A Comparison Between the Properties of Devonian Shale and Green River Oil Shale via Thermal Analysis

Wen, C. S.; Yen, Teh Fu

doi:10.1021/ba-1979-0183.ch020

Cited by 9 publications

(6 citation statements)

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“…It was also of interest to see if liquefaction yields could be predicted by a simple kinetic approach using a single rate-constant activation energy for the volatilization of organic matter (360–480 °C), rather than using the more-refined methods of Burnham. , Different authors have published a range of results for the rate-constant activation energy (93–272 kJ/mol). − The TGA curves for the powder sample gave rate-constant activation energies of 185 kJ/mol for 20% organic weight loss and 265 kJ/mol for 30–80% organic weight loss, calculated by the Friedman differential method, within the range found by other workers. Assuming first-order kinetics, the percent organic weight loss was found to increase from 26% (290 °C, 14 days) to 67% (330 °C, 14 days) or 61% (320 °C, 28 days).…”

Section: Resultsmentioning

confidence: 99%

Long-Time-Period, Low-Temperature Reactions of Green River Oil Shale

Marshall

Jackson

et al. 2018

Energy Fuels

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Reactions of water-washed chunks of a deeply buried Green River oil shale (2880–2920 ft, well below the water table) have been carried out in N2–H2O and CO–H2O for up to 28 days at temperatures in the range of 280–370 °C. Large variations in yields of liquid products were observed for reactions below 330–340 °C. These were attributed to varying mineralogy in the chunks because the variations disappeared for reactions of ground samples or reactions above 330–340 °C, at which point the chunks disintegrated. Liquid-product yields of up to 70 wt % dry mineral matter free could be obtained from the chunks at temperatures as low as 320 °C, provided that long reaction times of 14 or 28 days were used. In particular, at lower temperatures, yields were higher under N2 than under CO, but the quality of the CO–H2O petroleum or oil/gas products tended to be better than that of N2–H2O products. The liquid products contained 1–2 wt % nitrogen, were high in aliphatic material, and contained significant amounts of heavily substituted aromatic rings.

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Section: Resultsmentioning

confidence: 99%

Long-Time-Period, Low-Temperature Reactions of Green River Oil Shale

Marshall

Jackson

et al. 2018

Energy Fuels

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“…We have also observed it with four Paris Basin Toarcian kerogens and in three of four kerogens isolated from Kimmeridge clays. It has been observed in Green River kerogen by others who did not explore the phenomenon . Sporopollenin, kuckersite, and kerosene shale have been studied by differential thermal analysis (DTA) and all show low-temperature endotherms. , The sporopollenin endotherm extends from ∼50 °C to 150 °C.…”

Section: Resultsmentioning

confidence: 99%

Kerogen Chemistry 2. Low-Temperature Anhydride Formation in Kerogens

et al. 2004

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Bakken kerogens react rapidly when heated at temperatures of 40-180 °C to form carboxylic acid anhydrides and water from carboxylic acids. Differential scanning calorimetry (DSC) shows a pronounced irreversible endotherm over this temperature range, demonstrating the occurrence of an endothermic chemical reaction. The fact that this reaction is the formation of an acid anhydride was demonstrated using Fourier transform infrared (FTIR) spectroscopy. The amount of anhydride formed can be estimated by measuring the enthalpy of the process using DSC. Approximately 20% of the anhydride is hydrolyzed when the reacted kerogen has been allowed to stand in air at room temperature for three weeks, demonstrating that water has access predominantly to the kerogen surface during this time. Exposure of the kerogen to water vapor at 150 °C for 48 h results in complete anhydride hydrolysis. Swelling the kerogen with 95 vol% tetrahydrofuran (THF)-5 vol% water also results in only partial hydrolysis of the anhydride; however, exposure to 50% aqueous THF results in complete anhydride hydrolysis. The extent of anhydride formation decreases as maturation increases. Anhydride formation has been observed with 13 of 14 kerogens that have been studied and is widespread. It occurs when either the isolated kerogen or the source rock are heated. The carboxylic acid groups must be adjacent to each other to enable such a fast reaction to occur in a glassy solid where diffusion is strongly limited. This suggests the existence of molecular-level heterogeneity in kerogens.

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“…The published examination of oil shale thermal characteristics related to processing dates back some 80 years. , This work examined the reaction heats and heating requirements of whole Colorado oil shale and found that reaction heats and heating requirements were dependent on the oil shale composition. Colorado oil shale has also been the subject of much work on its thermal characteristics using differential scanning calorimetry and thermogravimetry. − Comparisons between pyrolysis heats of Colorado and Devonian oil shale have also been made . The pyrolysis heats for Colorado oil shale were found to be lower because of the differences in mineralogy between Colorado and Devonian oil shales, in particular, the influence of pyrite found in the Colorado shales.…”

Section: Introductionmentioning

confidence: 99%

“…Colorado oil shale has also been the subject of much work on its thermal characteristics using differential scanning calorimetry and thermogravimetry. [6][7][8][9][10] Comparisons between pyrolysis heats of Colorado and Devonian oil shale have also been made. 7 The pyrolysis heats for Colorado oil shale were found to be lower because of the differences in mineralogy between Colorado and Devonian oil shales, in particular, the influence of pyrite found in the Colorado shales.…”

Section: Introductionmentioning

confidence: 99%

“…[6][7][8][9][10] Comparisons between pyrolysis heats of Colorado and Devonian oil shale have also been made. 7 The pyrolysis heats for Colorado oil shale were found to be lower because of the differences in mineralogy between Colorado and Devonian oil shales, in particular, the influence of pyrite found in the Colorado shales. Other work has shown a correlation between total measured enthalpy and oil shale grade; that is, the higher the oil yield for the shale, the higher the total measured enthalpy.…”

Section: Introductionmentioning

confidence: 99%

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Predictive Heat Model for Australian Oil Shale Drying and Retorting

Berkovich

Levy

Young

2000

Ind. Eng. Chem. Res.

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The exploitation of Australia's oil shale reserves has been the subject of much research over several decades. The extraction of oil from shale is usually a thermal process and therefore oil shale processing is dominated by heat-transfer and thermal reactions. To fully develop any oil shale processing technology, knowledge of an oil shale's thermodynamic properties is desirable. This paper presents a novel approach for the determination of an oil shale's thermodynamic properties and subsequent development of a predictive heat model. This approach involves experimental determination of the thermodynamic properties of an oil shale's individual components, in particular, the unique kerogen and clay minerals in Australian oil shale. The experimental data was then used to develop a predictive heat model for Australian oil shale based upon its kerogen and mineral, composition, and concentrations. The predictive heat model allows investigation of heat capacity, enthalpy, and total enthalpy for Australian oil shale during the process temperatures of drying and retorting.

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A Comparison Between the Properties of Devonian Shale and Green River Oil Shale via Thermal Analysis

Cited by 9 publications

References 0 publications

Long-Time-Period, Low-Temperature Reactions of Green River Oil Shale

Long-Time-Period, Low-Temperature Reactions of Green River Oil Shale

Kerogen Chemistry 2. Low-Temperature Anhydride Formation in Kerogens

Predictive Heat Model for Australian Oil Shale Drying and Retorting

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