AndreaBozzo/ceres-open-data-index huggingface dataset:
Formation of calcium and magnesium molybdate complexes in dilute aqueous solutions and evaluation of powellite solubility in spent oil shale

"In order to increase our understanding of the chemistry of molybdenum (Mo) in spent oil shale disposal environments, predict fate and behavior, and assess the  effectiveness of proposed mitigation techniques, we feel that it is imperative to understand the processes controlling Mo aqueous and solid-phase distribution.  Recent research supports the significance of alkaline earth and alkali metal ion pairs with molybdate in aqueous solutions. However, ion association constants for  the formation of these species have not been rigorously determined. The objectives of this study were to measure the ion association constants (log Q) for the  formation of calcium and magnesium molybdate ion pairs by potentiometric titration lit pH 7 and 25RC in NaN03 ionic media. The measured values were then used to examine the equilibrium solubility of powellite (CaMo04) in KN03 solutions and spent oil shale systems. The mean log Q and DGR/V values for the formation ofCaMo02 are 2.58 and -1411.55 kJ mor1, respectively. The mean log  Q and DGR/V values for the formation of MgMo02 are 3.04 and -1315.38 kJ mor 1, respectively. Powellite solubility data were e evaluated using log Q for CaMo02  formation, resulting in a calculated log Ksp for powellite dissolution of -7.84. Close examination of the powellite solubility data suggests that the formation of Ca(Mo04)2/2may also influence molybdate aqueous chemistry. A log Q of 4.77 was approximated by an iterative estimation technique for the formation of  Ca(Mo04)2/2. Inclusion of this value in model analysis resulted in a calculated log Rsp for powellite dissolution of -7.86 and a DGR/V of -1441.78 ; 1.22 kJ mor1. A log  Q of 1.22 for the formation of NaMo04 was  approximated from powellite-spiked spent oil shale solubility data. Application of an ion associated model that used the molybdate ion pair formation data shows that spent oil shale leachetes are undersaturated with respect to powellite. The results of this study show that molybdate ion pair formation in spent oil shale solutions may be significant and that soluble Mo concentrations may not be supported by powellite dissolution."

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Modeling of vertical pressure distribution in large in situ retorts

"Deformation of oil-shale rubble and its consequent permeability loss depends upon consequent permeability loss depends upon rock pressure. This pressure distribution in oil-shale rubble columns is therefore  important to modified in -situ oil extraction from oil shale. Pressure distribution in unretorted columns of oil-shale rubble has been modeled using the theory of bins.  Dependence of vertical pressure on column geometry  and shale properties was examined. A major finding is that , at room temperature for a given geometry and properties, pressure approaches an asymptotic limit regardless of overburden forces. The model has been extended to include variations in density and frictional properties of shale that accompany the temperature  changes occurring during retorting, and this expanded model has been programmed for the CDC 7600 computer. Parametric studies with this program point up the urgent need for data on the dependence of interparticle frictional properties on temperature and pressure.* Directions of further development and  improvement of this modeling effort are discussed."

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Water pollution potential of spent oil shale residues from above-ground retorting. [Physical properties. Percolation experiments]

"Oil shale resources in the United States cover more than 11 million acres of Colorado, Utah. and Wyoming. and the known petroleum reserve from this source is more than sixty times the proven reserve of crude oil in the United States. If present trends for needs in petroleum in the United States continue, the use of shale oil to supplement crude oil resources becomes likely as a major future development. In the event the industrial development of oil shale becomes economically feasible, a considerable quantity of retorted shale residue will require disposal. The disposition of spent shale in a way to prevent water pollution will become a problem for industry. Because a good oil shale yields only 25 to 30 gallons of oil per ton of  rock, from 85 to 90% of the weight of the original rock appears as spent shale. Some of the precipitation falling on exposed spent oil shale residue piles will run off and  will contain dissolved material leached from these piles. Depending on both the concentration and composition of this runoff water, surface streams and possibly some  ground waters may be polluted to some extent. The purpose of this project was to determine the water pollution potential of these exposed oil shale residue piles."

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Pyrolysis of crude shale oil. [Yields at 1400, 1470, and 1550/sup 0/F]

The prospect of inadequate future supply of natural gas, natural gas liquids, and petroleum oils has stimulated considerable interest in the utilization of the large reserve of high grade Green River formation oil shale.  Although much information on the production and refining of crude shale oils has been published, little is known of the value of crude shale oils as a source of fuel gas, low-molecular weight olefins, aromatics and pitch.  A 2 1/2 inch inside diameter tubular flow reactor was employed to study the pyrolysis of crude Green River shale oils at atmospheric pressure, using steam for atomization of the feedstock and for control of the partial pressure of the product gas in the 0.2 to 0.8 atmosphere range.  At pyrolysis temperatures from 1400 to 1550 F and reaction times from one to 4 1/2 seconds approximately 50 percent of gaseous products were formed. Carbon formation varied from one to eleven weight percent, with the remaining nongaseous products consisting primarily of liquid aromatics and pitch.  It is demonstrated that the pyrolysis product yields of Green River shale oils are very similar to those obtained from petroleum oils of equal carbon-hydrogen weight ratio in spite of significant differences in composition.  Gaseous product distribution are shown to agree closely with the generalizations developed from natural gas liquid and petroleum oil pyrolysis data obtained over an equivalent range of reaction conditions.

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ANALYSIS OF THE ECONOMIC POTENTIAL OF UNDERGROUND COAL GASIFICATION

Underground Coal Gasification is the process by which coal is converted to combustible gas in situ. The process has been successfully demonstrated technically in this country and a commercial UCG industry has existed in the USSR for many years. A number of thorough and valid economic studies have shown that UCG has commercial potential in this country at prices of less than $6/10^6 Btu. This is better than demonstrated costs for similar products gases from surface coal gasification processes. Current low natural gas prices and questions as to possible environmental degradation are hampering commercial development.

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Composition of shale oil

"Shale oil, produced at Rifle, Colorado, by the Bureau of Mines through NTU retorting of oil shale, has been examined by a combination of the following techniques: distillation, extraction with a solution consisting of a metal chloride dissolved in concentrated hydrochloric acid,  silica-gel percolation, extraction with urea, and infrared spectrometry. Hydrocarbons constitute 39% of the shale oil, and compounds of nitrogen, sulfur, and oxygen account for the remaining 61%. The hydrocarbons  are 6% normal paraffin, 6% normal olefins, 5% isoparaffins plus naphthenes, 12% isoolefins plus cycloolefins, 4% monocyclic aromatics, and 6% polycyclic  aromatics. The non-hydrocarbons are 36% nitrogen compounds, 6% sulfur compounds, and 19% oxygen compounds. The composition data suggest that some hydrocarbons are formed during retorting of oil shale via the steps: kerogen--) nitrogen compounds--)isoparaffins plus naphthenes --)isoolefins plus cycloolefins --)aromatics."

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Results of the processing of a western oil shale on the Allis-Chalmers Roller Grate Retort system

"Allis-Chalmers has developed a patented oil shale retorting process based on a new and unique cross-flow heat exchanging device. A Process Development Unit (PDU) retort has been designed and built based on this new process and equipment. Over thirty tests have been conducted on this unit involving retorting, combustion and cooling of a Colorado oil shale. These tests were conducted over a wide range of variables,  including on-gas flowrate, on-gas temperature, particle size and  bed depth. Data obtained from the tests have been  used to design both a demonstration and commercial  size retorting system. Tests are conducted on the PDU with an initial charge weight of 500 to 1500 pounds. Data are taken throughout the test by an automatic data logging system. This data is analyzed and used to determine important design variables such as pressure drop, heat transfer rates, retorting and combustion rates  and level of side reactions such as calcinations and pyritic sulfur oxidation. The Allis-Chalmers Roller Grate Retorting  Process is discussed along with an examination of  the flowsheet. The PDU test apparatus and procedures are reviewed and typical test results are presented."

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BX In Situ Oil Shale Project. Quarterly technical progress report, June 1, 1978-August 31, 1978

During the quarter June 1, 1978 to August 31, 1978, work on the BX In Situ Oil Shale Project consisted of drilling Project wells; the running of additional pulse tests with consequent redesign of the well completion format; and the commencement of construction of surface facilities.

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Evaluation of a steamflood experiment in a Utah tar sand deposit

The first U.S. DOE Laramie Energy Technology Center (LETC) steam flood experiment in a Utah tar sand, LETC TS-IS, was conducted in the Northwest Asphalt Ridge deposit near Vernal, UT> Steam was injected into the center well of two concentric invented five-spot patterns. The zone chosen for the experiment was a sand stone 45 ft (14m) thick in the Rimrock member of the Mesa verde formation. The pattern area was 0.25 acres (1012 m2) and contained a 13 degree API (979 kg.m3) bitumen with a viscosity greater than 10^6 cp (10^3 Pa*s) at reservoir conditions. The average oil saturation was 78.9% PV. During 160 days of operation, 65,700 bbl (10.4 x 10^3 m3) of water-equivalent steam were injected at 360 to 530 psig (2.5 to 3.7 MPa) and 180 to 650 B/D (29 to 103 m^3/d). Total production during the test amounted to 1,150 bbl (183 m3) of oil and 6,250 bbl (994 m3) of water.

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Echoing in situ combustion oil recovery project in a Utah tar sand

The U.S. tar sand resource consists of an estimated 30 billion barrels (4.7Gm) of oil. Most of this resource is in six large deposits in Utah. Through research and development to prove tar sand oil recovery methods, the Department of Energy is attempting to stimulate commercialization of this resource. Two in situ combustion field experiments have been conducted in Utah’s Northwest Asphalt Ridge deposit. The second of these experiments, described here in detail, was completed in early 1978 and consisted of a reverse combustion preparatory phase followed by a forward combustion production phase. Oil recovery exceeding 25 percent of the oil-in-place from a 40 ft by 120 ft (12m by 26m) nine-well line drive pattern provides encouragement for larger scale technical and economic demonstrations.

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Tar-sand potential of selected areas in Carter and Murray Counties, South-Central Oklahoma

Tar sands and heavy-oil deposits have been known in Oklahoma since the late 1800’s, and these deposits, or certain aspects of particular deposits, have been described in a number of early publications (Eldridge, 1901; Taff, 1904; Hutchison, 1911; Snider, 1913, 1914; Tomlinson, 1928; Shelley, 1929; Wolfard, 1929; and Woodruff, 1934). Jordan (1964) used the H.P. Goodrich File (unpublished) to compile data on 298 occurrences of petroleum-impregnated outcrops and asphaltite deposits as well as several shallow (less than 500 feet) oil fields. The Goodrich data are on file at the Oklahoma Geological Survey and constitute a fairly comprehensive summary of surface and shallow occurrences of petroleum and petroleum-related material in the State.

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Reverse combustion instabilities in tar sands and coal

A linear stability analysis shows that reverse combustion in coal and tar sands is only conditionally stable for mobility ratios less than one. However, high air flow rates and gas generation at the combustion front can be stabilizing influences. For unstable operation, an estimate of the size of the reverse combustion channel may be obtained from the curve for the most highly amplified wavelength. This in turn provides a method for calculating air flux and combustion front velocity.

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Northwest asphalt ridge tar sand deposit well logging and coring comparison

Quantitative well logging techniques were performed on four LETC wells used to conduct a small scale tar sand steam flood and four additional wells used to provide reservoir data for the design of a fourth field experiment near Vernal, Utah. The purposes of this study were to: summarize and present the log derived information; determine how accurately the log data matched the core data; and estimate values for Rw in the Rimrock Sandstone Member.

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Geology and resources of the Tar Sand Triangle, southeastern Utah

The Tar Sand Triangle is located in southeastern Utah between the Dirty Devil and Colorado Rivers and covers an area of about 200 square miles. The geology of the area consists of gently northwest dipping strata exposed in the box canyons and slopes of the canyon lands morphology. Strata in the area range in age from Jurassic to Permian. The majority of tar sand saturation is found in the Permian White Rim Sandstone Member of the Cutler Formation. The White Rim Sandstone Member consists of clean, well-sorted sandstone which was deposited in a shallow marine environment. Resources were calculated from analytical data from the three core holes drilled by the Laramie Energy Technology Center and other available data. The total in-place resources, determined from this study, are 6.3 billion barrels. Previous estimates ranged from 2.9 to 16 million barrels. More coring and analyses will be necessary before a more accurate determination of resources can be attempted.

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Field experiment of in-situ oil recovery from a Utah tar sand by reverse combustion

Part of the mission of the Energy Research and Development Administration (ERDA) is to develop all energy sources to meet the needs of present and future generations. Toward that mission the Laramie Energy Research Center (LERC) is conducting research and field experiments for the development of recovery methods applicable to important supplemental sources of oil and gas. These experiments involve: (1) in situ oil recovery from oil shale, (2) underground gasification of coal, and (3) in situ oil recovery from tar sands. This report is concerned with the latter on which research was begun about 4 years ago. The objectives of this research are two told:  To determine the physical characteristics of known tar sand deposits and their probable effect on oil recovery, and to develop and field test in situ methods applicable to the recovery of oil from tar sands.

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Evaluation of the native hydraulic characteristics of the Felix Coal (Eocene, Wasatch Formation) and Associated Strata, Hoe Creek Site, Campbell County, Wyoming

The native hydraulic characteristics of the shallow (35- to 50-m-deep) Felix coal and adjacent strata have been estimated from the results of comprehensive field tests at the Campbell County, Wyoming, site of proposed in situ coal-gasification experiments. The field tests involved withdrawal of water from and water injection into wells completed in the Felix coal. Measurement of the effects of these hydraulic perturbations in terms of water-level fluctuations in wells completed in the coal and adjacent strata provided the data used in the analysis. At the proposed gasification site, the Felix coal consists of two seams. The estimates of hydraulic conductivity of the 3-m-thick Felix No. 1, the shallower of the two seams, range from about 0.3 to 1 m/day. The coefficient of storage of the Felix No. 1 is approximately 2 x 10/sup -2/. Test results indicate that the Felix No. 1 behaves as a very leaky aquifer.

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Characteristics and analyses of ninety-two Colorado crude oils. [Analysis of 92 crude oils from 73 fields; specific gravity, sulfur content, viscosity, API gravity, pour point, color, an d distillation]

This report presents analyses of 92 crude oils from 73 fields representing 90 percent of the production in 1955. Abridged analyses are listed for easy comparison, and complete analyses are given in the appendix. Oil samples were collected for study from many different sources. Although many of the newer fields were not sampled, their oils probably are very similar to those from corresponding formations that were studied and tabulated.

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Outlook for underground coal gasification

Past experiments have shown underground coal gasification (UCG) to be technically feasible but not economically competitive. During these tests, stabilization of gas production rates and of gas heating value were not achieved for sustained periods. The Bureau of Mines began UCG experiments at Hanna, Wyoming, in November 1972. On January 19, 1975, this work was transferred to the U. S. Energy Research and Development Administration. The problems of past tests have been avoided and encouraging results have been obtained. No gas leakage from the reaction zone has been observed. Gas production rate and gas heating value were relatively stable for a 5/sup 1///sub 2/-month period. During this period approximately 20 tons of moisture-free coal were gasified per day, energy balance calculations showed 3.5 times more energy produced than consumed, and comparison with an air-blown surface gasifier showed similar energy recovery efficiencies. A second experiment to further define process feasibility is underway. If results from this experiment are favorable, design and construction of a 15- to 30-MWe pilot plant will follow. Successful pilot plant operation would lead to design of a commercial demonstration plant by 1980.

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Activity of the production of energy from tar sands of the United States

Shown dramatically by the recent crisis involving petroleum and natural gas  shortages and rising prices foreshadows an end go unlimited consumption of natural resources at traditionally low prices.  Alleviating these growing shortages of fossil fuels will require increased production from traditional sources and development of new sources.  Thus the prime mission of the U.S. Energy Research and Development Administration (ERDA) is to insure a timely supply of fossil fuels at the lowest possible economic, occupational, environmental and social costs.  As part of this mission, ERDA is conducting research aimed at production on energy from several unconventional resources, including tar sands.

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200 Steamflood Demonstration Project. Fourth annual report, June 1979-June 1980

The "200" Sand Steamflood Demonstration Project, a jointly  funded venture between Santa Fe Energy Company - Chanslor Division (formerly Chanslor-Western Oil and Development Company) and the United States Department of Energy (DOE), is testing an enhanced steamflooding technique in the Midway-Sunset Field, Kern County , California (Figure I-1). The project was initiated in July, 1975, by Santa Fe Energy Company -Chanslor Division (SFE) and was followed by the DOE Cost-Sharing Contract which commenced on June 16, 1976, and will expire on June 30, 1983. A contract initiation the total cost of the work to be performed under the contract was estimated to be $8,247,266. Of this estimated amount, the Government will fund a maximum amount of $1 , 700,000 (21%). Actual cost will be approximately 2.5 times the original estimate , because of increased fuel  cost , delay in expanding project area which caused capital expenditure to rise, and the unpredictably high inflation rates. Likewise, the revenue stream has and will increase dramatically.

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'200''Sand Steamflood Demonstration Project. Eighth annual report, June 1983-June 1984

The "200" Sand Steamflood Demonstration Project, a jointly funded venture between Santa Fe Energy Company - Western Division (SFE) and the United States Department of Energy (DOE), is testing an enhanced  steamflooding technique in the Midway-Sunset Field. Kern County. California (Figures 1). The project was initiated in July, 1975. by Santa Fe Energy Company - Western Division SFE) and was followed by the DOE Cost - Sharing  Contract which commenced on June 16, 1976 and was scheduled to end in June, 1983. The contract has since been extended until June, 1985. Steamflooding generally has been conducted in Midway-Sunset Field reservoirs which have responded favorably to cyclic steam  stimulation in order to increase recovery and accelerate cyclic production. Numerous heavy oil pools in this field as well as other fields have not been adequately developed because of poor cyclic steam performance. The Demonstration Project was initiated in the "200" Sand Pool to demonstrate the operational, recovery, and economic aspects of steamflooding a typical heavy oil reservoir which has unfavorable response to cyclic stimulation.  This pool, designated the "200" Sand, contains  approximately 50 million barrels of oil-in-place in a structure that lies between 400 and 700 feet in depth. The reservoir produced very little primary oil production and responded poorly to cyclic steam stimulation.

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Chemical composition of Antrim shale in the Michigan basin

During the period between March 1977 and July 1980 core samples from 28 different wells at various locations in the Antrim shale deposit in the Michigan Basin were analyzed. The geochemical analysis revealed that the sulfur content of the shale varied proportionately with that of carbon. On the other hand, calcium values vary inversely with organic carbon. Iron values do no vary greatly within a core and show no tendency to follow organic carbon or sulfur. It seems that the relationships that exist between the chemical species are controlled by the geological events that resulted in the formation of the shale.

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Analyses of crude oils from 546 important oilfields in the United States. [Data compilation of physical and chemical properties]

The Bureau of Mines analyzed 626 crude oils from 546 oilfields in the United States that produced 2,500 BOPD or more during at least 1 of the last 3 years. Included also are crude oil analyses from eight fields that produced less but which were located in areas having few or no fields that produced 2,500 BOPD. The tables show the geographical and geological source, general  characteristics, and determined and computed analytical data for each sample. The analyses were made  according to the Bureau of Mines routine method and are directly comparable to other previously published analyses.

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Analytical methods for the analysis of acids in high-boiling petroleum distillates

The acids in ten high-boiling crude oil distillates were characterized. Four major acidic compound types were found in all of the distillates--carboxylic acids, phenols, carbazoles, and amides. Three methods were used for the quantitative determination of the major acidic compound types. One method involved the use of a separation scheme by which compound types were separated and the percentage of each compound type was determined gravimetrically. The second and third quantitative methods utilized infrared spectrometry. The relative amounts of compound types in the various distillates could be determined using any of the three methods. (auth)

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