasifier in an actual operating environment. The gasifier was run intermittently for 10,500 h during 11 runs using western United States sub-bituminous coals. The thermal efficiency of the gasifier was found to average 90% during performance tests. The estimated cost of generating the gas and by-product tar fuels to meet University fuel requirements, excluding plant investment costs, was $7.09/million Btu with a Wyoming sub-bituminous coal. 16 references, 13 figures, 8 tables.

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Mechanism of the catalytic gasification of coal char:  a critical review. Final report, Task 6, September 1983. [137 references]

There has been great interest recently in the mechanism of catalyst action in the stream- or CO/sub 2/-gasification of carbonaceous substances, as evidenced by the publication of more than 100 papers and reports related to the subject since 1979. Our review of this literature reveals broad agreement among many investigators that the mechanism of catalytic gasification involves a redox cycle in which the catalyst is reduced by the carbon and oxidized by the gaseous reactant. There is still considerable debate over the elementary steps that comprise the process, although there has been significant evidence presented in support of types of intermediate species. This review covers literature that has appeared through April 1983. 137 references, 5 tables.

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High-temperature solid oxide electrolyte fuel cell power generation system. Technical progress report, November 1-December 31, 1982

Work continues on the modified program, toward: (1) advancing the solid oxide fuel cell components and the fabrication processes, particularly, the longer support tube and the interfacial bonding at the air electrode/electrolyte interface; (2) meeting the single and 3-cell performance and life qualification requirements; and (3) analyzing power plant and cogeneration applications that utilize the solid oxide fuel cell generator as part of a total system.

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