A comparison of pyrolysis products with models for natural gas generation

Andresen, Bjørg; Throndsen, Torbjørn; Råheim, A.; Bolstad, Johanne

doi:10.1016/0009-2541(95)00122-0

Cited by 53 publications

(38 citation statements)

References 15 publications

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“…2a and b). The amounts of extracted bitumens generated by Type II kerogen of the Kimmeridge Formation were reported to decrease at the Ro of 0.8% under hydrous pyrolysis (Andresen et al, 1995), while those generated by the type II kerogen in this work started to decrease at the EasyRo value of 0.9%. The oil generation of type II Toarcian kerogen peaked at the EasyRo value of 1.2% (Dieckmann et al, 1998), and the extracted oil included not only the C 15+ fraction but also the C 6-14 fraction.…”

Section: Liquid Hydrocarbonsmentioning

confidence: 42%

“…The high oil expulsion efficiencies for type I and type II kerogen in the oil window were also validated by geological section studies in the Ordos Basin (Zhang et al, 2006) and Bohai Bay Basin (Pang et al, 2005). Meanwhile, the transformation ratio of oil from type I and II kerogen may reach 60% or more, as evidenced by many laboratory and field observations (Andresen et al, 1995;Pepper and Corvi, 1995;Behar et al, 1997;Lewan, 1997;Xiong et al, 2002;Pan et al, 2010;Lewan and Roy, 2011;Wei et al, 2012). The high transformation ratio, in conjunction with high expulsion efficiency, allows substantial kerogen mass loss during the oil expulsion.…”

Section: Introductionmentioning

confidence: 70%

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The effect of oil expulsion or retention on further thermal degradation of kerogen at the high maturity stage: A pyrolysis study of type II kerogen from Pingliang shale, China

Jia

Wang

Liu

et al. 2014

Organic Geochemistry

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Section: Liquid Hydrocarbonsmentioning

confidence: 42%

Section: Introductionmentioning

confidence: 70%

The effect of oil expulsion or retention on further thermal degradation of kerogen at the high maturity stage: A pyrolysis study of type II kerogen from Pingliang shale, China

Jia

Wang

Liu

et al. 2014

Organic Geochemistry

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“…The 3 13 C results in Table 3 underscore the well-known isotopic disproportionation of sedimentary organic carbon during thermal maturation into 13 C-depleted low-molecular hydrocarbon compounds and relatively 13 C-enriched remaining kerogen, as documented from anhydrous pyrolysis (Sackett, 1978;Peters et al, 1981;Arneth and Matzigkeit, 1986; reviewed by Whiticar, 1996), hydrous pyrolysis (Andresen et al, 1995;E li l 1995) pyrolysis of a Green River Fm. shale sample similar to the one used in this study (Collister et al, 1992).…”

Section: Methodsmentioning

confidence: 64%

“…Hydrous pyrolysis has become a successful laboratory method to simulate thermal maturation of source rocks in a pressure reactor (Lewan, 1993(Lewan, , 1997(Lewan, , 1998Andresen et al, 1995;Michels et al, 1995). Under appropriate conditions, source rock chips that are submerged under water expel an oil phase that collects on the water surface and shows surprising similarity to natural petroleum (Lewan, 1997).…”

Section: Introductionmentioning

confidence: 99%

Experimental controls on D/H and 13 C/ 12 C ratios of kerogen, bitumen and oil during hydrous pyrolysis

Schimmelmann

Boudou

Lewan

et al. 2001

Organic Geochemistry

129

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Large isotopic transfers between water-derived hydrogen and organic hydrogen occurred during hydrous pyrolysis experiments of immature source rocks, in spite of only small changes in organic 13 C/ 12 C. Experiments at 330'C over 72 h using chips or powder containing kerogen types I and III identify the rock/water ratio as a main factor affecting ASD for water and organic hydrogen. Our data suggest that larger rock permeability and smaller rock grain size increase the H-isotopic transfer between water-derived hydrogen and thermally maturing organic matter. Increasing hydrostatic pressure may have a similar effect, but the evidence remains inconclusive.

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“…38,39 Stable carbon isotopic curves of the different gas components change to differing extents with increasing pressure. For methane, the isotope ratio at 350 °C shows little variation (-46.3 to -45.4‰) over the pressure range of 200 to 900 bar.…”

Section: Stable Carbon Isotopic Compositions Of Individual Gas Componentmentioning

confidence: 99%

Thermal Cracking of Oil under Water Pressure up to 900 bar at High Thermal Maturities. 1. Gas Compositions and Carbon Isotopes

et al. 2016

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In this study, a C 9 + fraction of saturate-rich Tertiary source rock-derived oil from the South China Sea basin was pyrolyzed in normal and supercritical water using a 25 mL vessel at a range of temperature from 350 to 425 °C for 24 h, to probe pressure effects up to 900 bar on gas yields and their stable carbon isotopic compositions during thermal cracking. Pressure generally retards oil cracking, as evidenced by reduced gas yields, but the trends depend upon the level of thermal evolution. In the early stages of cracking (350 and 373 °C, equivalent vitrinite reflectance of < ∼1.1% R 0 ), the suppression effect increases with pressure from 200 to 900 bar, but it is most marked between 200 and 470 bar. At the later stages in the wet gas window (390, 405, and 425 °C, equivalent vitrinite reflectance of >1.3% R 0 ), pressure still has a strong suppression effect from 200 to 470 bar, which then levels off or is reversed as the pressure is increased further to 750 and 900 bar. Interestingly, the stable carbon isotopic composition of the generated methane becomes enriched in 13 C as the pressure increases from 200 to 900 bar. A maximum fractionation effect of ∼3‰ is observed over this pressure range. Due to pressure retardation, the isotopically heaviest methane signature does not coincide with the maximum gas yield, contrary to what might be expected. In contrast, pressure has little effect on ethane, propane, and butane carbon isotope ratios, which show a maximum variation of ∼1‰. The results suggest that the rates of methane-forming reactions affected by pressure control methane carbon isotope fractionation. Based on distinctive carbon isotope patterns of methane and wet gases from pressurized oil cracking, a conceptual model using "natural gas plot" is constructed to identify pressure effect on in situ oil cracking providing other factors excluded. The transition in going from dry conditions to normal and supercritical water does not have a significant effect on oil-cracking reactions as evidenced by gold bag hydrous and anhydrous pyrolysis results at the same temperatures as used in the pressure vessel.

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A comparison of pyrolysis products with models for natural gas generation

Cited by 53 publications

References 15 publications

The effect of oil expulsion or retention on further thermal degradation of kerogen at the high maturity stage: A pyrolysis study of type II kerogen from Pingliang shale, China

The effect of oil expulsion or retention on further thermal degradation of kerogen at the high maturity stage: A pyrolysis study of type II kerogen from Pingliang shale, China

Experimental controls on D/H and 13 C/ 12 C ratios of kerogen, bitumen and oil during hydrous pyrolysis

Thermal Cracking of Oil under Water Pressure up to 900 bar at High Thermal Maturities. 1. Gas Compositions and Carbon Isotopes

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