Geochemical characterization and depositional environment of source rocks of small fault basin in Erlian Basin, northern China

Ding, Xiujian; Liu, Guangdi; Zhang, Ming; Gao, Changhai; Huang, Zhilong; Qu, Jin; Lu, Xuejun; Wang, Pangen; Chen, Zhelong

doi:10.1016/j.marpetgeo.2015.11.006

Cited by 47 publications

(24 citation statements)

References 41 publications

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“…69 In the P 2 l lacustrine mixed source rocks, the C 26 /C 25 tricyclic terpane ratio ranges widely from 0.89 to 4.54 (average = 2.34), indicative of a mixed OM of algae, bacteria, and higher plants. 67,69,70 This was also suggested by the medium values of the C 24 /C 23 tricyclic terpane ratio (0.35−0.55) and low C 22 / C 21 tricyclic terpane values (0.10−0.21). 71 Proportional sterane abundances are another useful indicator of biological sources of OM.…”

Section: Resultsmentioning

confidence: 74%

“…OM maturity indicates the extent of thermal reactions that drive the conversion of sedimentary OM into petroleum. 70 The mean vitrinite reflectance (R o ) of P 2 l source rocks ranges from 0.52 to 1.87% with an average value of 0.84% and increases with depth. The T max values of P 2 l source rocks range from 423 to 443 °C (average = 433 °C), indicating that the mixed source rocks of the Lucaogou Formation have entered the thermally low mature to mature stage of the oil window.…”

Section: Resultsmentioning

confidence: 99%

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Geochemical Characteristics, Hydrocarbon Potential, and Depositional Environment Evolution of Fine-Grained Mixed Source Rocks in the Permian Lucaogou Formation, Jimusaer Sag, Junggar Basin

et al. 2020

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The Permian Lucaogou Formation (P2l) in the Jimusaer Sag, Junggar Basin is an essential source rock and a tight oil-producing layer in China. The source rock of the Lucaogou Formation is characterized by mixed sedimentation of siliciclastics, carbonates, and tuffaceous materials, and the formation of mixed source rocks is different from that of conventional source rocks (e.g., mudstones or carbonates). Our petrological observation and X-ray diffraction mineralogical analysis suggest that the mixed source rocks are divided into three types: terrigenous-dominated mixed rocks (Td-mixed rocks), carbonate-dominated mixed rocks (Cd-mixed rocks), and tuffaceous-dominated mixed rocks (Tuf-mixed rocks). Compared with the upper section, more Td- and Tuf-mixed rocks, as well as less Cd-mixed rocks, developed in the lower section. Integrated organic geochemical and molecular geochemical analyses indicate that the Lucaogou mixed source rock is abundant in organic matter (OM) (TOC = 3.12 wt %), which is at the thermally low mature to mature stage. The sources of OM mainly originate from the mixture of planktonic organisms, bacteria, and terrigenous higher plants. Comparatively, some geochemical parameters (e.g., TOC, S 1 + S 2, and hydrogen index) of the upper section of P2l show slightly higher values than those of the lower section both before and after extraction, indicating a higher hydrocarbon generation potential of the source rocks in the upper section. Besides, more finely disseminated bacterial and planktonic organics are present in the upper section, whereas the lower section is more enriched in terrestrial OM. The mixed source rocks of the lower section were deposited in a deeper, anoxic–dysoxic, and brackish environment, whereas those of the upper section were deposited in a shallow, suboxic, saline, and evaporative environment. Moreover, we found that the lacustrine basin evolved from a more balanced-filled scenario with moderate productivity during the lower section deposition to an under-filled lake basin with higher productivity during the upper section deposition, in response to the climatic change from warm humid to hot semiarid conditions. Accordingly, the corresponding depositional models of mixed source rocks in the upper and lower sections of the Lucaogou Formation are proposed. Overall, the mixed rocks of the Lucaogou Formation can be regarded as good source rocks, which could offer favorable targets and resource potential for tight oil exploration.

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Section: Resultsmentioning

confidence: 74%

Section: Resultsmentioning

confidence: 99%

Geochemical Characteristics, Hydrocarbon Potential, and Depositional Environment Evolution of Fine-Grained Mixed Source Rocks in the Permian Lucaogou Formation, Jimusaer Sag, Junggar Basin

et al. 2020

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“…Biomarkers have drawn much attention in the past few decades, mainly because of their usefulness in assessing organic matter type and quality, depositional conditions (e.g., salinity, oxicity, anoxicity), thermal maturity level, biodegradation extent and lithology (Arfaoui et al 2007 ; Ding et al 2016 ). In the upper sweet spot, the source rocks in the interior of the sweet spot are characterized by high value of Pr/Ph (>1), low C 27 steranes, moderate C 28 steranes, and high C 29 steranes, which are consistent with the biomarkers characteristics of oil in the upper sweet spot (Fig.…”

Section: Resultsmentioning

confidence: 99%

Geochemical characterization of Lucaogou Formation and its correlation of tight oil accumulation in Jimsar Sag of Junggar Basin, Northwestern China

Ding

Zhang

et al. 2017

J Petrol Explor Prod Technol

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With the constant consumption of conventional oil and gas resources, unconventional oil and gas resources with great resource potential such as tight oil have gradually been valued and become the new exploration area. Jimsar Sag is the key tight oil exploration and development block in Junggar Basin of Northwestern China. Based on the data sets of geology, oil production test, logging, rock thin section, and geochemistry of Permian Lucaogou Formation (LCG), we studied the geochemical characteristics of hydrocarbon source rocks and their relation to the tight oil accumulation. Organic matter abundance of source rocks is high, the types of organic matter are mainly type I and type II, and the organic matter maturation is in the low mature stage to mature stage. Results of oil source correlation showed that the crude oil of sweet spots was mainly derived from the source rocks in the interior of the sweet spots. The LCG tight oil is mainly distributed in the plane where the source rocks have great thickness and the TOC is higher than 3.5%. It shows that the source rocks have obvious controlling on the occurrence and accumulation of tight oil.

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“…The depression is part of the Early Cretaceous rift group, which was formed and developed on the Hercynian Fold Basement (Wei and Xu, 1994;Zhai et al, 2010). Previous work in the region has shown that four potential source rocks were developed: the Sahantala Formation (K 1 s), the Duhongmu Formation (K 1 d 3 , K 1 d 2 , and K 1 d 1 ), the Tengge'er Formation (K 1 t), and the A'ershan Formation (K 1 a 2 and K 1 a 1 ) (Ding et al, 2015(Ding et al, , 2016Gao et al, 2015;Wei and Xu, 1994;Zhai et al, 2010). However, previous studies on the source rock in the Baibei Depression have been limited to a single well (well Sc1), and only the A'ershan Formation has been found to be thermally mature, with vitrinite reflectance values in the range of 0.6-0.75%R O (Gao et al, 2015).…”

Section: Introductionmentioning

confidence: 99%

Hydrocarbon source rock evaluation of the Lower Cretaceous system in the Baibei Depression, Erlian Basin

Liu

Ren

Lyu

et al. 2017

Energy Exploration & Exploitation

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The K 1 s, K 1 d, K 1 t, and K 1 a Formations are potential source rock intervals for hydrocarbon formation, all of which are part of the Lower Cretaceous system in the Baibei Depression in the Erlian Basin in China. However, no well has found oil flow because the hydrocarbon-generating potential of the source rocks has not been comprehensively evaluated. Based on organic geochemical and petrological analyses, all the source rocks possess highly variable total organic carbon and S 1 + S 2 contents. Total organic carbon and S 1 + S 2 contents indicate that the K 1 a 2 Formation through the K 1 d 1 Formation are source rocks that have fair to good generative potential and the K 1 d 2 Formation through the K 1 s Formation are source rocks that have good to very good generative potential. The organic matter in the K 1 a 2 Formation is dominated by Type I and II kerogen; thus, it is considered to be oil prone based on H/C versus O/C plots. Most of the analyzed samples were deposited in reducing environments and sourced from marine algae; thus, they are oil prone. However, only two source rock intervals were thermally mature with vitrinite reflectance values in the required range. Hydrocarbon-generating histories show that the K 1 t and K 1 a 2 intervals began to generate hydrocarbons during the depositional period of the K 1 d 2 and K 1 d 3 Formations, respectively, and stopped generating hydrocarbons at the end of the depositional period of the late Cretaceous. Therefore, the main stage of hydrocarbon migration and accumulation was between the depositional period of the K 1 d 2 and K 1 s Formations, and the critical moment was the depositional period of the late K 1 s Formation. The generation conversion efficiency reached approximately 55% in the K 1 a 2 Formation and 18% in the K 1 t Formation at

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Geochemical characterization and depositional environment of source rocks of small fault basin in Erlian Basin, northern China

Cited by 47 publications

References 41 publications

Geochemical Characteristics, Hydrocarbon Potential, and Depositional Environment Evolution of Fine-Grained Mixed Source Rocks in the Permian Lucaogou Formation, Jimusaer Sag, Junggar Basin

Geochemical Characteristics, Hydrocarbon Potential, and Depositional Environment Evolution of Fine-Grained Mixed Source Rocks in the Permian Lucaogou Formation, Jimusaer Sag, Junggar Basin

Geochemical characterization of Lucaogou Formation and its correlation of tight oil accumulation in Jimsar Sag of Junggar Basin, Northwestern China

Hydrocarbon source rock evaluation of the Lower Cretaceous system in the Baibei Depression, Erlian Basin

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