AndreaBozzo/ceres-open-data-index huggingface dataset:
Microbial enhanced waterflooding Mink Unit and Phoenix field pilots. Final report

To determine the feasibility of improving oil recovery and the economics of microbial enhanced waterflooding in mature oil wells in the United States, two field pilots have been conducted. Candidate fields were screened to determine whether they have any potential for a microbial system developed at the National Institute for Petroleum and Energy Research (NIPER), and microbial compatibility tests were conducted in the laboratory to select the target field. A specific microbial formulation was selected that was compatible with the chosen reservoir environment and had been shown to recover oil after waterflooding in Berea sandstone and field core. The microbial formulation was designed to improve microscopic oil displacement efficiency by surfactant, gas and acid production from fermentation of molasses. A 20-acre pilot test was initiated in October 1986, and completed in December 1989. Results from this pilot demonstrated that microorganisms could be injected into an ongoing waterflood and that such injection could increase oil production by at least 13%. A larger test (520 acres) was completed in the same formation to evaluate the feasibility of commercial application of the technology. This field pilot was injected with microorganisms and molasses from a centralized injection station in June 1990. Although microorganisms were injected only once per site, nutrient injection continued throughout the project life. All 19 injection wells were treated, and oil production was monitored from the 47 production wells. Injection pressures and volumes were monitored throughout the project. No operational problems were encountered. At the end of May 1993, oil production was improved by 19.6 %. Results from both projects are presented and the potential for microbial-enhanced waterflooding technology is evaluated.

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Commercial scale demonstration, enhanced oil recovery by micellar-polymer flooding. Initial report, October--December 1976

This commercial scale test, known as the M-1 Project, is located in Crawford County, Illinois. The M-1 Project area encompasses approximately 407 acres of Robinson Sand reservoir; the area covers portions of several waterfloods that were developed on 10-acre spacing in the 1950's and are now approaching their economic limit. This report covers the interim from contract execution, September 30, 1976, through December 31, 1976. Limited additional information and data obtained prior to September 30, 1976, are also included in this first report to add continuity. (DLC)

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Advanced coal-fueled gas turbine systems

No combustion tests for this program were conducted during this reporting period of January 1 to March 31, 1992. DOE-sponsored slogging combustor tests have been suspended since December 1991 in order to perform combustion tests on Northern States Power Company (NSP) coals. The NSP coal tests were conducted to evaluate combustor performance when burning western sub bituminous coals. The results of these tests will guide commercialization efforts, which are being promoted by NSP, Westinghouse Electric, and Textron Defense Systems. The NSP testing has been completed and preparation of the final report for that effort is underway. Although the NSP testing program has been completed, the Westinghouse/DOE program will not be resumed immediately. The reason for this is that Textron Defense Systems (TDS) has embarked on an internally funded program requiring installation of a new liquid fuel combustor system at the Haverhill site. The facility modifications for this new system are significant and it is not possible to continue the Westinghouse/DOE testing while these modifications are being made. These facility modifications are being performed during the period February 15, 1992 through May 31, 1992. The Westinghouse/DOE program can be resumed upon completion of this work.

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Proceedings of second annual underground coal gasification symposium

The Second Annual Underground Coal Gasification Symposium was sponsored by the Morgantown Energy Research Center of the US Energy Research and Development Administration and held at Morgantown, WV, August 10-12, 1976. Fifty papers of the proceedings have been entered individually into EDB and ERA. While the majority of the contribution involved ERDA's own work in this area, there were several papers from universities, state organizations, (industrial, engineering or utility companies) and a few from foreign countries. (LTN)

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Subsurface stratigraphy and gas production of the Devonian shales in West Virginia

The subsurface Devonian shales are defined as all of the fine clastic rocks between the top of the Onondaga Limestone and the base of the Berea Sandstone. This term is used only in the western one-third of the state where the thickness of these shales ranges from 1000 to 3000 feet. The interval thickens to the east and northeast and facies changes to coarser clastics occur. In north-central West Virginia numerous sandstones and siltstones have replaced much of the shale section, particularly the so-called Brown shales. These shales are actually dark gray to black, organic-rich, generally non-silty shales that yield higher natural radioactivity readings on a gamma-ray log, and low readings on a density log. Sample descriptions, cable-tool drillers'logs, and gamma-ray and density logs are all used to subdivide the Devonian shales into 4 zones: a thick (1100 to 1200 feet) upper sandy, silty, gray, and greenish gray shale; a thinner (300 to 400 feet) zone consisting of two dark to very dark gray shales (the Brown shales of the driller) separated by a thin gray shale; a greenish gray, generally non-silty shale; and the lowermost interval that consists of very dark to black shales, often calcareous near the base. A thin limestone is often noted within the lowest black shale and is usually referred to by drillers as the Tully. Farther to the west and southwest a fifth zone, a younger Brown shale, is present near the top of the Devonian shale sequence in the approximate stratigraphic position of the Cleveland Shale of Ohio. Natural gas has been produced for nearly 50 years from relatively shallow-depth, low-volume wells completed in the Brown shales and adjacent units. Although these wells are marginally economic at current costs, prices, and completion techniques, these shales represent a very large gas resource with less than 10 percent of the calculated gas in place ever produced.

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Systems studies of energy conservation:  methane produced from coalbeds. [177 references]

Utilization of coalbed methane gas is practicable and economically favorable. Drainage of methane in advance of mining, and from gob areas subsequent to mining, decreases the quantity of methane now being released into the mine environment. Such drainage reduces ventilation requirements and the hazards of removing methane by this technique. Therefore, a severe hazard is significantly reduced, greatly enhancing underground mine safety. Differences in type of mining in progress, site access, availability of commercial gas transmission pipelines, ownership of surface rights and gas rights, legal constraints, etc., require several different techniques for gas recovery and several variant uses for the recovered methane gas. Cost-sharing of demonstration projects between government and private interests is necessary to expedite early commercial applications and encourage conservation of this resource. Legal problems and possible litigation may result when coalbed methane gas is recovered and utilized in a profitable venture. Coal rights agreements vary in mining ventures, and when they do not specifically state or imply the right to recover gas released in conjunction with mining requirements, litigation to recover royalties likely to result.

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Advanced Turbine Systems Program conceptual design and product development. Quarterly report, November 1993--January 1994

This Quarterly Technical Progress Report covers the period November 1, 1993, through January 31, 1994, for Phase 11 of the Advanced Turbine Systems (ATS) Program by Solar Turbines Incorporated under DOE Contract No. DE-AC421-93MC30246. The objective of this program is to provide the conceptual design and product development plan for an industrial gas turbine system to operate at a thermal efficiency of 50 percent ({open_quotes}ATS50{close_quotes}) with future improvement to 60 percent ({open_quotes}ATS60{close_quotes}). During the prior quarter Solar`s ATS Engine Design Team characterized the intercooled and recuperated (ICR) gas turbine cycle in 1-spool, 2-shaft, and 2-spool 3-shaft arrangements. Fixed and variable geometry free power turbines were compared in both arrangements and sensitivity of all combinations to component performance was determined. Full- and part-load performance were compared over a range of ambient air temperatures. During the quarter just completed, the Team defined four unique and different physical arrangements of the gas turbine components outlined above. These three arrangements were then examined in terms of their ability to support Program goals of thermal efficiency, low emissions, increased reliability, availability and maintainability (RAM), and reduced cost of electrical power production. This work, together with preliminary specification of component cooling needs, suggested that earlier studies of the pressure ratio/firing temperature/thermal efficiency relationship should be re-visited. This accomplished, the effect of total cooling air bleed requirements on thermal efficiency was determined. This will lead to the selection of hot section material capability/cooling air requirements which are able to meet Program goals. As noted in the first quarterly report, where there are apparently conflicting data, later results should take precedence due to the continuing refinement of analytical models.

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Massive hydraulic fracturing experiment No. 1 Home Federal well, Uintah County, Utah

Two massive hydraulic fracturing experiments were performed on two separate gas-bearing intervals of Mesaverde sandstones in the No. 1 Home Federal well located in Uintah County, Utah. Water-base gel carrying sand proppant was used as the frac medium and the limited entry technique was used for injection. The first experiment was carried out on an interval containing 112 ft of net pay between 10,014 and 10,202 ft. Pre-frac production capacity was estimated to be 60  MCF/D. Post-frac production capacity was significantly less, presumably attributable to a limited lateral extent of inherent formation permeability. The second experiment was carried out on an interval containing 85 ft of net pay between 7826 and 9437 ft. Pre-frac production capacity of 33 MCF/D was increased by MHF to an initial 500 MCF/D and to a relatively stabilized 155 MCF/D within four months following the treatment.

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Clean coal reference plants: Atmospheric CFB. Topical report, Task 1

The Clean Coal Technology Demonstration Program is a government and industry cofunded technology development effort to demonstrate a new generation of innovative coal utilization processes in a series of full-scale facilities. The goal of the program is to provide the US energy marketplace with a number of advanced, more efficient and environmentally responsive coal-using technologies. The Morgantown Energy Technology Center (METC) has the responsibility for monitoring the CCT Projects within certain technology categories, which correspond to the center`s areas of technology development, including atmospheric fluidized bed combustion, pressurized fluidized bed combustion, integrated gasification combined cycle, mild gasification, and industrial applications. A measure of success in the CCT program will be the commercial acceptance of the new technologies being demonstrated. The dissemination of project information to potential users is being accomplished by producing a series of reference plant designs which will provide the users a basis for the selection of technologies applicable to their future energy requirements. As a part of DOE`s monitoring and evaluation of the CCT Projects, Gilbert/Commonwealth (G/C) has been contracted to assist in this effort by producing the design of a commercial size Reference Plant, utilizing technologies developed in the CCT Program. This report, the first in a series, describes the design of a 400 MW electric power plant, utilizing an atmospheric pressure, circulating fluidized bed combustor (ACFB) similar to the one which was demonstrated at Colorado-Ute`s Nucla station, funded in Round 1 of the CCT Program. The intent of the reference plant design effort was to portray a commercial power plant with attributes considered important to the utility industry. The logical choice for the ACFB combustor was Pyropower since they supplied the ACFB for the Nucla Project.

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Properties of shale-oil asphalts from Colorado oil shale

Asphalts from N-T-U crude oil of Green River oil shale at Rifle (Colo.) were prepared by vacuum distillation, propane precipitation, air-blowing, and by thermal cracking of the crude oil, and were then evaluated according to commercial specification tests. A 116 penetration (at 77/sup 0/ F.) asphalt, prepared by vacuum distillation and representing 17 percent of the crude oil, contained 85.02 percent carbon, 10.24 percent hydrogen, 2.82 percent nitrogen, 0.56 percent sulfur, and 1.36 percent oxygen (by difference). A similar asphalt of 173 penetration contained 15 percent asphaltenes, 47 percent resins, and 38 percent oils. The nitrogen contents of these constituents increased with increasing molecular weight; the oils contained 1.1 percent nitrogen, resins 3.4 percent, and asphaltenes 4.5 percent.

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Hot low Btu producer gas desulfurization in fixed bed of iron oxide-fly ash. Final report, 1 July 1975--30 April 1977. Volume I

This work was undertaken to support the Morgantown Energy Research Center on their development of a process for desulfurizing hot, low BTU producer gas with iron oxide sorbents. Specific objectives were sorbent development and definition of scale-up criteria for commercial design. Several experimental sorbents were prepared using commercially available raw materials and were tested for capacity for hydrogen sulfide removal from the producer gas. Effects of iron oxide source, iron oxide content, sorbent support and binder on sorbent performance were investigated. Changes in properties like porosity, crushing strength, surface area, attrition resistance, x-ray diffraction patterns, DTA, density of the sorbents after undergoing a single absorption and regeneration cycle were evaluated. Effects of process variables like GHSV, superficial velocity, temperature, H/sub 2/S concentration in producer gas, pellet diameter, iron oxide content and pressure on the absorption dynamics were experimentally determined. Several mathematical models to describe the isothermal sorption of H/sub 2/S were developed. All the models were evaluated using experimental data. The semi-empirical model was able to predict the shapes of breakthrough curves and sorbent performance at 10% breakthrough for H/sub 2/S. Several schemes were considered to regenerate sulfided sorbents and yield a high concentration of sulfur dioxide without exceeding 1500/sup 0/F. A short experimental program was completed to study effects of process variables on regeneration dynamics using air-stream. Heat effects for the highly exothermic regeneration were incorporated in the isothermal sorption models and were tested with experimental data. The adiabatic kinetically controlled model was best able to correlate the regeneration data.

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Analysis of reservoir heterogeneities due to shallowing-upward cycles in carbonate rocks of the Pennsylvanian Wahoo Limestone of Northeastern Alaska

The primary objective of this project is to develop an integrated database to characterize reservoir heterogeneities resulting from numerous small-scale shallowing-upward cycles (parasequences) comprising the carboniferous Pennsylvanian Wahoo Limestone. The Wahoo Limestone is the upper formation of an extensive carbonate platform sequence of the Carboniferous Lisburne Group which is widely exposed in the Brooks Range and is a widespread hydrocarbon reservoir unit in the subsurface of the North Slope of Alaska. A principal goal is to determine lateral and vertical variations in the complex mosaic of carbonate facies comprising the Wahoo Limestone. This report presents the preliminary results of research accomplished by a team of specialists in carbonate petrology, biostratigraphy, and diagenesis during the 1990--1991 fiscal year.It includes a summary of regional geological framework studies, a discussion conodont analyses, an overview of diagenetic studies, a brief description of progress in computerized database development, and appendices containing some of the new data on petrographic analyses, conodont analyses, and locality and sample information. Our correlation scheme, which uses cyclic stratigraphy, biostratigraphy, and cement stratigraphy, will allow interpretation of the depositional history and paleogeographic evolution of the region. We have developed predictive facies models and will make paleogeographic maps to illustrate different stages in the history of the Wahoo carbonate ramp. Our detailed analyses of the Wahoo Limestone will provide a basis for interpreting correlative rocks in the adjacent subsurface of the coastal plain of ANWR, a potential hydrocarbon lease-sale area. In a broader sense, our work will provide an excellent generic example of carbonate shallowing-upward cycles which typify carbonate sediments.

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Detailed project plan: Design, construction and operation of pilot scale Charfuel{reg_sign} process. Topical report, Task 2

In this project, a pilot-scale facility for the flash hydropyrolysis of coal will be designed, built and operated to demonstrate the integrated operation of critical components of the CHARFUEL process and to obtain scale-up data for subsequent demonstration facility for the production of a clean coal slurry fuel. This report presents project plans which includes detailed construction plan; procurement of materials and equipment; construction, test and start-up; potential problems and solutions during operations; data collection and analysis; and feasibility analysis.

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Field and laboratory procedures for oriented core analysis of Devonian shales

Field and laboratory procedures for handling, performing a lithologic description, marking azimuth directions, mapping the native fractures, and measuring directional physical properties of oriented cores are described. In the fulfillment thereof, directional properties of tensile strength, and sonic velocity are correlated with preferred planes of weakness and orientation of visible fractures in the core to ascertain the preferred direction of fracture orientation that should occur in the hydraulic fracturing process. Characterization of the lithology is required to identify intervals for stimulation. Measurements of hardness are conducted to identify containment barriers to fracture growth vertically. All information is required to assist in the design and the development of a pattern of fractured wells for commercialization. Definition and description of the activities required to extract and characterize the oriented cores should serve as the standard methodology for all Devonian Shale core analysis.

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Development of an inflow performance relationship (IPR) for a slanted/horizontal well

Since 1968, the Vogel equation has been used extensively and successfully for analyzing the inflow performance relationship (IPR) of flowing oil wells under solution-gas drive. Oil well productivity can be rapidly estimated using the Vogel IPR curve and well outflow performance. However, the Vogel curve was originally developed for conventional vertical wells and may not be valid for slanted and horizontal wells. This report presents the development of IPR's for slanted and horizontal wells by using a vertical/horizontal/slanted well reservoir simulator. The generated IPR's are found to be similar to the parabolic characteristic of the Vogel curve. Several application examples are included to illustrate the use of the newly generated curves. 12 refs., 15 figs., 25 tabs.

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Ground movements associated with gas hydrate production. Progress report, January 1--March 31, 1993

The grantee will evaluate the influence of hydrate production on ground subsidence near the wellbore and the surface. The objective of this research will be achieved by using computer simulations of what is expected in a hydrate reservoir during the production stage as reported by hydrate production models and available data. The model will be based on theories of continuum mechanics, thermomechnanics of hydrate production, principles of rock mechanics and geomechanics, and special features of geomaterials under cold temperatures such as those found in permafrost regions. The research work involved in the proposed investigation will be divided into three major tasks: mechanics of subsidence in permafrost regions; modeling of subsidence; and parametric studies. Under task 1, the literature survey was completed, and following factors were identified influencing subsidence: overburden depth; extent of dissociated (or depleted) hydrate reservoir; rock/frozen soil mechanical properties and strength; and reservoir compaction characteristics. Under task 2, technical progress is reported for studies on: mechanical properties; simulation of reservoir compression; and computer modeling effort.

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Proceedings of the ninth annual gasification and gas stream cleanup systems contractors review meeting

Research programs, presented at the contractors review meeting on gasification and gas stream cleanup systems, are presented. Major topics included the following: systems for the production of power, systems for gas stream cleanup, production of synthesis gas, and production of co-products. Poster session topics are included. A total of sixty-six topics (including poster session topics) were addressed. Individual projects are processed separately on the data bases. (CBS)

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Review of EOR (enhanced oil recovery) project trends and thermal EOR (enhanced oil recovery) technology

Information on United States (US) enhanced oil recovery (EOR) projects is analyzed to discern trends in applications of EOR technologies. This work is based on an evaluation of current literature and analysis of the Department of Energy (DOE) EOR project data base which contains information on over 1,300 projects. Three-quarters of current US oil production attributed to EOR is derived from thermal EOR processes (TEOR). Changes in the technology of TEOR since the 1984   Enhanced Oil Recovery''study by the National Petroleum Council (NPC) are reviewed in terms of the current applied technology and reported research. 87 refs., 4 figs., 20 tabs.

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Ground movements associated with gas hydrate production. Progress report, July 1--September 30, 1992

The grantee will evaluate the influence of hydrate production on ground subsidence near the wellbore and the surface. The objective of this research will be achieved by using computer simulations of what is expected in a hydrate reservoir during the production stage as reported by hydrate production models and available data. The model will be based on theories of continuum mechanics, thermomechanics of hydrate production, principles of rock mechanics and geomechanics, and special features of geomaterials under cold temperatures such as those found in permafrost regions. The research work involved in the proposed investigation will be divided into three major tasks: (1) Mechanics of subsidence in permafrost regions; (2) modeling of subsidence; and (3) parametric studies. Progress reports are presented for tasks 1 and 2.

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