AndreaBozzo/ceres-open-data-index huggingface dataset:
Expression of a cross-strike structural discontinuity in Pennsylvanian rocks of the eastern Plateau province. [West Virginia]

Major, cross-strike structural discontinuities appear to be large volumes of intensely fractured rock, and may be useful guides in exploration for fractured gas reservoirs. To determine whether the Petersburg lineament of the western Valley and Ridge province of West Virginia is expressed in the Pennsylvanian rocks of the easternmost Plateau province, LaCaze mapped about 60 square km (23 square m) of late Paleozoic molasses atop Allegheny Front, in an area straddling the lineament's westward projection. Eight outcrops of Homewood sandstone strung across the projection contain longitudinal, transverse and an east-striking set of diagonal joints. Joint intensity (surface area per unit volume of rock) in the projection is about twice that outside. Structure contours show that a map-scale syncline is disrupted immediately west of the high-intensity zone. Thus the lineament is expressed in the Pennsylvanian rocks of the easternmost Plateau province as a zone of increased fracturing at least 1.3 km (0.18 m) wide, with associated broader disruption of map-scale structure.

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Distribution of Gas, Organic Carbon, and Vitrinite Reflectance in the Eastern Devonian Gas Shales and their Relationship to the Geologic Framework

Gas volume data from outgassing tests were available from twenty one sites in the Appalachian Basin and seven sites in the Illinois Basin. Most of these sites also had data available on organic carbon and vitrinite reflectance. Gas volume distribution varies with each stratigraphic unit tested in the Appalachian Basin. Thermal maturity increased from northwest to southeast in the Appalachian Basin. Gas volume, organic carbon, and thermal maturity increased from northwest to southeast in the Illinois Basin. High gas volumes were present in the Appalachian Basin in the Cleveland, Upper Huron, and Lower Huron Members of the Ohio Shale, the Rhinestreet Member of the West Falls formation, and the Middlesex Member of the Sonyea formation. In the Illinois Basin, The Grassy Creek and Sweetland Creek Shales of the New Albany showed relatively high gas volumes at some locations. Prior production areas of the Appalachian Basin are characterized by a thick sequence of radioactive shale, high measured gas volume, optimum stress ratio, and optimum thermal maturity. These same characteristics are present in an extensive area of Ohio, Pennsylvania, and New York and present areas of optimum exploration potential. The Devonian shale gas resource of the Illinois Basin is most probably the area of southeastern Illinois and adjacent areas of Indiana and Kentucky.

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A preliminary analysis of US CO/sub 2/ emissions reduction potential from energy conservation and the substitution of natural gas for coal in the period to 2010

Carbon dioxide (CO/sub 2/) is a product of burning fossil fuels (oil, gas and coal) and fossil fuel burning is the dominant source of global CO/sub 2/ emissions amounting to 5.2 petagrams of carbon per year (PgC) in 1985. The control of CO/sub 2/ emissions would require control of energy production and use. US emissions were 1.25 PgC in 1985. National Energy Policy Plan (NEPP) projections show total US emissions rising 38% by 2010 to 1.7 PgC. The US Department of Energy (DOE) Carbon Dioxide Research Division (CDRD) has sponsored research at the Pacific Northwest Laboratory (PNL), Brookhaven National Laboratory (BNL), and at the Oak Ridge National Laboratory to do a preliminary assessment of the technical feasibility and consequences of reducing US CO/sub 2/ emissions from 1985 levels by 10, 25 or 50 percent by either the year 1995 and 2010. In addition, DOE/CDRD sponsored a day-long roundtable attended by nine experts in the field to discuss this issue. Two methods of CO/sub 2/ emissions reduction were considered: energy intensity reductions (conservation), and substitution of natural gas for coal. The study did not address the contribution of other energy supply options or the feasibility of pre- or post-combustion CO/sub 2/ removal. Furthermore, the study made no attempt to explore specific policies that might be employed to achieve technically feasible CO/sub 2/ emissions reductions. This is not a policy document.

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Peat deposits of North Carolina: Bulletin 88

Fuel-grade peat is an accumulation of partially decomposed plant material that has less than 25% non-combustible material (ash). In eastern North Carolina peat has formed in the past 10,000 years in swamps or pocosins (coastal swamps), Carolina bays, and river floodplains. Most of the peat is found at the surface with no over-burden and usually ranges in thickness from 1 to 15 ft with an average of 4-1/2 ft. The mean ash content of the fuel-grade peats is about 7.4%, but ash contents of less than 5% are common in most peat deposits. Heating values average 10,100 Btu/lb on a moisture-free basis. Fuel-grade peat deposits cover about 677,000 acres (1060 sq mi) in coastal North Carolina with total resources of about 500 million tons of moisture-free peat. Of this total, about 284,000 acres (444 sq mi) with 319 million tons are underlain by peat greater than 4 ft thick. Peat resources are concentrated in the pocosins or coastal swamps of northeastern North Carolina with the Albemarle-Pamlico peninsula having 55% of the resources and the Dismal Swamp, 11%. The remaining coastal swamp deposits are small but significant. Although 96 Carolina bays have peat, only 46 have peat greater than 4 ft thick; and only one has more than 1 million tons of peat. None of the river floodplain peats located were very large, continuous, or of high quality. 75 refs.

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Stimulation research on Appalachian tight formations. Appendices A, B, C

The objective of this program was to compare the effectiveness of massive stimulation techniques with other novel candidate hydraulic treatments on gas wells drilled in the Appalachian area. Water and foam treatments were tested in the sandstones and cryogenic treatments were tested in the Devonian Shales. Volume 2 contains appendices for the following: Kiel patent - dendritic stimulation; core data; and Terra Trek - rock mechanics reports.

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Fracture of Devonian Shale by Tailored Pulse-Loading

Methods to increase production of natural gas from marginal reserves are being investigated. Because of the potentially large reserves present in the eastern Devonian shales, these materials have been selected for the application and evaluation of novel and existing well fracturing and stimulation techniques. The feasibility of enhancing fracture formation and growth in well stimulation by tailored pulse loading, i.e., shaping the borehole imput pressure-time history to produce a specified fracture pattern is discussed in this report. Specifically, SRI's computational fracture model, NAG-FRAG, was used to evaluate the effect of pulse shape and rock properties in controlling dynamic rock fracture. Preliminary calculations were made of the amount and location of damage in a cylindrical configuration, and laboratory-scale springing experiments were performed to determine the NAG-FRAG fracture parameters of the Devonian shale. The results indicate that in general: the amount and location of tensile cracking in a cylindrical geometry are strongly dependent on the shape of the pulse applied to the borehole; in the range of stress investigated the width of the propagated radial stress pulse is determined largely by the geometry and material properties rather than the shape of the borehole pulse; the shape of the fracture density distribution for a given pulse shape is not strongly dependent on the values of the NAG-FRAG fracture parameters; the magnitude of the circumferential stress occurring in any given annulus of material is little affected by the fracture history of inner annuli; additional calculations are needed in which the interdependence of pulse shape and material properties, such as tensile yield strength, are examined for cylindrical flow; a shear-cracking model should be incorporated into NAF-FRAG; and crack closure and reopening generate instabilities in the calculations.

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Supporting technology for enhanced oil recovery: Polymer predictive model

The Polymer Flood Predictive Model (PFPM) was developed by Scientific Software-Intercomp for the National Petroleum Council's (NPC) 1984 survey of US enhanced oil recovery potential (NPC, 1984). The PFPM is switch-selectable for either polymer or waterflooding, and an option in the model allows the calculation of the incremental oil recovery and economics of polymer relative to waterflooding. The architecture of the PFPM is similar to that of the other predictive models in the series: in-situ combustion, steam drive (Aydelotte and Pope, 1983), chemical flooding (Paul et al., 1982) and CO/sub 2/ miscible flooding (Paul et al., 1984). In the PFPM, an oil rate versus time function for a single pattern is computed and then is passed to the economic calculations. Data for reservoir and process development, operating costs, and a pattern schedule (if multiple patterns are desired) allow the computation of discounted cash flow and other measures of profitability. The PFPM is a three-dimensional (stratified, five-spot), two-phase (water and oil) model which computes water from breakthrough and oil recovery using fractional flow theory, and models areal and vertical sweeps using a streamtube approach. A correlation based on numerical simulation results is used to model the polymer slug size effect. The physical properties of polymer fluids, such as adsorption, permeability reduction, and non-Newtonian effects, are included in the model. Pressure drop between the injector and producer is kept constant, and the injectivity at each time step is calculated based on the mobility in each streamtube. Heterogeneity is accounted for by either entering detailed layer data or using the Dykstra-Parsons coefficient for a reservoir with a log-normal permeability distribution. 24 refs., 27 figs., 59 tabs.

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Gas miscible displacement enhanced oil recovery: Technology status report

Gas miscible displacement enhanced oil recovery research is conducted by the US Department of Energy's Morgantown Energy Technology Center to advance the application of miscible carbon dioxide flooding. This research is an integral part of a multidisciplinary effort to improve the technology for producing additional oil from US resources. This report summarizes the problems of the technology and the 1986 results of the ongoing research that was conducted to solve those problems. Poor reservoir volumetric sweep efficiency is the major problem associated with gas flooding and all miscible displacements. This problem results from the channeling and viscous fingering that occur due to the large differences between viscosity or density of the displacing and displaced fluids (i.e., carbon dioxide and oil, respectively). Simple modeling and core flooding studies indicate that, because of differences in fluid viscosities, breakthrough can occur after only 30% of the total pore volume (PV) of the rock has been injected with gas, while field tests have shown breakthrough occurring much earlier. The differences in fluid densities lead to gravity segregation. The lower density carbon dioxide tends to override the residual fluids in the reservoir. This process would be considerably more efficient if a larger area of the reservoir could be contacted by the gas. Current research has focused on the mobility control, computer simulation, and reservoir heterogeneity studies. Three mobility control methods have been investigated: (1) the use of polymers for direct thickening of high-density carbon dioxide, (2) mobile ''foam-like dispersions''of carbon dioxide and an aqueous surfactant, and (3) in situ deposition of chemical precipitates. 22 refs., 14 figs., 6 tabs.

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Handbook for personal computer version of Boast II: A three-dimensional, three phase black oil applied simulation tool

Computer programs have become an important part of modern petroleum engineering. Black oil simulators, in particular, are used routinely for performing evaluation and design work. Until the 1982 release of BOAST: A Three-Dimensional, Three-Phase Black Oil Applied Simulation Tool, a black oil simulator was available usually only for a substantial fee. Since its release by the Department of Energy, BOAST has gained popularity because of its uncomplicated, easy-to-use features. However, problems occur when BOAST is used for field-scale conditions. BOAST II, released in 1987, was designed to overcome the limitations of the original BOAST. Features were added which would improve the versatility of the program. The amount of code in BOAST II is approximately three times that of the original BOAST. This handbook describes a version of BOAST II that has been developed for use on the personal computer. This version combines most of the options available on the original BOAST II with the size necessary to fit on a personal computer. This makes it possible for users who do not have access to a mainframe computer to use BOAST II. This manual is intended to be only a guideline for the use of the PC version of BOAST II. Detailed discussions on theory, solution methods, program output, and other important topics are found in the BOAST II manual. 5 refs.

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Economic analysis of multizone completion opportunities in the Appalachian Basin

This topical report presents the economic analysis of developing Devonian shale gas reserves beyond the present limits of historical shale gas production. The various completion scenarios investigated include: single zone Devonian shale completion; dual completion of the Devonian shale with the Big Lime and Oriskany; multiple completion of the Big Lime, Big Injun and Devonian shale; deepening an existing Big Lime well to the Devonian shale; and, plugging back an existing Oriskany well to the Devonian shale. 2 refs., 7 figs., 13 tabs.

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Industrial application of fluidized-bed combustion. Quarterly technical progress report, January-March 1980

In line with a determination by the Federal Government that a fluidized bed combustion process can efficiently convert the energy of coal to usable power in an environmentally acceptable manner, Georgetown University was awarded a contract to construct and operate a demonstration plant. This report, which is the fourteenth quarterly progress report under the contract, reflects the progress made during the third quarter of plant startup.

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Cogeneration Technology Alternatives Study (CTAS). Volume II. Comparison and evaluation of results

The specific objectives of the overall CTAS effort were: (1) to identify and evaluate the most attractive advanced energy conversion systems, for implementation in industrial cogeneration systems between 1985 and 2000, that could permit increased use of coal or coal-derived fuels, and (2) to quantify and assess the advantages of using advanced systems in industrial cogeneration. CTAS was concerned exclusively with providing technical and economic comparisons and evaluations of advanced systems as applied to industrial cogeneration rather than with evaluating the merits of the cogeneration concept. At the request of DOE, nine types of energy conversion systems were evaluated in CTAS: (1) steam turbines, (2) diesel engines, (3) open-cycle gas turbines, (4) combined gas turbine/steam turbine cycles, (5) Stirling engines, (6) closed-cycle gas turbines, (7) phosphoric acid fuel cells, (8) molten carbonate fuel cells, and (9) thermionics. Each type of system was examined with a variety of fuels and over a range of parameters and levels of technological advancement that could be made available for implementation between 1985 and 2000. In addition, for the steam turbine, diesel engine, open-cycle gas turbine, and combined-cycle systems, cogeneration results for technology levels and fuels representative of current commercially available equipment were estimated in order to serve as a baseline for evaluating the advantages of advanced systems. The systems were examined in cogeneration applications in a wide variety of representative industrial process plants selected from the highest energy-consuming industries.

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Dunn-Nokota Methanol project, Dunn County, North Dakota. Volume I. Executive summary

The Dunn-Nokota Methanol Project is a mine-mouth, coal-to-methanol complex proposed by The Nokota Company for construction and operation in west-central North Dakota in the Fort Union Coal Region at Dunn County, North Dakota. The Project would produce 86,940 barrels per stream day (BPSD) of methanol from 43,156 net short tons per stream day (ST/SD) of run-of-mine (ROM) lignite coal and have an annual capacity of 29.6 million barrels (1.24 billion gallons) of methanol and 14.7 million tons of ROM coal, based on a 93% onstream factor (340 stream days per year). The objectives of the feasibility studies (together with the parallel activities conducted by Nokota) were to produce data and analyses in sufficient detail to support a determination to proceed to final design, financing, and actual construction of the Project. In meeting this goal, the feasibility studies were designed to provide comprehensive data on the Project's technical, economic, regulatory, and marketing feasibility, as well as available financing and product transportation alternatives; and to identify and consider the significant environmental, health, socioeconomic, and safety concerns arising from construction and operation of the Project. The results of the DOE feasibility studies for the Dunn-Nokota Methanol project are contained in an eight-volume Final Report. This report is a compilation of the summaries contained in each of the other volumes of the Final Report.

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Dunn-Nokota Methanol Project, Dunn County, North Dakota. Volume IV. Product transportation analysis. [Proposed methanol project near Dunn Center, North Dakota]

The objective of this portion of the study was to evaluate the technical feasibility of transportation of methanol and by-products to predefined marketing areas by various modes of transportation including pipeline, rail, truck, and water. The study included a review of codes, standards and regulations; product characteristics in relation to transportation, tentative corridor route selections, permitting requirements, use of existing transportation systems, preliminary engineering costs for the pipeline section and transportation costs for available common carrier modes. The market areas considered in this part of the study were established in the Market Analysis Study (Volume III). The primary market area includes North Dakota, South Dakota, Minnesota, Iowa, Wisconsin, Illinois, Indiana, and Michigan. The secondary market area includes Montana, Wyoming, Colorado, Nebraska, Missouri, and Ohio. The West Coast market area consists of California, Oregon, and Washington. The study included investigation of use of existing pipeline systems and tentative selection of routings for eleven system alternatives, in corridors adjacent to existing or proposed pipelines. The eleven alternative pipeline routes are identified in Table 2-1 and include new dedicated systems and use of existing systems by batching. A generalized map showing the geographic relationship of the alternative routes is shown in Figure 2-1 and Figure 2-2 indicates possible terminal locations for the Minneapolis and Chicago areas.

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Dunn-Nokota Methanol Project, Dunn County, North Dakota. Volume VIII. Coal quality analysis. [Proposed methanol project near Dunn Center, North Dakota]

John T. Boyd Company's assignment for the Dunn-Nokota Methanol feasibility study was to determine the quality of the Dunn Center lignite seams for the area studies, both on an in-place and run-of-mine basis. Previous available quality data was reviewed, absence of required data noted, and a new drilling program designed to complete the data base. Additional core samples were taken in March, April, and October of 1981, analyzed and the quality weight-averaged with previous data to develop average field quality. A geological reserve study was completed in 1980 by Boyd Company which incorporated information from 747 rotary holes and quality from 52 cores holes. Of these core holes, 32 have influence in the area of interest used for this study. The laboratory analysis from the 32 core holes within the area of interest are summarized in this subsection. The data are reported on in-place dry, in-place as-received, and in-place equilibrium moisture bases and adjusted for out-of-seam dilution to the run-of-mine, equilibrium moisture basis. Laboratory analysis provides the basic data to compute field quality Table 2-1 presents the previous quality data on an in-place, dry basis by seam.

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Characterization and modification of particulate properties to enhance filtration performance

The specific objectives of this project are to characterize the particulate properties that determine the filtration performance of fabric filters, and to investigate methods for modifying these particulate properties to enhance filtration performance. Inherent in these objectives is the development of an experimental approach that will lead to full-scale implementation of beneficial conditioning processes identified during the project. The general approach has included a large number of laboratory evaluations to be followed by optional field tests of a new successful conditioning processes performed on a sidestream device. This project was divided into five tasks. The schedule followed for these tasks is shown in Figure 4. Tasks 2 and 3 each focus on one of the two complementary parts of the project. Task 2 Parametric Tests of Ashes and Fabrics, evaluates the degree to which ash properties and fabric design determine filtration performance. Task 3 Survey of Methods to Modify the Particle Filtration Properties, provides a literature review and laboratory study of techniques to modify ash properties. The results of these two tasks were used in Task 4 Proof-of-Concept Tests of Methods to Modify Particle Filtration Properties to demonstrate the effects on filtration performance of modifying ash properties. The findings of all the tasks are summarized in this Final Report. 13 refs.

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Dunn-Nokota Methanol Project, Dunn County, North Dakota. Volume II. Preliminary plant design and cost estimate. [Proposed methanol project near Dunn Center, North Dakota]

This volume continues plant engineering studies as follows: water supply, solid waste (characteristics and disposal methods), sulfur balance, emissions, discussion of certain plant processes and start-up procedures, product and by-product specifications, construction plan, capitalized and operating cost estimates, alternative design and process studies, processing of contaminated methanol, purchase of electric power as power generation, cost reduction studies, carbon dioxide incineration (to burn impurities if no market develops), health hazard analysis (including regulations, control measures and monitoring and surveillance), and safety analysis (including regulation and control). (LTN)

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