Geochemical comparison of fluid inclusion and present-day oil accumulations in the Papuan Foreland – evidence for previously unrecognised petroleum source rocks

Volk, Herbert; George, Simon C.; Middleton, Heather; Schofield, Shane

doi:10.1016/j.orggeochem.2004.07.018

Cited by 132 publications

(43 citation statements)

References 44 publications

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“…Aquino Neto et al (1983) systematically investigated the distributions of tricyclic terpanes in oils and source rocks formed in a variety of depositional environments and showed that the C 23 member is often the dominant homologue in crude oils of a marine source while the C 19 and C 20 members are more abundant in terrestrial oils (Peters and Moldowan, 1993). High C 19 /C 23 TT and C 20 /C 23 TT ratios indicate important contribution from terrigenous organic matter (Hanson et al, 2000;Preston and Edwards, 2000;Volk et al, 2005). Specific parameters include C 23 /C 21 (Ekweozor and Strausz, 1983), C 23 /C 24 (Cassani et al, 1988) and (C 20 þC 21 )/ (C 23 þC 24 ) (Shi et al, 1988).…”

Section: Distribution Of Tricyclic and Tetracyclic Terpanes In Crude mentioning

confidence: 99%

Geochemical application of tricyclic and tetracyclic terpanes biomarkers in crude oils of NW China

Tao

Wang

et al. 2015

Marine and Petroleum Geology

143

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a b s t r a c tComposition and distribution of tricyclic terpanes, tetracyclic terpanes and hopane in crude oils from Tarim, Turpan, Ordos and Qaidam basins, NW China, were investigated, and some new source dependent parameters were developed and evaluated. C 19 and C 20 tricyclic terpanes are more abundant in terrigenous oils, with C 24 tetracyclic terpane dominant. Relatively higher carbon number tricyclic terpanes, especially C 23 tricyclic terpane, are often the dominant homologues in crude oils from saline lacustrine and marine sources. On the whole, the relative content of C 23 tricyclic terpane of crude oils follow the order of saline lacustrine oils > marine oils > freshwater lacustrine oils > terrigenous oils for C 19e23 tricyclic terpane. Some new parameters based on the tricyclic/hopane and tetracyclic/tricyclic terpane as well as tetracyclic/hopane ratios, could be used to distinguish the oils and source rocks with similar maturity deposited in different sedimentary environments.

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Section: Distribution Of Tricyclic and Tetracyclic Terpanes In Crude mentioning

confidence: 99%

Geochemical application of tricyclic and tetracyclic terpanes biomarkers in crude oils of NW China

Tao

Wang

et al. 2015

Marine and Petroleum Geology

143

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“…The C 19 -C 20 tricyclic terpanes are believed to originate mainly from diterpenoids (Peters et al, 2005), which are produced by vascular plants. The C 19 / (C 19 + C 23 ) or C 19 /C 23 tricyclic terpane is usually considered as a useful indicator of terrigenous organic matter input (e.g., Preston and Edwards, 2000;Volk et al, 2005). Changes in the carbon number distributions of the tricyclic terpanes could also be caused by thermal maturity (Farrimond et al, 1999).…”

Section: Tricyclic Terpanes and Tetracyclic Terpanesmentioning

confidence: 99%

Origin and occurrence of crude oils in the Zhu1 sub-basin, Pearl River Mouth Basin, China

Hao

Zhu

et al. 2015

Journal of Asian Earth Sciences

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“…The C 19-20 tricyclic terpanes originate mainly from diterpenoids (Peters et al, 2005). Therefore, ratios of high C 19+20 tricylic terpanes/tricylic terpanes (C 19+20 TT/∑TT) commonly indicate important contributions from terrigenous organic matter (Volk et al, 2005;Hanson et al, 2000). In this study, C 24 tetracylic terpane/(C 24 tetracylic terpane+C 26 tetracylic terpane) ratios increase as pristane/phytane (Pr/Ph) and C 19+20 tricaylic terpanes/tricylic terpanes ratios increase (Figs.…”

Section: Origin Of Crude Oilmentioning

confidence: 99%

Key elements controlling oil accumulation within the tight sandstones

Zeng

Liu

2015

J. Earth Sci.

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Tight oil sandstone reservoirs with low porosity and permeability, which are an unconventional petroleum resource, have been discovered in the Jurassic intervals of the central Junggar Basin, the northwestern China. To reveal the accumulation mechanism, a relatively comprehensive research was conducted, including oil-source correlation, porosity evolution, and hydrocarbon charging history. The results show that crude oil of these tight sandstone reservoirs were mainly from Permian source rocks with some contribution from Jurassic source rocks. The reservoirs were buried at shallow depth (<3 100 m) and exposed to weak diagenesis, and thus had high porosity (18.5%) when the Permian-sourced oil from Permian source rock was charging, indicating high GOI values (>5%). In contrast, the sandstone reservoir had already become tight and did not provide available space to accumulate oil due to severe compaction and cementation when hydrocarbon from Jurassic source rock filled, evidenced by low GOI values (<5%). Therefore, reservoir porosity controls the oil accumulation within tight sandstone. Whether tight sandstone reservoirs accumulate oil depends on the reservoir quality when hydrocarbons charge. Before the exploration of tight oil sandstone reservoirs, it should be required to investigate the relationship between oil charging history and porosity evolution to reduce the exploration risk and figure out the available targets.

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Geochemical comparison of fluid inclusion and present-day oil accumulations in the Papuan Foreland – evidence for previously unrecognised petroleum source rocks

Cited by 132 publications

References 44 publications

Geochemical application of tricyclic and tetracyclic terpanes biomarkers in crude oils of NW China

Geochemical application of tricyclic and tetracyclic terpanes biomarkers in crude oils of NW China

Origin and occurrence of crude oils in the Zhu1 sub-basin, Pearl River Mouth Basin, China

Key elements controlling oil accumulation within the tight sandstones

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