Biomarker signatures of Sinian bitumens in the Moxi–Gaoshiti Bulge of Sichuan Basin, China: Geological significance for paleo-oil reservoirs

Chen, Zhonghong; Simoneit, Bernd R.T.; Wang, T.-G.; Yang, Yueming; Ni, Zhiyong; Cheng, Bin; Luo, Bin; Yang, Chengyu; Chen, Tong

doi:10.1016/j.precamres.2017.04.038

Cited by 61 publications

(18 citation statements)

References 102 publications

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“…The Neoproterozoic to Lower Cambrian black shales widely occur around the world and have attracted great interest from geologists and geochemists because of the economic importance of petroleum exploration potential and geological implications (Grosjean, Love, Kelly, Taylor, & Summons, ; Grosjean, Love, Stalvies, Fike, & Summons, ; Huang, Zhang, & Su, ; Suryendu, Sharmila, & Srinivasan, ; Zhang et al, ). This potential has been confirmed by the discoveries of some industrial petroleum fields in many countries, particularly in China (Chen et al, ; Huang et al, ; Zhang et al, ), Oman (Grantham, ; Grosjean et al, ), western India (e.g., Suryendu et al, ), eastern Siberia (e.g., Kelly, Love, Zumberge, & Summons, ), and Australia (Logan, Summons, & Hayes, ). Besides, the Ediacaran–Cambrian (E–C) black shales also indicate the significant transition from Precambrian Era to the Phanerozoic, which is marked by tectonic readjustments and palaeoceanographic, palaeoclimatic, and biological conversion (Craig et al, ).…”

Section: Introductionmentioning

confidence: 85%

“…The Sichuan Basin is a large‐scale petroliferous basin located in the shallow‐water setting of the Yangtze Platform (Zhu, Wang, Xie, Xie, & Liu, ; Zou et al, ). The studied Gaoshiti‐Moxi (GM) area (Figure b), is an important tectonic unit located in the ancient uplift named Leshan‐Longnvsi developed during the Ediacaran in the central Sichuan Basin (Chen et al, ). Because of the high palaeogeographical position of GM region in the Sichuan Basin and limited sea level rise, only a few sediments were deposited in GM region during the Fortunian Stage to early Stage 2 of the Early Cambrian (about 20 Myr; Gao et al, ).…”

Section: Geological Settingmentioning

confidence: 99%

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Main factors controlling the organic matter enrichment in the Lower Cambrian sediments of the Sichuan Basin, SW China

Wang

Tian

et al. 2019

Geological Journal

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The Lower Cambrian Qiongzhusi Formation contains more than 200 m of marine sediments mainly consisting of mudstone and black shales, which are widely accepted as the most important hydrocarbon source rocks of the Ediacaran–Cambrian giant gas field in the Sichuan Basin. The geochemical compositions of biomarkers and trace elements obtained from black shales at the bottom of the Qiongzhusi Formation were used to reconstruct the palaeoproductivity and palaeoenvironment and to determine the main factors controlling the deposition and preservation of this organic‐rich shales. Based on varieties of steroids and hopanoids compositions, multifarious palaeobios such as pelagophyceae, dinoflagellate, diatom (or its ancestor), sponges, and aerobic/anaerobic bacteria have been proved to evolve in the Early Cambrian in the Sichuan Basin. In addition, a relative high concentration of Cubio compared with modern oceanic palaeoproductivity proxies indicate a moderate to relatively high palaeoproductivity, which is favourable for the organic matter accumulation of this source rocks. Moreover, the evidence from biomarkers and trace element ratios suggest that the Lower Cambrian sediments were deposited under a non‐sulphurized anoxic condition, which provided a favourable preservation condition. The covariation among Porg, Cubio, and TOC shows that the palaeoproductivity is the main controlling factor for the high organic content of the black shales of the Qiongzhusi Formation.

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Section: Introductionmentioning

confidence: 85%

Section: Geological Settingmentioning

confidence: 99%

Main factors controlling the organic matter enrichment in the Lower Cambrian sediments of the Sichuan Basin, SW China

Wang

Tian

et al. 2019

Geological Journal

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“…The Sinian succession was then buried to a depth of 5015–5396 m. During the burial process, the oil may have pyrolyzed into pyrobitumen and gas, which are the most common materials filling the pore space in the reservoir 2 , 3 . The geochemistry evidences of pyrobitumen indicate that the gas field was generated by an in-situ burial pyrolysis of paleo-oil 20 , 21 . The Sinian reservoir is located at the top of the Dengying Formation (Z 2dn4 ) (Fig.…”

Section: Geological Settingmentioning

confidence: 99%

A new genetic mechanism of natural gas accumulation

Yang

Wang

et al. 2018

Sci Rep

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Natural gas of organic origin is primarily biogenic or thermogenic; however, the formation of natural gas is occasionally attributed to hydrothermal activity. The Precambrian dolomite reservoir of the Anyue gas field is divided into three stages. Dolomite-quartz veins were precipitated after two earlier stages of dolomite deposition. Fluid inclusions in the dolomite and quartz are divided into pure methane (P-type), methane-bearing (M-type), aqueous (W-type), and solid bitumen-bearing (S-type) inclusions. The W-type inclusions within the quartz and buried dolomite homogenized between 107 °C and 223 °C. Furthermore, the trapping temperatures and pressures of the fluid (249 °C to 319 °C and 1619 bar to 2300 bar, respectively) are obtained from the intersections of the isochores of the P-type and the coeval W-type inclusions in the quartz. However, the burial history of the reservoir indicates that the maximum burial temperature did not exceed 230 °C. Thus, the generation of the natural gas was not caused solely by the burial of the dolomite reservoir. The results are also supported by the presence of paragenetic pyrobitumen and MVT lead-zinc ore. A coupled system of occasional invasion by hydrothermal fluids and burial of the reservoir may represent a new genetic model for natural gas accumulation in this gas field.

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“…The third member of Dengying Formation is composed of dolomite and mudstone. The Fourth member of Dengying Formation is dominated by algal dolomite with thin‐bedded grey dolomite mudstone at the top (Chen et al, ). A large‐scale Sinian gas field was recently discovered in the Moxi (MX well)–Gaoshiti (GS well) areas in central Sichuan Basin (Figure c).…”

Section: Regional Geological Settingmentioning

confidence: 99%

Trace element characterization of bitumen constraints on the hydrocarbon source of the giant gas field in Sichuan Basin, South China

Chen

et al. 2018

Geological Journal

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The exploration of high production, natural gas wells (>10 6 m 3 /d) has been extremely successful in the Gaoshiti and Moxi areas of the Leshan-Longnvsi paleo-uplift, in the west-central Sichuan Basin. This paper focuses on the Sinian and Cambrian reservoirs from the Gaoshiti and Moxi areas, where a dataset of new trace elements in bitumen and potential source rock is reported and where hydrocarbon-source correlation is attempted based on trace elements characteristics of the 12 potential source rocks and 22 bitumen samples. Results show that the bitumen from the three reservoirs can be distinguished from each other using trace element distribution patterns and redox-and provenance-sensitive elemental ratios. Bitumen in the second and fourth members of the Sinian Dengying Formation were derived primarily from the third member of the source rocks of the Dengying Formation, which represents a selfsourced paleo-petroleum system. In contrast, bitumen in the reservoirs of the Cambrian Longwangmiao Formation is derived from the Cambrian Qiongzhusi Formation and third member of Dengying Formation. The trace element method used in this study improves our understanding of the complex hydrocarbon-source relation and confirm the potential target for petroleum exploration in the study area.

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Biomarker signatures of Sinian bitumens in the Moxi–Gaoshiti Bulge of Sichuan Basin, China: Geological significance for paleo-oil reservoirs

Cited by 61 publications

References 102 publications

Main factors controlling the organic matter enrichment in the Lower Cambrian sediments of the Sichuan Basin, SW China

Main factors controlling the organic matter enrichment in the Lower Cambrian sediments of the Sichuan Basin, SW China

A new genetic mechanism of natural gas accumulation

Trace element characterization of bitumen constraints on the hydrocarbon source of the giant gas field in Sichuan Basin, South China

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