AMSO’s Novel Approach to In-Situ Oil Shale Recovery

Burnham, Alan K.; Day, Roger L.; Hardy, Michael; Wallman, P.H.

doi:10.1021/bk-2010-1032.ch008

Cited by 18 publications

(18 citation statements)

References 6 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…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

View full text Add to dashboard Cite

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.

show abstract

Section: Resultsmentioning

confidence: 99%

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

Marshall

Jackson

et al. 2018

Energy Fuels

View full text Add to dashboard Cite

show abstract

“…For example, the Petrosix process uses a moving bed similar to that found in moving bed gasifiers; the Tosco II process uses a rotary kiln similar to that found in cement production. ,, In situ subsurface production by definition operate on the principle of a semibatch process, keeping the oil shale stationary and continuously removing the produced oil and gas. The technologies differ mostly in terms of the way in which heating is supplied and subsurface permeability is created. ,,, …”

Section: Discussionmentioning

confidence: 99%

“…The technologies differ mostly in terms of the way in which heating is supplied and subsurface permeability is created. 10,41,43,44 Considering the differences in potential application, the implication of this work will be analyzed by looking at how the kinetics describes the rate of oil and gas production by pyrolysis as a function of time. Although the rate equation is first-order with respect to kerogen, in practice the pyrolysis rate is not a simple first-order relationship with respect to time, due to the conversion dependence of the rate constant.…”

Section: Energy and Fuelsmentioning

confidence: 99%

Oil Shale Pyrolysis: Conversion Dependence of Kinetic Parameters

2017

View full text Add to dashboard Cite

Oil can be recovered from kerogen in oil shale by pyrolysis. The devolatilization kinetics of the pyrolysis of oil shale from the Irati Formation in Brazil was studied. Kinetic parameters were determined from dynamic thermogravimetric analysis over the temperature range 323–1173 K, using different model-free methods. Evaluation and validation were performed by pyrolysis at 673 K for 3 hours. It was found that the activation energy depended on the extent of conversion. Activation energy increased over the range 215–255 kJ/mol for conversion in the range 0.15 ≤ α ≤ 0.55, where α = 1 for pyrolysis at 1173 K. When the reaction rate was high, the conversion calculated using kinetic parameters derived by the Friedman method was more accurate than those calculated from the Flynn–Wall–Ozawa and the Kissinger–Akahira–Sunose methods. The latter two methods performed better when the reaction rate was lower, i.e., at higher conversion. Isothermal kerogen pyrolysis approached an incomplete conversion limit that could be increased only by increasing the temperature; this type of behavior was predicted by the conversion dependence of activation energy. The observed activation energy is an average of the different activation energies of the individual compounds in kerogen. As conversion progresses, the compounds with lower activation energies are more readily converted, so that the average activation energy of the compounds that remain increases with increasing conversion. The work highlighted the importance of employing conversion-dependent kinetic parameters when modeling oil shale pyrolysis for process design, especially when the process is designed for high kerogen conversion.

show abstract

“…In this study, 15 samples of kerogen-bearing oil shale samples from Bazhenov Formation wells A, B, and C were used for subcritical water injection experiments. Namely, the samples were from the depth of 2327-2328 m (Well C; samples BF 2, 6), 2462-2476 m (Well A; samples BF 1,3,4,10,11,15), 2485-2491 m (Well A; sample BF 5,14), 2983-2990 m (Well B; samples BF 7,8,9,12,13). The samples were not crushed to maintain reservoir-close conditions-the average size of rock chips varied from 2 cm to 5 cm.…”

Section: Samplesmentioning

confidence: 99%

Cyclic Subcritical Water Injection into Bazhenov Oil Shale: Geochemical and Petrophysical Properties Evolution Due to Hydrothermal Exposure

et al. 2021

View full text Add to dashboard Cite

In situ shale or kerogen oil production is a promising approach to developing vast oil shale resources and increasing world energy demand. In this study, cyclic subcritical water injection in oil shale was investigated in laboratory conditions as a method for in situ oil shale retorting. Fifteen non-extracted oil shale samples from Bazhenov Formation in Russia (98 °C and 23.5 MPa reservoir conditions) were hydrothermally treated at 350 °C and in a 25 MPa semi-open system during 50 h in the cyclic regime. The influence of the artificial maturation on geochemical parameters, elastic and microstructural properties was studied. Rock-Eval pyrolysis of non-extracted and extracted oil shale samples before and after hydrothermal exposure and SARA analysis were employed to analyze bitumen and kerogen transformation to mobile hydrocarbons and immobile char. X-ray computed microtomography (XMT) was performed to characterize the microstructural properties of pore space. The results demonstrated significant porosity, specific pore surface area increase, and the appearance of microfractures in organic-rich layers. Acoustic measurements were carried out to estimate the alteration of elastic properties due to hydrothermal treatment. Both Young’s modulus and Poisson’s ratio decreased due to kerogen transformation to heavy oil and bitumen, which remain trapped before further oil and gas generation, and expulsion occurs. Ultimately, a developed kinetic model was applied to match kerogen and bitumen transformation with liquid and gas hydrocarbons production. The nonlinear least-squares optimization problem was solved during the integration of the system of differential equations to match produced hydrocarbons with pyrolysis derived kerogen and bitumen decomposition.

show abstract

AMSO’s Novel Approach to In-Situ Oil Shale Recovery

Cited by 18 publications

References 6 publications

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

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

Oil Shale Pyrolysis: Conversion Dependence of Kinetic Parameters

Cyclic Subcritical Water Injection into Bazhenov Oil Shale: Geochemical and Petrophysical Properties Evolution Due to Hydrothermal Exposure

Contact Info

Product

Resources

About