AndreaBozzo/ceres-open-data-index huggingface dataset:
Application of characteristic time concepts for hydraulic fracture configuration design, control, and optimization

The analysis of pertinent energy components or affiliated characteristic times for hydraulic stimulation processes serves as an effective tool for fracture configuration designs optimization, and control. This evaluation, in conjunction with parametric sensitivity studies, provides a rational base for quantifying dominant process mechanisms and the roles of specified reservoir properties relative to controllable hydraulic fracture variables for a wide spectrum of treatment scenarios. Results are detailed for the following multi-task effort: (a) Application of characteristic time concept and parametric sensitivity studies for specialized fracture geometries (rectangular, penny-shaped, elliptical) and three-layered elliptic crack models (in situ stress, elastic moduli, and fracture toughness contrasts). (b) Incorporation of leak-off effects for models investigated in (a). (c) Simulation of generalized hydraulic fracture models and investigation of the role of controllable vaxiables and uncontrollable system properties. (d) Development of guidelines for hydraulic fracture design and optimization.

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Development of potential uses for the residue from fluidized bed combustion processes. Quarterly technical progress report, December 1980-February 1981

Research on potential uses of solid wastes from fluidized-bed combustion processes included the following activities during this quarterly report period: chemical analysis was performed on a pulverized coal fly ash that was proposed for use in the briquetting program; briquettes were evaluated by abrasion testing, incorporation into concrete mixes as the coarse aggregate, and by an examination of their crushing characteristics; the effects of carbonation of briquettes by exposure to CO/sub 2/ were studied; final data on the dimensional stability of test pads are presented; the wall constructed with AFB masonry block was monitored and additional compressive strengths of the block determined; waste sludge stabilization using AFB residue was tested and the results are reported; evaluation of crushed, stockpiled residue has continued; the qualitative review of the effects of molding moisture content on road base mixes has been completed; and preliminary results on the effects of combined storage of AFB residue and pulverized coal fly ash were obtained and are presented. (LCL)

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Characterization of streams around a slip-stream gas chiller at the KRW coal gasifier process development unit. Technology status report

The following summarizes the results and conclusions of the gas chiller operation and stream characterization performed at the KRW PDU: The gas chiller apparatus was designed, constructed, and successfully operated. The first two runs served primarily as commissioning runs. Chiller operating procedures were established and additional stream characterization needs were identified as a result of these runs. An indication of the types of compounds that would be present in the condensate and flash gases produced as a result of chilling cooled gasifer product gas was obtained. Dissolved gases led to significant concentrations of ammonia (estimated at 1280 mg N/L for the subbituminous coal run, 3330 mg N/L for the lignite run) and cyanide (200 Mg/L for the lignite run). There is evidence that dissolved hydrogen sulfide was also present in the condensate, based on the concentrations of this species found in the flash gases evolved as the condensate was depressurized. Residual quantities of organics were also present. Treatment of this stream would be required to reduce the concentrations of these components. Flash gases produced as the chiller condensate is depressurized contain reduced sulfur species, 1.35 to 2.5 vol. % and carbonyl sulfide, 189 to 932 ppmv) and volatile organics (e.g., 618 to 1610 ppmv of C/sub 6/ ), as well as carbon dioxide and other major gas species present in the chiller inlet gas. Possible options for treatment of this stream would include combining it with other streams routed to sulfur recovery or incineration. Health and safety concerns arise due to the high concentration of H/sub 2/S in the flash gases and cyanide in the condensate. 12 refs., 2 figs., 13 tabs.

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Fundamentals of nitric oxide formation in fossil fuel combustion. Progress report, 29 June-28 September 1980

The study of the oxidation kinetics of pyridine was completed in the temperature range of 948 to 1073/sup 0/K and concentration ranges of 1.75 to 7.0 mole % oxygen; 0.25 to 2.0 mole % pyridine. The rate law is rate = k(C/sub 5/H/sub 5/N)/sup 1/2/(0/sub 2/)(..delta..0/sub 2/)/sup 1/2/, where ..delta..0/sub 2/ is oxygen consumed (autocatalysis). The temperature dependence is k = 10/sup 14.7  - .7/exp(-26600  - 1600/T)(1/mole s). The yield of HCN appeared insensitive to changes in temperature, concentrations and equivalence ratio, and only trace amounts of nitrogen oxides and ammonia were found. Fuel-rich mixtures produced large amounts of smoke so that a nitrogen balance was not possible but for lean mixtures HCN and N/sub 2/ accounted for the product nitrogen. Increase to 2% pyridine and 14% oxygen produced reduced yields of HCN and increased yields of N/sub 2/, N/sub 2/O, and NO. H/sub 2/ had no influence on the rates of pyrolysis and oxidation of pyridine. At 1073/sup 0/K HCN was oxidized at a measurable rate, added benzene increased the rate of oxidation at low equivalence ratios and reduced it at ratios above 0.9, with no significant nitrogen oxides produced, added acetylene increased the oxidation rate and also produced NO. It is clear that conditions can be found for the oxidation of heterocyclic nitrogen compounds that promote the formation of N/sub 2/ at the expense of NO.

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Performance of an electrostatic precipitator on a bench-scale gasifier: Final report

The objective was to evaluate the technical and economical feasibility of electrostatic precipitators (ESPs) as hot gas cleanup devices on combined cycle gasifier power plants. The program consisted of three tasks. The first was the bench-scale testing of an ESP on an actual gasifier at the Morgantown Energy Technology Center. The second was to investigate, in the laboratory, design principles related directly to the use of ESPs on gasifiers. The design principle tests were primarily to investigate clean electrode voltage-current characteristics and rapping efficiencies at high-temperature and high-pressure. The third task was to conceptualize a full-scale design and conduct an economic study of the use of ESPs for this application. The purpose of the bench scale tests was to obtain technical information on the operation of a high-temperature high-pressure electrostatic precipitator for application as a final particulate cleanup device on a coal gasification combined cycle power generating system. The specific objectives of the bench scale tests were to successfully operate the test module under actual gasifier conditions, to determine the level of particulate collection obtainable for these operating conditions, and to evaluate the technical feasibility of using electrostatic precipitators for this application. The bench scale tests were performed at the gasifier facility at the Morgantown Energy Technology Center. The purpose of the design principles tests was to obtain additional information on the operation of a precipitator at conditions typical of a coal gasifier that could be used in the conceptual design of a commercial scale precipitator. The design principles tests are distinguished from the bench scale tests in that they consisted of a series of experiments run under simulated gasifier conditions, whereas the bench scale tests were run on an actual gasifier fuel gas stream. 12 refs., 27 figs., 12 tabs.

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Design studies for gasification/hot gas desulfurization system operation in a load following mode

The prime objective of this project has been to perform design studies and develop conceptual and detailed designs for a hot gas desulfurization system for Simplified (IGCC) integrated gasification combined cycle electric power generation. The desulfurization system is designed so that the Simplified IGCC system can be operable in a load following mode to allow the power generation equipment to participate in grid load management. The project was conducted in two phases. Phase I has resulted in the conceptual design of a commercial-scale desulfurization system for a 50 MW utility electric power generation system. Based on this conceptual design, estimates were made of the cost of electricity such a plant would produce. Phase II developed a conceptual adaptation of that design concept to   proof-of-concept''scale for incorporation in an existing Process Evaluation Facility for experimental verification of the design. The desulfurization system design is based on the use of solid pellets of zinc ferrite (ZnFe{sub 2}O{sub 4}) as the sorbent. The hot coal gas desulfurization system design developed in this program consists of high-efficiency cyclones to collect entrained particles, a moving bed absorber containing zinc ferrite sorbent to remove sulfur compounds, a moving bed regenerator to regenerate the sulfided sorbent, a regeneration gas recycle system and a solids transport system. 26 refs., 49 figs., 17 tabs.

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Rivesville multicell fluidized-bed boiler. Annual technical progress report, July 1979-June 1980

Design, construction and test program of a 300,000 lb/hr steam generating capacity multicell fluidized bed bouler (MFB), as a pollution free method of burning high-sulfur or highly corrosive coals, is being carried out. The concept involves burning fuels such as coal, in a fluidized bed of limestone particles that react with the sulfur compounds formed during combustion to reduce air pollution. Nitrogen oxide emissions are also reduced at the lower combustion temperatures. The CaSO/sub 4/ produced in the furnace is discharged with the ash or regenerated to CaO for reuse in the fluidized bed. This report presents information on continued operation of the Rivesville MFB steam generating plant in a commercial mode and for determining performance and emission characteristics; studies and tests on flyash characterization and reinjection, fuel feed educators and needles, air distributor, corrosion-erosion and sulfur capture; engineering studies to improve MFB performance and reliability.

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Pressurized fluidized-bed combined-cycle-concept evaluation. Volume II

The primary Pressurized Fluidized Bed Combustion (PFBC) concepts being developed within the DOE PFBC program with conventional coal-fired technology are compared. A more conservative PFBC cycle is also evaluated. A normalized performance analysis showed that both PFBC cycles are significantly more efficient than conventional power plants; the steam cooled PFBC has a greater performance advantage than the air cooled PFBC cycle; and a more conservative PFBC cycle employing turboexpanders was an attractive option that could serve as a first generation PFBC power plant. The air and steam cooled PFBC costs and the conventional coal fired plant costs were compared. It was concluded that the steam cooled PFBC appears most attractive on the basis of capital cost. A subsequent COE analysis demonstrated that the performance and capital cost benefits of the steam cooled PFBC result in a significant economic benefit when compared to conventional technology, and certainly demonstrates that PFBC is a promising new technology. The turboexpander PFBC power plant is competitive on a cost of electricity basis with conventional coal fired power plants. It was also concluded that the air cooled PFBC will only see commercial application if breakthroughs in materials technology occur or a hybrid air/steam cycle is developed, but it is recommended to continue with the air cooled PFBC pilot plant as an excellent turbine test facility. This volume contains information on cost analysis; economic analysis; sensitivity analyses; PFBC market perspective; and 18 appendices. (LCL)

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Tri-State Synfuels Project Review:  Volume 1A. Executive summary and overall project review. [Proposed Henderson, Kentucky coal to gasoline plant; executive summary and overall project review]

The Tri-State coal to gasoline project finally resulted from an initial Lurgigasification and Fischer-Tropsch syntheses to produce liquid fuels. As a result of changes, resulting partly from the analysis results, partly from changes in world energy price forecasts, and partly from the national administration change, the goals were changed during the work. Finally, a process resulted which seemed to have little technical risk, but which would result in higher gasoline costs than could be obtained from western coal; but there was difficulty in obtaining partners and uncertainty in getting financing or financial incentives from the US government. The history of the work is reviewed. The process advantages, contracts, licenses and agreements, environmental effects, coal supplies (Kentucky) and coal testing. Tri-State believed that continued investment of substantial monies in the project could not be justified in light of: the present uncertainties of obtaining adequate financing of the plant investment; of our inability to acquire additional partners, given currently projected energy prices and continuing uncertainties surrounding the nature and ultimate amount of financing; and of government support for the planned facility. Tri-state further proposed to initiate project demobilization immediately to be completed by mid-June 1982. We expressed to SFC that in our opinion the nucleus of a synfuels industry is still a critical strategic US need and that Tri-State should be a part of that nucleus. We also encouraged SFC to investigate the project through third parties we had dealt with, such as other government agencies and potential partners who had reviewed the project.

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Morgantown Energy Technology Center technology status report: Systems studies and combustion research for coal-fueled heat engines

Significant accomplishments during FY 84 include completion of a series of bench-scale combustion tests on CWF's (coal-water fuel) of varying ash levels and compositions, development of an alkali and particulate sampling technique for field application on hot-cleaned coal-derived gas and gas combustion experiments, preliminary laboratory measurements of deposition-related sticking coefficients for coal ash, development of a unique technique for the study of coal-water droplet disruption and evaporation phenomena, and systems analysis and sensitivity studies on several direct coal-fired gas turbine concepts.

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Supporting technology for enhanced oil recovery: Chemical flood predictive model

The Chemical Flood Predictive Model (CFPM) was developed by Scientific Software-Intercomp for the US Department of Energy and was used in the National Petroleum Council's (NPC) 1984 survey of US enhanced oil recovery potential (NPC, 1984). The CFPM models micellar (surfactant)-polymer (MP) floods in reservoirs which have been previously waterflooded to residual oil saturation. Thus, only true tertiary floods are considered. An option is available in the model which allows a rough estimate of oil recovery by caustic (alkaline) or caustic-polymer processes. This ''caustic''option, added for the NPC survey, is not modeled as a separate process. Rather, the caustic and caustic-polymer oil recoveries are computed simply as 15% and 40%, respectively, of the MP oil recovery. In the CFPM, an oil rate versus time function for a single pattern is computed and the results are passed to the economic routines. To estimate multi-pattern project behavior, a pattern development schedule must be specified. After-tax cash flow is computed by combining revenues with capital costs for drilling, conversion and upgrading of wells, chemical handling costs, fixed and variable operating costs, injectant costs, depreciation, royalties, severance, state, federal, and windfall profit taxes, cost and price inflation rates, and the discount rate. A lumped parameter uncertainty routine is used to estimate risk, and allows for variation in computed project performance within an 80% confidence interval. The CFPM uses theory and the results of numerical simulation to predict MP oil recovery in five-spot patterns. Oil-bank and surfactant breakthrough and project life are determined from fractional flow theory. A Koval-type factor, based on the Dykstra-Parsons (1950) coefficient, is used to account for the effects of reservoir heterogeneity on surfactant and oil bank velocities. 18 refs., 17 figs., 27 tabs.

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Supporting technology for enhanced oil recovery: CO/sub 2/ miscible flood predictive model

The CO/sub 2/ Miscible Flood Predictive Model (CO2PM) was developed by Scientific Software-Intercomp for the US Department of Energy and was used in the National Petroleum Council's (NPC) 1984 survey of US enhanced oil recovery potential (NPC, 1984). The CO2PM is applicable to both secondary (mobile oil) and tertiary (residual oil) floods, and to either continuous CO/sub 2/ injection or water-alternating-gas (WAG) processes. In the CO2PM, an oil rate versus time function for a single pattern is computed, the results of which are passed to the economic calculations. To estimate multi-pattern project behavior a pattern development schedule is required. After-tax cash flow is computed by combining revenues with costs for drilling, conversion and well workovers, CO/sub 2/ compression and recycle, fixed and variable operating costs, water treating and disposal costs, depreciation, royalties, severance, state, federal and windfall profit taxes, cost and price inflation rates, and the discount rate. A lumped parameter uncertainty model is used to estimate risk, allowing for variation in computed project performance within an 80% confidence interval. The CO2PM is a three-dimensional (layered, five-spot), two-phase (aqueous and oleic), three component (oil, water, and CO/sub 2/) model. It computes oil and CO/sub 2/ breakthrough and recovery from fractional theory modified for the effects of viscous fingering, areal sweep, vertical heterogeneity and gravity segregation. 23 refs., 19 figs., 57 tabs.

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Systematic procedure for reservoir characterization: Annual report, October 1, 1986--September 30, 1987

The general objective of this work is to develop procedures to enhance the accuracy and reliability of numerical simulation of oil recovery processes. The approach is to encapsulate geological observations into a numerical/statistical format, convert these into a random field of properties and then to simulate fluid flow through the field. The procedure should retain the geologic insight of more traditional methods while incorporating more spatial variability and, we believe, more realism into simulation. In this report we deal with several topics which lead up to the general goal. We give results on hydrodynamic simulations of viscous fingering and on the theoretical calibration of a field minipermeameter, discuss applications of this device to two outcrops in the Page sandstone and a San Andres dolomite, give results on theoretical analysis of the bias and precision of autocorrelation measures and, finally, introduce fluid flow simulations in the Page sandstone outcrop as a means of validating reservoir characterization procedures. 33 refs., 82 figs., 3 tabs.

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Development and operation of METC 42-inch gas producer during 1964-1977

This report reviews the developments associated with the pressurized, moving-bed gasifier operated at the Morgantown Energy Technology Center during the time period 1964--1977. A short description of coal gasification in general and its specific implications in a moving-bed gasifier are provided. A brief discussion of the history of moving-bed gasifiers, or gas producers as they are more commonly called, is included to set the background and justification for the birth of the METC program. During this program, the METC producer has gasified coals varying in rank from anthracite to lignite at pressures from near atmospheric to 300 psig and at feed rates up to approximately 2,500 lbs per hr. The main accomplishment of the program has been demonstration of the ability to gasify highly caking bituminous coals at pressure and without recourse to expensive pre-sizing or pretreatment. This has primarily been due to the use of a deep-bed stirrer which can break up coal agglomerates and prevent bed plugging or severe gas channeling from occurring. The report describes the problems, both operational and mechanical, that have been encountered during the development and the ways that have been used to solve or circumvent them.

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Void-gas stripping in standpipes

A model of a packed-bed void-gas stripping section in a standpipe has been developed. This relative-velocity model allows the determination of the best stripper design for a particular application. This model was developed from the results of a void-gas stripping study using a nitrogen/oxygen gas system. The effects of stripping gas injection, particle size, particle density, stripper diameter, and solids flow rate on the amount of gas needed to strip were investigated. An example of how to design a packed-bed stripper is also presented.

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Weeks Island S sand reservoir B gravity stable miscible CO/sub 2/ displacement, Iberia Parish, Louisiana. First annual report

The ''S''sand Reservoir B CO/sub 2/ pilot was designed to demonstrate the feasibility of a downward CO/sub 2/ displacement in a steeply dipping, high temperature and high pressure Gulf Coast reservoir. Research results show that CO/sub 2/ injection is not a miscible process at the S Sand Reservoir B (SRB) conditions but a CO/sub 2/-crude oil vaporization process. Vaporization means that the CO/sub 2/ strips and replaces hydrocarbon components from the crude. The stripping is enhanced with repeated contacts with fresh CO/sub 2/. Results of experiments indicate that CO/sub 2/ diluted with five to ten percent of plant gas (primarily methane) would result in a miscible-like displacement process. It also appears that based on slim tube experiments alone, undiluted CO/sub 2/ might be the most efficient material for the SRB field test. Under SRB reservoir conditions, CO/sub 2/ not diluted with light hydrocarbons is more dense than the reservoir oil. Fortunately, process mechanisms can work to the benefit of displacement stability. Upon mixing SRB oil and CO/sub 2/, two phases are formed. The CO/sub 2/ rich vapor phase is less dense than the liquid phase. Based on a zero dimensional analysis and the phase behavior study results, the vertical displacement by CO/sub 2/PG or CO/sub 2/ alone should be gravity stable at the expected flood conditions. A mixture of five percent by volume of plant gas and 95 percent CO/sub 2/ is the recommended injection system for this field test. This dilution should allow gravity forces to augment the vaporization process.

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Development of molten carbonate fuel cell power plant technology. Quarterly technical progress report No. 5, October 1, 1980-December 31, 1980

The overall objective of this program is to develop and verify the design of a prototype molten carbonate fuel cell stack which meets the requirements of a 1990's-competitive coal-fired electrical utility central station or industrial cogenerating power plants. During this quarter, activity continued in all four task areas: Task 1 - system studies to define the reference power plant design; Task 2 - cell and stack design, development and verification; Task 3 - preparation for fabrication and testing of the full-scale prototype stack; and Task 4 - development of the capability to operate stacks on coal-derived gas.

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