Methylbiphenyl, ethylbiphenyl and dimethylbiphenyl isomer distributions in some sediments and crude oils

Cumbers, K.M.; Alexander, Robert; Robert, I Kagi

doi:10.1016/0016-7037(87)90121-9

Cited by 49 publications

(17 citation statements)

References 18 publications

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“…The hydropyrolysate products of the asphaltenes (Fig. 5), afford the major aromatic hydrocarbons commonly used in assessing the biological origin and thermal maturity of geological materials [45][46][47][48][49]. The distributions of these compounds in a representative sample are shown in Fig.…”

Section: Steranesmentioning

confidence: 99%

Geochemical characterisation of heavily biodegraded tar sand bitumens by catalytic hydropyrolysis

Sonibare

Snape

Meredith

et al. 2009

Journal of Analytical and Applied Pyrolysis

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Section: Steranesmentioning

confidence: 99%

Geochemical characterisation of heavily biodegraded tar sand bitumens by catalytic hydropyrolysis

Sonibare

Snape

Meredith

et al. 2009

Journal of Analytical and Applied Pyrolysis

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“…Thermal maturity-dependent ratios based on aromatic hydrocarbon compound ratios predominantly indicate maturities for the Oklo FI oil in the late stage of the oil generation window (calculated R o reflectances of 1.1%-1.3% [28] ). This is based on published calibrations [42][43][44][45] , and on comparison of ratios with the maturity sequence in the Velkerri Formation (Mesoproterozoic) [46] . The aromatic ratios for the Elliot Lake FI oil indicate more variable, early to peak oil window maturities, based on the published calibrations.…”

Section: Resultsmentioning

confidence: 99%

Oil-bearing fluid inclusions from the Palaeoproterozoic: A review of biogeochemical results from time-capsules >2.0 Ga old

George

Dutkiewicz

Volk

et al. 2009

Sci. China Ser. D-Earth Sci.

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The observation of oil inclusions trapped prior to 2.0 Ga in Palaeoproterozoic rocks and the ability to obtain detailed molecular geochemical information from them provide a robust way for understanding the early biogeochemical evolution of the Earth. Oil-bearing fluid inclusions (FI) in ca. 2.45 Ga fluvial metaconglomerate of the Matinenda Formation at Elliot Lake, Canada were trapped in quartz and feldspar during diagenesis and early metamorphism of the host rock, probably before ca. 2.2 Ga. The 2.1 Ga FA Formation sandstone of the Franceville Basin in Gabon that hosts the Oklo natural fission reactors has also been discovered to contain abundant Palaeoproterozoic oil-bearing FIs. This oil occurs within H 2 O and CO 2 -dominated inclusions trapped in syntaxial quartz overgrowths and intragranular and transgranular microfractures in detrital quartz, and was most likely trapped 2.1-1.98 Ga. Molecular geochemical analyses of both FI oils reveal a wide range of compounds, including n-alkanes, isoprenoids, monomethylalkanes, aromatic hydrocarbons, and trace amounts of complex multi-ring biomarkers including terpanes, hopanes, methylhopanes, steranes and diasteranes. To ensure a reliable interpretation of oil inclusions, a comprehensive series of outside-rinse blanks and procedural system blanks was analysed by gas chromatography-mass spectrometry; quantitative amounts of the hydrocarbons in these blanks were compared to the FI extracts, so as to provide confidence limits on the experimental integrity of each compound class. Maturity ratios based on reliably detected compound classes show that the FI oils were generated in the oil window, with no evidence of extensive thermal cracking. The presence of biomarkers for cyanobacteria and eukaryotes derived from and trapped in rocks deposited prior to 2.0 Ga is consistent with early evolution of oxygenic photosynthesis and suggests that some aquatic settings had become sufficiently oxygenated for sterol biosynthesis by this time. The extraction of biomarker molecules from Palaeoproterozoic oil-bearing FIs thus establishes a new method, using low detection limits and system blank levels, to trace evolution through Earth's early history that avoids the potential contamination problems affecting shale-hosted hydrocarbons. Palaeoproterozoic, fluid inclusion, oil, biomarker, blank Early Precambrian sequences containing suitable material for biomolecular studies are relatively rare due to poor preservation of sedimentary rocks over such long periods of time. Metamorphism greatly limits the number of old rocks suitable for study, so the record of biomarker evolution very early in time is distinctly incomplete [1][2][3] and to date only trace amounts of biomarkers

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“…Biphenyls are often detected in coal extracts (Mair and Mayer, 1964;Yew and Mair, 1966;White and Lee, 1980), suggesting that the crude oils and condensates in the Surma basin may have originated from organic matter derived from coal or coaly shale. However, Cumbers et al (1987) identified alkylbiphenyls in extracts from Middle Cambrian 1874 -1886 m, 1901-1908 m) and Sylhet #7 (2020 -2033 m). Identification of important peaks: 1, methylcyclohexane; 2, toluene; 3, ethylbenzene; 4, meta + para-xylene; 5, ortho-xylene; 6 + 7, trimethylbenzene; 8, naphthalene; 9, 2-methylnaphthalene; 10, 1-methylnaphthalene; 11, biphenyl; 12, pristane; 13, phytane; 15, phenanthrene. sedimentary rocks, demonstrating that biphenyls are not exclusively derived from higher plants.…”

Section: Source Rock Organic Mattermentioning

confidence: 95%

In‐reservoir Fractionation and the Accumulation of Oil and Condensates in the Surma Basin, Ne Bangladesh

Hossain

Suzuki

Matsumoto

et al. 2014

Journal of Petroleum Geology

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Petroleum in the Surma basin, NE Bangladesh (part of the Bengal Basin) ranges from waxy crude oils to condensates. The origin and source rocks of these hydrocarbons were investigated based on the distributions of saturated and aromatic hydrocarbons in 20 oil samples from seven oil-and gas fields. The relative compositions of pristane, phytane and adjacent n-alkanes suggest that the source rock was deposited in a nonmarine setting. The abundance and similar distribution of biphenyls, cadalene and bicadinanes in most of the crude oils and condensates indicates a significant supply of higher-plant derived organic matter to the source rocks. Maturity levels of the crude oils and condensates from the Surma basin correspond to calculated vitrinite reflectance (Rc) values of 1.0-1.3%, indicating hydrocarbon expulsion from the source rock at a comparatively high maturity level. The Rc values of oils from the Titas field in the southern margin of the Surma basin are relatively low (0.8-1.0%).Some oils were severely biodegraded. The similar distribution of diamondoid hydrocarbons in both biodegraded and non-biodegraded oils indicated similar types of source rocks and similar maturity levels to those of oils from the Surma basin. The Oligocene Jenam Shale and/or underlying non-marine deposits located at greater depths may be potential source rocks. The diversity of the petroleum in the Surma 2 basin was likely due to evaporative fractionation, resulting in residual waxy oils and lighter condensates which subsequently underwent tertiary migration and reaccumulation. Evaporative fractionation due to modification of the reservoir structure occurred during and after the Pliocene, when large-scale tectonic deformation occurred in and around the Bengal Basin.

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Methylbiphenyl, ethylbiphenyl and dimethylbiphenyl isomer distributions in some sediments and crude oils

Cited by 49 publications

References 18 publications

Geochemical characterisation of heavily biodegraded tar sand bitumens by catalytic hydropyrolysis

Geochemical characterisation of heavily biodegraded tar sand bitumens by catalytic hydropyrolysis

Oil-bearing fluid inclusions from the Palaeoproterozoic: A review of biogeochemical results from time-capsules >2.0 Ga old

In‐reservoir Fractionation and the Accumulation of Oil and Condensates in the Surma Basin, Ne Bangladesh

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