AndreaBozzo/ceres-open-data-index huggingface dataset:
Improvement of CO/sub 2/ flood performance. Quarterly report, January 1-March 31, 1985

Progress has been made in each of the three major areas which our CO/sub 2/ flooding research is directed. In the phase behavior area, there is continuing effort for the refinement of the existing Continuous Multiple Contact (CMC) experiment. One of the high-pressure, oscillating crystal viscometers designed for use in this system has been completed, leak-tested and checked electrically. The entire CMC system is being reconstructed to fit into a temperature-controlled air bath, and for operation without use of mercury. The major new data from the reconstructed apparatus will concern the viscosities of the CO/sub 2/-rich and of the heavier fractions that may comprise part of the transition zone during displacements both above and below the MMP. The phase behavior and fluid properties activity has also produced further thermodynamic calculations and data for the correlation of MMP and oil composition. The second area of activity concerns the fluid-mechanical and chemical processes involved in displacement itself. Research in this category is concerned both with the microscopic or pore-level aspects, and with larger scale description. An important objective of this part of the work is to define and elucidate the dependence of reservoir-scale displacement behavior on those smaller-scale core and micromodel properties which are accessible to laboratory measurements. To this end, there are continuing observations of diffusion processes in CO/sub 2/ and of displacement mechanisms in etched-glass micromodels, as well as core-flooding studies. The third area of research on CO/sub 2/ flooding concerns another aspect of large-scale displacement phenomena - the effect of the unfavorable mobility ratio between displaced and displacing fluids. Progress is reported here on the selection of new surfactants for use in making ''CO/sub 2/-foams,''and also in the synthesis of polymeric solutes to increase the viscosity of dense CO/sub 2/. 29 refs., 27 figs., 3 tabs.

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Field experiment of improved steam drive with in-situ foaming. Final report

This report discusses the design, execution, results, conclusions and recommendations of a field experiment of improved steam drive with in-situ foaming by the surfactant Suntech IV in the Kern River Field of California. The project background, goals and field work are described. Several standards and experimental analytical methods have been applied to define the reservoir and to monitor the progress of the field experiment. The analysis of the results indicates that Suntech IV surfactant improved heavy recovery by steam drive with in-situ foaming and could successfully and economically be employed on a leasewide basis. 12 references, 22 figures, 7 tables.

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H/sub 2/S removal from coal gas at mid-temperature (150 to 200/sup 0/C)

The objective of the program reported here was to develop and evaluate mid-temperature H/sub 2/S removal processes. The program was carried out in two phases divided into four tasks: Phase I Absorbent Evaluation (chemistry, mass transfer,5663 ); Phase II Process Development and Evaluation (process evaluation, slip stream verification). The absorption reactions proposed for mid-temperature H/sub 2/S removal processes are the precipitation of metal sulfate or metal hydroxide to metal sulfides, and the oxidation of H/sub 2/S for production of elemental sulfur and sulfates. Zinc, nickel, and iron were evaluated as metal sulfate or hydroxide absorbents. Organometallic redox reagents and compounds of nickel or iron were employed as absorbents for processes involving oxidation of H/sub 2/S. These processes were evaluated in Tasks I, II, and III; in Task IV the most promising processes were demonstrated on a slip stream from the gasifier. The direct oxidation process with either NiSO/sub 4/ or Fe(OH)/sub 3/ absorbent was selected for further devaluation in Task III. The operating conditions for each process were determined using simulated coal gas. Regeneration of absorbents was studied. In Task IV, the direct oxidation process was operated with a slip stream of coal gas produced by the GE fixed-bed gasifier. The H/sub 2/S and COS absorption efficiency and optimum operating conditions for operation with coal gas were determined. The overall applicability of the direct oxidation process was evaluated. 21 figures, 24 tables.

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Experimental evaluation of the steady-state and dynamic performance characteristics of the interactive units of a coal gasification process. Quarterly report, 28 June 1982-26 September 1982

Coal gasification/gas cleanup fuel plants for synthetic fuel applications must be developed within the constraints imposed by the end-use application, which include compliance with environmental regulations and dynamic response to variations in load demand. The overall objective of this program is to develop the technology base required to permit coal conversion systems to operate within those constraints. The fuel plant performance will be characterized in both steady state and dynamic operations; component interactions and end-use interactions will also be characterized. The information required to establish system control logic will be developed. An integrated coal gasification system composed of proven process units (i.e., a Process Evaluation Facility - PEF) is being used for generating an experimental information base to: characterize effluent flow streams from the process; establish individual PEF component performance parameters; define dynamic interactions of components operating in a variable load situation; and verify a simulation model for integrated component operations. The combined experimental/analytical approach employed will yield empirically verified performance projections for full-scale systems. The activities for this program are divided into six tasks: (1) test program definitions and analysis; (2) facility operation; (3) system modeling; (4) component support requirements; (5) fuel system modifications; and (6) program management. Progress reports of these tasks are presented. 25 figures, 14 tables.

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Conceptual models for gas hydrates. Phase I. Technical Directive 6. Final report. [Steam injection; fracturing; decompression]

Three conceptual models for the recovery of methane hydrates are discussed in this report that address different recovery methods for producing gas from hydrates. The three models are: (1) single-well cyclic thermal injection; (2) multi-well continuous thermal injection; and (3) reservoir depressurization. In the first model, a reservoir is stimulated (either radially, horizontally or vertically), steam is injected, and water/gas are produced cyclically. In the second model, 2 or more wells are interconnected by an induced fracture and the injection of steam and production of gas and water are continuous. In the third model, an induced fracture with a large surface area is propagated into the reservoir, the pressure in the fracture is maintained at a low value, and gas is produced through the gas-ice zone as the hydrate dissociates. The three conceptual hydrate recovery models represent original work as well as building on prior work by others. Five previously published models are reviewed for their strong and weak points and applicability to this modeling effort is summarized in Attachment A. 16 figures, 1 table.

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Photoassisted electrolysis applied to coal gasification. Final report, 2 July 1981-1 September 1983

This project was carried out to test the technical feasibility of coal gasification employing semiconductor electrodes with solar energy. The project consisted of five tasks. In Task 1, a literature search was conducted on electrochemistry of coal and carbonaceous materials and conclusions are presented. Topics reviewed include: electrochemistry of various forms of carbon, chemical oxidation and reduction of coal, electrochemical oxidation and reduction of coal, photoelectrochemistry of coal, and direct power generation from coal burning fuel cells. In Task 2, the oxidation mechanisms of coal slurries in electrolysis cells were studied in detail. Results indicate that coal is catalytically oxidized by Fe(III) leached out in the acidic medium. The Fe(II) produced in the process is oxidized back to Fe(III) at the anode. Various other catalysts were studied and their reaction rate constants measured. In Task 3, studies of photoassisted coal gasification reactions at n-SnO/sub 2/, n-WO/sub 3/, n-CdS, and n-CdSe electrodes were carried out, and substantial photocurrents were generated. Methods of preparation of semiconductor thin film electrodes were studied, and successfully used. In Task 4, rotating ring-disk electrode techniques were developed and used to study various methods of stabilizing semiconductor electrodes. Electrodes were stabilized substantially by coating with conductive organic polymers, inert metal films, or heavily doped metal oxides such as heavily doped SnO/sub 2/. Electrodes thus stabilized last only a few days for photoassisted coal gasification reactions; much longer term stabilities would be needed for practical applications. The basic concept of using solar energy for gasification of coal was technically demonstrated. 57 figures, 3 tables.

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Houston area medium-Btu coal-gasification project feasibility study. Final report. Volume IV. Environmental, safety, health and socioeconomic factors. [Production based on using Texaco gasifiers to process Illinois No. 6 coal barged to the site]

The Houston Project entails constructing and operating a centralized facility to produce hydrogen, syngas, and fuel gas and distribute these gases to refineries and chemical plants in the Houston Ship Channel area. The ultimate goal of the feasibility study was to ascertain the technical and economic viability of advancing to the commercial stage. Thus, the essential element was to develop a technically sound design and perform the supporting studies necessary to generate a cost estimate that could be used with confidence for economic and business analyses. The study included seven overall tasks: (1) preliminary facility and distribution system design; (2) economic and financial analysis; (3) marketing analysis; (4) site selection and evaluation; (5) resource assessment; (6) environmental, safety, health, and socioeconomic analysis; and (7) study management. The 18-month study was concluded in March 1982. The final report presents a description of the effort performance, the results, and the conclusions. The report consists of four volumes. Volume I contains a brief overview of the entire study with emphasis on results and conclusions that significantly impact the decision to proceed. The risks in this first-of-a-kind project are high and the decision to proceed is clouded by uncertainties. Four critical elements would be necessary to ensure commercial viability: moderate real growth in world oil prices; acceptable long-term purchase contracts for the hydrogen and syngas; partners for the venture; and consistent government policies regarding synfuels and taxes. 10 figures, 6 tables.

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Assessment of coal gasification/hot gas cleanup based advanced gas turbine systems

The major objectives of the joint SCS/DOE study of air-blown gasification power plants with hot gas cleanup are to: (1) Evaluate various power plant configurations to determine if an air-blown gasification-based power plant with hot gas cleanup can compete against pulverized coal with flue gas desulfurization for baseload expansion at Georgia Power Company's Plant Wansley; (2) determine if air-blown gasification with hot gas cleanup is more cost effective than oxygen-blown IGCC with cold gas cleanup; (3) perform Second-Law/Thermoeconomic Analysis of air-blown IGCC with hot gas cleanup and oxygen-blown IGCC with cold gas cleanup; (4) compare cost, performance, and reliability of IGCC based on industrial gas turbines and ISTIG power island configurations based on aeroderivative gas turbines; (5) compare cost, performance, and reliability of large (400 MW) and small (100 to 200 MW) gasification power plants; and (6) compare cost, performance, and reliability of air-blown gasification power plants using fluidized-bed gasifiers to air-blown IGCC using transport gasification and pressurized combustion.

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Laboratory investigation of briquettes, wafers, and pellets from coal fines for fixed-bed gasification. Task 1-C and Task 1-D

This report presents the results of studies to determine the technical and economic aspects of coal agglomeration. The agglomerated coal is to be used as a feed coal to a fixed-bed type coal gasification facility. Up to eight coals are examined for agglomerating properties in three different agglomeration techniques: water briquetting in a Carver press; roll briquetting in a double roll briquetter, and pelletizing on a one meter inclined disc pelletizer. The wafer briquetting functioned as a screening examination for various coal/binder combinations to be examined in roll briquetting and pelletizing. Prepared agglomerates were examined in a series of tests to determine their ability to withstand handling and gasification. These tests included: crush strength tests of green agglomerates, hot agglomerates and cured or post (agglomeration) treated agglomerates; high temperature exposure tests; tumble tests on green, posttreated and agglomerates after high temperature exposure; Burghardt tests; small scale gasifier tests; and a high temperature degradation test. Many agglomerates failed the least severe of these tests and thus, were not subjected to the more severe tests.

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Microbial degradation of polycyclic aromatic hydrocarbons under denitrification conditions in soil-water suspensions: Final report

The microbial degradation of polycyclic aromatic hydrocarbons (PAH) under different redox conditions was examined for soil-water suspensions, with particular emphasis on microbial degradation under denitrification conditions. Batch microbial degradation tests of naphthol, naphthalene, and acenaphthene with 1 gram of soil per 50-ml aqueous phase were conducted under aerobic and anaerobic conditions. A conceptual model was proposed to describe the aqueous-phase concentration of PAH solute under denitrification conditions for soil-water systems maintained under gentle suspension. The approach combined an intra-aggregate radial diffusion model to represent solute sorption and desorption with soil, with either Monod or first-order kinetics to describe the microbial degradation of solute from the bulk-aqueous phase. The microbial degradation of naphthalene in soil-water suspensions under denitrification conditions was modeled by the coupled desorption-degradation approach in order to evaluate unexplored situations in which soil particle size may affect the rate of microbial degradation. A preliminary assessment of the effect of solute hydrophobicity on microbial degradation was modeled for volumetric mean particle radii in the range of 0.01 to 0.1 cm. The coupled desorption-degradation model and first-order aerobic degradation kinetic information from the literature used to predict the aqueous- and sorbed-phase concentrations for the solutes naphthalene, anthracene, and benzo(a)pyrene. 43 refs., 53 figs., 10 tabs.

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Advanced water-cooled phosphoric acid fuel cell development

The Advanced Water Cooled Phosphoric Acid Fuel Cell Development program is being conducted by International Fuel Cells Corporation (IFC) to improve the performance and minimize the cost of water cooled, electric utility phosphoric acid fuel cell stacks. The program adapts the existing on-site Configuration B cell design to electric utility operating conditions and introduces additional new design features. Task 1 consists of the conceptual design of a full- scale electric utility cell stack that meets program objectives. Tasks 2 and 3 develop the materials and processes required to fabricate the components that meet the program objective. The design of the small area and two 10-ft{sup 2} short stack is conducted in Task 4. The conceptual design also is updated to incorporate the results of material and process developments, as well as results of stack tests conducted in Task 6. Fabrication and assembly of the short stacks are conducted in Task 5 and subsequent tests are conducted in Task 6. The Contractor expects to enter into a contract with The Electric Power Research Institute (EPRI) to assemble and endurance test the second 10-ft{sup 2} short stack. This report describes the cell design and development effort that is being conducted to demonstrate by subscale stack test, the technical achievements made toward the above program objectives. 9 figs., 6 tabs.

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Corrosion due to use of carbon dioxide for enhanced oil recovery. Final report. SumX No. 78-003

This study documents the specific effects of CO/sub 2/ on corrosion and identifies promising methods for controlling corrosion in fields using CO/sub 2/ injection. Information has been assembled on: CO/sub 2/ corrosion problems in general, surface and downhole corrosion problems specifically associated with CO/sub 2/ enhanced oil recovery, and methods to reduce corrosion problems in CO/sub 2/ environments. Corrosion mechanisms, kinetic behavior, and the effects of various parameters on corrosion by CO/sub 2/ are presented in this study. Engineering metals are not attacked by CO/sub 2/ under oil field environments unless liquid water is also present. Plain and low alloy steels are attacked by mixtures of CO/sub 2/ and liquid water. Attack on these bare metals may become serious at a CO/sub 2/ partial pressure as low as 4 psi and it increases with CO/sub 2/ partial pressure although not in direct proportion. Fluid flow rate is an important factor in CO/sub 2//water corrosion. Practically all stainless steels and similar resistant alloys are not particularly subject to corrosion by CO/sub 2//water mixtures alone, even at high CO/sub 2/ pressures. Elevated levels of CO/sub 2/ can aggravate the corrosive effects of other species such as hydrogen sulfide, oxygen, and chloride. Mixtures of CO/sub 2/, carbon monoxide (CO), and water can cause stress corrosion cracking of plain steels. Corrosion problems in CO/sub 2/ systems should be circumvented when possible by avoiding combination of the corrosive components. Although water cannot be excluded throughout the CO/sub 2/ injection-oil production-CO/sub 2/ and water reinjection chain, air in-leakage can be minimized and oxygen scavengers used to remove any residual. Exclusion of oxygen is important to the successful use of other corrosion control measures. A discussion is given of the main control methods including metal selection, protective coatings and nonmetallic materials, and chemical inhibition. (DLC)

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Analysis of pressure data of vertically fractured injection wells

This study investigates the flowing and shut-in pressure behavior of a fractured well located in a square drainage region with the outer boundary at a constant pressure. The fracture plane lies on one of the diagonals of the square. The results can be used to analyze pressure data for a five-spot pattern when the fracture orientation is most favorable (from the viewpoint of sweep efficiency). Comparisons with the results in the literature (which assume that the fracture orientation is unfavorable) are given. It is shown that the fracture orientation must be considered in the analysis of pressure data for the following conditions: (i) small values of fracture penetration ratio, (ii) large flowing times prior to shut-in, and (iii) large values of fracture flow capacity. New insights into the application of type curve analysis to estimate drainage volumes are presented. The drainage volume can be obtained from a pressure fall-off test only if the flowing times prior to shut-in are large. The estimate of the drainage volume obtained by type curve matching pressure build-up data can be erroneous even if producing times are long. Claims in the literature regarding the determination of the drainage volume by type curve matching appear to be based on unrealistic expectations. The flowing pressures were obtained by a Crank-Nicolson Galerkin procedure. Analytical expressions to evaluate the integrals of the basis functions used in this study are given.

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Unconventional gas recovery program. Semi-annual report for the period ending March 31, 1979

This document is the second semi-annual report describing the technical progress of the US DOE projects directed at gas recovery from unconventional sources. Currently the program includes: Methane Recovery from Coalbeds Project, Eastern Gas Shales Project, Western Gas Sand Project, and Geopressured Aquifers Project. This report is divided into five parts: a summary (Section 1), and a section devoted to each resource (Sections 2 through 5). Each resource section presents information which serves as an introduction to that project.

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Improvement of CO2 Flood Performance

In Task Area 1, an oscillating quartz viscometer was developed to measure viscosities of CO/sub 2//hydrocarbon systems over a range of conditions. Viscosity dependency on density, composition, and temperature is examined and the functional form of a modified Lohrenz, Bray, and Clark correlation for CO/sub 2/-oil systems is presented. Also, the effect of free gas on displacement efficiency and that of multiple hydrocarbon phase flow on sweep efficiency are being investigated. With two-dimensional glass micromodels at reservoir conditions, we studied the effects of different scales of microscopic heterogeneity on flow behavior and blocking mechanisms using both in-situ foaming and pregenerated foam. Additionally, the initial formulation of a two-dimensional simulator which models high-pressure gas-foam flow is presented. A simulation of the processes of high-permeability zone blockage with foam, fluid diversion, and increased trapped oil recovery is included. Also, an NMR imaging study on fluid flow through porous media addressing the nonlinear stability analysis of miscible displacements and matrix-fracture fluid transport functions has been initiated. In Task Area 2, work commenced on the non-uniformity of flow which results from rock heterogeneity. Emphasis was placed on the effect of this non-uniformity on displacement efficiency. Measurements were made of the steady-state mobility of foam-like dispersions of dense CO/sub 2/ in surfactant solutions. 114 refs., 138 figs., 21 tabs.

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Design criteria for a control valve for slurry letdown service

These design requirements are applicable to valves suitable for use in controlling a coal/ash-solvent slurry under pressure letdown conditions in a coal liquefaction process. The valves are in the main flow downstream of the reactor vessel. The slurry also contains dissolved gases, including hydrogen, hydrogen sulfide and hydrocarbons. This valve must operate on a coal/ash-solvent slurry at 500 to 850/sup 0/F and with letdown pressures from 2000 to 4000 psig to atmospheric. The design and construction of the valves shall comply with commercial standards as defined in ANSI B16.34-1977. It should be noted that the valves will be used in piping systems that conform to the ASME Boiler and Pressure Vessel Code and the ANSI Code for Pressure Piping. Therefore, the valves are also subject to any limitations of those codes. In case of a conflict between requirements in these codes, the more stringent (i.e., more conservative) requirement shall apply. The valves shall be designed to be remote operating-type valves.

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