AndreaBozzo/ceres-open-data-index huggingface dataset:
Investigations into coal coprocessing and coal liquefaction

The conversion of coal to liquid suitable as feedstock to a petroleum refinery is dependent upon several process variables. These variables include temperature, pressure, coal rank, catalyst type, nature of the feed to the reactor, type of process, etc. Western Research Institute (WRI) has initiated a research program in the area of coal liquefaction to address the impact of some of these variables upon the yield and quality of the coal-derived liquid. The principal goal of this research is to improve the efficiency of the coal liquefaction process. Two different approaches are currently being investigated. These include the coprocessing of a heavy liquid, such as crude oil, and coal using a dispersed catalyst and the direct liquefaction of coal using a supported catalyst. Another important consideration in coal liquefaction is the utilization of hydrogen, including both externally- and internally-supplied hydrogen. Because the incorporation of externally-supplied hydrogen during conversion of this very aromatic fossil fuel to, for example, transportation fuels is very expensive, improved utilization of internally-supplied hydrogen can lead to reducing processing costs. The objectives of this investigation, which is Task 3.3.4, Coal Coprocessing, of the 1991--1992 Annual Research Plan, are: (1) to evaluate coal/oil pretreatment conditions that are expected to improve the liquid yield through more efficient dispersion of an oil-soluble, iron-based catalyst, (2) to characterize the coke deposits on novel, supported catalysts after coal liquefaction experiments and to correlate the carbon skeletal structure parameters of the coke deposit with catalyst performance as measured by coal liquefaction product yield, and (3) to determine the modes of hydrogen utilization during coal liquefaction and coprocessing. Experimental results are discussed in this report.

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Development of the CROW{trademark} process

The Contained Recovery of Oily Waste (CROW{trademark}) technology has been successfully tested in the laboratory and presently is being implemented at field sites contaminated with wood treating wastes and byproducts of town gas production. These field demonstrations will utilize only hot-water displacement without any chemical additives because the use of chemicals to enhance the hot-water flushing process has only been tested on a preliminary basis. Preliminary testing has shown that low concentrations of chemicals could reduce the contaminant content by an additional 10 to 20 wt %. Western Research Institute (WRI) research, plus research at Carnegie Mellon University, on surfactant enhancement of solubility of polynuclear aromatic hydrocarbons in water and water-soil systems indicate the potential of chemical enhancement of the CROW process. Chemicals that have been tested and that were used in these tests are totally biodegradable. The objective of this task was to obtain sufficient baseline data to show the effectiveness and environmentally safe use of chemicals, primarily surfactants, to enhance the CROW process. To meet this objective, 14 one-dimensional displacement tests were conducted. Eleven tests were conducted on a material from a former manufactured gas plant (MGP) site and four tests were conducted with a contaminated soil from a former wood treatment facility. The tests investigated the effect of three chemical concentrations (0, 0.5, and 1.0 vol %) at three temperatures (ambient, the projected optimum temperature, and one 40{degree}F [22{degree}C] below the optimum temperature).

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High-volume, high-value usage of fuel gas desulfurization (FGD) by-products in underground mines, Phase 1: Laboratory investigations. Quarterly report, January--March 1994

The objective of the project is to determine the technical, environmental, and economic feasibility of emplacing solid wastes from dry flue gas desulfurization (FGD) processes in underground mines to prevent acid mine drainage and mine surface subsidence. Activities during the quarter focused on three areas: materials acquisition (Subtask 2. 1,8340 ); the development and implementation of a hydrologic monitoring plan (Subtask 4.2) and the background survey for the transport and delivery system to the mines (Subtask 4.4). The materials for the study (20 tons total) were collected from the Archer Daniels Midland co-generation facility in Decatur, Illinois. A three phase hydrologic monitoring plan was successfully developed. A survey and drilling plan was accepted and survey points and well drill sites established. The site is currently being surveyed. The ways that backfill can be transported underground are many, but can be broken down into three main categories: (1) pumping, (2) gravity placement, and (3) other which includes novel and mobile equipment. The advantages and disadvantages of each are reviewed. The backfill placement method that is eventually chosen will depend on the geometry of the orebody and the personal preference of the company operating the mine.

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The development of an integrated multistage fluid bed retorting process. Quarterly report, January 1994--March 1994

This report summarizes the progress made on the development of an integrated multistage fluidized bed retorting process (KENTORT II) during the period of January 1, 1994 through March 31, 1994 under Cooperative Agreement No. DE-FC21-90MC27286 with the Morgantown Energy Technology Center, U.S. Department of Energy. The KENTORT II process includes integral fluidized bed zones for pyrolysis, gasification, and combustion of the oil shale. The purpose of this program is to design and test the KENTORT II process at the 50-lb/hr scale. Modifications to the system were completed that improved the start-up burner system and reduced thermal losses. Final shakedown tests were performed that demonstrated gasification zone and combustion zone temperatures of 800 and 900{degrees}C, respectively, at a raw shale feed rate of 50 lb/hr. Ash agglomeration and slagging was encountered during some of these tests, and these materials were analyzed by scanning electron microscopy and energy dispersive X-ray analysis. By limiting the combustion plenum chamber to 1100{degrees}C during heat up and by maintaining sufficient solid recycle to the combustor, it is believed that ash agglomeration difficulties will be eliminated.

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Advanced coal fueled industrial cogeneration gas turbine system. Final report, June 1986--April 1994

Demonstration of a direct coal-fueled gas turbine system that is environmentally, technically, and economically viable depends on the satisfactory resolution of several key issues. Solar Turbines, Incorporates technical approach to these issues was to advance a complete direct coal-fueled gas turbine system that incorporated near-term technology solutions to both historically demonstrated problem areas such as deposition, erosion, and hot end corrosion, and to the emergent environmental constraints based on NO{sub x}, SO{sub x}, and particulates. Solar`s program approach was keyed to the full commercialization of the coal-fueled cogeneration gas turbine which would occur after extended field verification demonstrations conducted by the private sector. The program was structured in three phases plus an optional fourth phase: Phase 1 -- system description; Phase 2 -- component development; Phase 3 -- prototype system verification; and Phase 4 -- field evaluation.

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Research program of the Morgantown Energy Research Center

Development of new and improved technology for coal conversion and utilization and enhanced recovery of oil and natural gas has been given priority by the Energy Research and Development Administration in its program of energy and fuels production from fossil sources. In support of this program, the Morgantown Energy Research Center (MERC) is engaged in a comprehensive effort involving in-house research supplemented by research projects under contract to private concerns and academic institutions. This brochure describes the objectives of these projects, accomplishments to date, and a general time-schedule for their completion.

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Advanced Turbine Systems Program: Conceptual design and product development. Quarterly report, February--April 1994

Objective (Phase II) is to develop an industrial gas turbine system to operate at a thermal efficiency of 50% (ATS50) with efficiency enhancements to be added as they become possible. During this quarter, Solar`s engine design team has refined both the 1- and 2-spool cycle concepts, to determine sensitivity to key component efficiencies, cooling air usage and origin, and location of compressor surge lines. The refined analysis included more detailed component work such as compressor and turbine design; different speed trade-offs for the low-and high-pressure compressor in the 1-spool configuration were examined for the best overall compressor efficiency. High-temperature and creep testing of recuperator candidate materials continued. Creep, yield, and proportional limit were measured for foil thicknesses 0.0030--0.0050 for Type 347 ss, Inconel 625, and Haynes 230. Combustor design work included preliminary layout of a multi-can annular combustor integrated into the main engine layout. During the subscale catalytic combustion rig testing, NOx emissions < 5 ppmv were measured. Integration of the engine concept designs into the full power plant system designs has started.

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Development of an advanced, continuous mild gasification process for the production of co-products. Quarterly report, April--June 1994

The primary objective of this project is to develop an advanced continuous mild gasification process and product upgrading processes which will be capable of eventual commercialization. The program consists of four tasks. Task 1 is a literature survey of mild gasification processes and product upgrading methods and also a market assessment of markets for mild gasification products. Based on the literature survey, a mild gasification process and char upgrading method will be identified for further development. Task 2 is a bench-scale investigation of mild gasification to generate design data for a larger scale reactor. Task 3 is a bench-scale study of char upgrading to value added products. Task 4 is being implemented by building and operating a 1000-pound per hour demonstration facility. Task 4 also includes a technical and economic evaluation based on the performance of the mild gasification demonstration facility. Installation of a continuous coke pilot plant started in the second quarter of 1994. Ten of 14 major components have been set. The remaining four are on order. Startup is scheduled for late September 1994. Eight test runs were completed in the continuous mild gasification unit (CMGU). These were short test runs to evaluate repair work or to demonstrate the PDU. Efforts continued to obtain financing for a commercial unit.

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Analytical steam injection model for layered systems

Screening, evaluation and optimization of the steam flooding process in homogeneous reservoirs can be performed by using simple analytical predictive models. In the absence of any analytical model for layered reservoirs, at present, only numerical simulators can be used. And these are expensive. In this study, an analytical model has been developed considering two isolated layers of differing permeabilities. The principle of equal flow potential is applied across the two layers. Gajdica`s (1990) single layer linear steam drive model is extended for the layered system. The formulation accounts for variation of heat loss area in the higher permeability layer, and the development of a hot liquid zone in the lower permeability layer. These calculations also account for effects of viscosity, density, fractional flow curves and pressure drops in the hot liquid zone. Steam injection rate variations in the layers are represented by time weighted average rates. For steam zone calculations, Yortsos and Gavalas`s (1981) upper bound method is used with a correction factor. The results of the model are compared with a numerical simulator. Comparable oil and water flow rates, and breakthrough times were achieved for 100 cp oil. Results with 10 cp and 1000 cp oils indicate the need to improve the formulation to properly handle differing oil viscosities.

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Advanced turbine systems program conceptual design and product development. Task 3 -- System selection; Topical report

Solar Turbines Incorporated has elected to pursue an intercooled and recuperated (ICR) gas turbine system to exceed the goals of the DOE Advanced Turbine Systems (ATS) program, which are to develop and commercialize an industrial gas turbine system that operates at thermal efficiencies at least 15% higher than 1991 products, and with emissions not exceeding eight ppmv NOx and 20 ppmv CO and UHC. Solar`s goal is to develop a commercially viable industrial system (3--20 MW) driven by a gas turbine engine with a thermal efficiency of 50% (ATS50), with the flexibility to meet the differing operational requirements of various markets. Dispersed power generation is currently considered to be the primary future target market for the ICR in the 5--15 MW size class. The ICR integrated system approach provides an ideal candidate for the assumed dispersed power market, with its small footprint, easy transportability, and environmental friendliness. In comparison with other systems that use water or toxic chemicals such as ammonia for NOx control, the ICR has no consumables other than fuel and air. The low pressure ratio of the gas turbine engine also is favorable in that less parasitic power is needed to pump the natural gas into the combustor than for simple-cycle machines. Solar has narrowed the ICR configuration to two basic approaches, a 1-spool, and a 2-spool version of the ATS50. The 1-spool engine will have a lower first-cost but lower part-power efficiencies. The 2-spool ATS may not only have better part-power efficiency, its efficiency will also be less sensitive to reduced turbine rotor inlet temperature levels. Thus hot-end parts life can be increased with only small sacrifices in efficiency. The flexibility of the 2-spool arrangement in meeting customer needs is its major advantage over the 1-spool. This Task 3 Topical Report is intended to present Solar`s preliminary system selection based upon the initial trade-off studies performed to date.

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Direct methane conversion to methanol. Quarterly project status report, January 1, 1994--March 31, 1994

We proposed to demonstrate the effectiveness of a catalytic membrane reactor (a ceramic membrane combined with a catalyst) to solely produce methanol by partial oxidation of methane. Methanol is used as a chemical feedstock, gasoline additive, and turbine fuel. Methane partial oxidation using a catalytic membrane reactor has been determined as one of the promising approaches for methanol synthesis from methane. In the original proposal the membrane was used to selectively remove methanol from the reaction zone before carbon oxides form, thus increasing the methanol yield. Methanol synthesis and separation in one step would also make methane more valuable for producing chemicals and fuels. The cooling tube inserted inside the membrane reactor has created a low temperature zone that rapidly quenches the product stream. Both ceramic and metal membranes were tested in this study and similar results were obtained. This membrane reactor system has proved effective for increasing methanol selectivity during CH{sub 4} oxidation. We are currently using this non-isothermal non-permselective membrane reactor, and evaluating modifications to further improve performance. Metal membrane was used to avoid the membrane breakage problem. A series of experiments were carried out in order to optimize the operation of the process. A methanol yield of 3.8% was obtained when 8% O{sub 2} was fed in a reactant mixture. The catalyst, MoO{sub 3}/SiO{sub 2}, was found not good for this methane partial oxidation process.

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Evaluation of western shale-oil residue as an additive to petroleum asphalt for use as a pavement crack and joint sealant material

The objective of this study was to perform a preliminary evaluation of using a distillation residue from Green River Formation (western) shale oil as an additive to a petroleum asphalt for use as a crack and joint filler material in portland cement concrete and asphaltic pavements. A commercially available rubberized asphalt crack and joint filler material was also tested for comparison. ASTM specification tests for sealant materials used in concrete and asphalt pavements were performed on the sealant materials. Portland cement concrete briquets prepared with an asphalt material sandwiched between two concrete wafers were tested in a stress-relaxation experiment to evaluate the relaxation and recovery properties of the sealant materials. The results show that the shale-oil modified petroleum asphalts and the neat petroleum asphalt do not pass the extension portion of the ASTM test; however, there is indication of improvement in the adhesive properties of the shale-oil modified asphalts. There is also evidence that the addition of shale-oil residue to the petroleum asphalt, especially at the 20% level, improves the relaxation and recovery properties compared with the petroleum asphalt.

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Reserve estimates in western basins. Quarterly report, January--March 1994

During the first quarter of 1994, work continued in assembling of data on the Uinta Basin. This included integration of the PI, NPS and WHCS data bases, assembly of critical well lists, construction of base maps, acquisition of log and core data, digitizing and commencement of log interpretation. During this period the authors anticipated the USGS Resource Assessment being completed for the Uinta Basin. Concern was expressed that delays in completion of this work would jeopardize the Uinta Basin schedule for report completion and also that methodology differences between that used for the Uinta Basin versus the Greater Green River Basin would cause problems in using common methodology from basin to basin. It was agreed that the Uinta Basin work would be wound down and work on the Piceance Basin commenced to allow the USGS time to complete their work and also to create sufficient time to review methodology differences and to derive a solution for commonalizing the methodology. Base maps for the Piceance Basin are under construction and the process of constructing key well lists is underway. The Uinta Basin work is being wound down with the completion of digitizing and log interpretation on the first set of Uinta Basin wells. The first draft of the USGS Uinta Basin work has been received and is in the process of review. As previously communicated, the Uinta Basin methodology does not involve a volumetric in-place estimate which is the required starting point for the methodology. As a result, a proposal has been forwarded to fund the generation of an in-place estimate by play for the Uinta Basin to allow the common approach to be utilized between all three tight gas basins.

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Development of an advanced, continuous mild gasification process for the production of co-products. Quarterly report, January 1994--March 1994

The primary objective of this project is to develop an advanced continuous mild gasification process and product upgrading processes which will be capable of eventual commercialization. This program consists of four tasks. Task 1 is a literature survey of mild gasification processes and product upgrading methods and also a market assessment for mild gasification products. Based on the literature survey, a mild gasification process and char upgrading method will be identified for further development. Task 2 is a bench-scale investigation of mild gasification to generate data for a larger scale reactor. Task 3 is a bench-scale study of char upgrading to value added products. Task 4 is being implemented by building and operating a 1000-pound per hour demonstration facility. Task 4 also includes a technical and economic evaluation based on the performance of the mild gasification demonstration facility.

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Feasibility study of heavy oil recovery in the Appalachian, Black Warrior, Illinois, and Michigan basins

This report is one of a series of publications assessing the feasibility of increasing domestic heavy oil production. Each report covers select areas of the United States. The Appalachian, Black Warrior, Illinois, and Michigan basins cover most of the depositional basins in the Midwest and Eastern United States. These basins produce sweet, paraffinic light oil and are considered minor heavy oil (10{degrees} to 20{degrees} API gravity or 100 to 100,000 cP viscosity) producers. Heavy oil occurs in both carbonate and sandstone reservoirs of Paleozoic Age along the perimeters of the basins in the same sediments where light oil occurs. The oil is heavy because escape of light ends, water washing of the oil, and biodegradation of the oil have occurred over million of years. The Appalachian, Black Warrior, Illinois, and Michigan basins` heavy oil fields have produced some 450,000 bbl of heavy oil of an estimated 14,000,000 bbl originally in place. The basins have been long-term, major light-oil-producing areas and are served by an extensive pipeline network connected to refineries designed to process light sweet and with few exceptions limited volumes of sour or heavy crude oils. Since the light oil is principally paraffinic, it commands a higher price than the asphaltic heavy crude oils of California. The heavy oil that is refined in the Midwest and Eastern US is imported and refined at select refineries. Imports of crude of all grades accounts for 37 to >95% of the oil refined in these areas. Because of the nature of the resource, the Appalachian, Black Warrior, Illinois and Michigan basins are not expected to become major heavy oil producing areas. The crude oil collection system will continue to degrade as light oil production declines. The demand for crude oil will increase pipeline and tanker transport of imported crude to select large refineries to meet the areas` liquid fuels needs.

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Kinetic modeling of petroleum formation in the Maracaibo Basin: Final report, Annex 12

The purpose of this project is to develop and test improved kinetic models of petroleum generation and cracking, pore pressure buildup, and fluid expulsion. The work was performed jointly between Lawrence Livermore National Laboratory and Research Organization of the Venezuelan National Petroleum Company under Annex 12 of an agreement between DOE and the Venezuelan Ministry of Energy and Mines. Laboratory experiments were conducted at both LLNL and INTEVEP to obtain the reaction rate and product composition information needed to develop chemical kinetic models. Experiments at INTEVEP included hydrous pyrolysis and characterization of oils by gas and liquid chromatography. Experiments at LLNL included programmed pyrolysis in open and self-purging reactors, sometimes including on-line gas analysis by tandem mass spectrometry, and characterization of oils by gas chromatography and nuclear magnetic resonance. The PMOD code was used to develop a detailed pyrolysis mechanism from the extensive laboratory data. This mechanism is able to predict yield of bitumen, oil, and gas as a function of time and temperature for such diverse laboratory conditions as hydrous pyrolysis and rapid, programmed, open pyrolysis. PMOD calculations were compared to geologic observations for 22 wells in the Maracaibo basin. When permeability parameters are chosen to match calculated pore pressures with measured present day values, the PMOD calculations indicate that organic maturation reactions contribute a significant fraction of the overpressure during oil generation and early oil cracking. Calculations agreed with observed geochemical maturity parameters of the source rock. 37 refs., 64 figs., 20 tabs.

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