Formation and distribution of coal measure source rocks in the Eocene Pinghu Formation in the Pinghu Slope of the Xihu Depression, East China Sea Shelf Basin
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Abstract: The Xihu Depression in the East China Sea Shelf Basin is a large petroliferous sedimentary depression, in which oil and gas reservoirs were mainly discovered in the Pinghu Slope and the central inversion zone. The oil-gas source correlation in the Xihu Depression was analyzed by hydrocarbon generating thermal simulation data via gold-tube pyrolysis experiments. The results indicated that the oil and gas in the Xihu Depression were mainly derived from coal measure source rocks of the Eocene Pinghu Formation. Therefore, the identification of coal seams is extremely crucial for evaluating coal measure source rocks in the Pinghu Formation in the Xihu Depression. Geochemical and petrological characterization pointed to input of terrigenous organic matter and redox conditions of the depositional environment as factors that govern the ability of the coal measure source rocks in hydrocarbon generation in the Xihu Depression. In this regard, the sedimentary organic facies in the Pinghu Formation were classified into four predominantly terrigenous and one mixed-source subfacies, which all varied in carbon and hydrogen content. The coal measure source rocks in the carbon- and hydrogen-rich tidal flat-lagoon exhibited the highest hydrocarbon generation potential, whereas the mudstone in the neritic facies was the poorest in its hydrocarbon yield. These results suggested that the coal measure source rocks in the Pinghu Formation likely developed in the Hangzhou Slope and the Tiantai Slope, both representing promising sources for oil and gas exploration.
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Figure 1. Structural outline of the Xihu Depression in the East China Sea Shelf Basin (Yu, 2020; Zhu et al., 2019). The whole wells are excessively dense and only key wells are shown.
Figure 2. Generalized stratigraphic column for the Xihu Depression showing the Tertiary petroleum system (Zhu et al., 2012).
Figure 3. Coal seam cores in the Pinghu Formation. a. Well A31; b. Well A13; c. Well A32.
Figure 4. Mass chromatogram (m/z 85) showing the alkanes and isoprenoids (pristane, phytane) in the saturated hydrocarbon frantions of the source rock and the crude oils in the Xihu Depression. a. The crude oil in the Pinghu Formation sandstone reservoir in Well A5; b. the crude oil in the Pinghu Formation sandstone reservoir in Well A25; c. the coal of the Pinghu Formation in Well A32. Pr: pristane; Ph: phytane.
Figure 5. Mass chromatogram (m/z 191) showing terpanes in the saturated hydrocarbons derived from the source rocks and crude oil in the Xihu Depression. a. Coal sample from the Pinghu Formation in Well A4; b. crude oil sample from the sandstone reservoir of the Pinghu Formation in Well A6.
Figure 6. Mass chromatogram (m/z 123) showing tetracyclic diterpanes (norpimarane, isopimarane, phyllocladane) in saturated hydrocarbons isolated from the source rocks and crude oil in the Xihu Depression. a. Crude oil sample isolated from the sandstone reservoir in the Pinghu Formation of Well A5; b. crude oil sample isolated from the sand reservoir in the Pinghu Formation of Well A25; c. coal from the Pinghu Formation in Well A32. nPM: norpimarane; iPM: isopimarane; PC: phyllocladane.
Figure 7. Stable-carbon isotope analysis of the methane produced from the gold-tube pyrolysis experiments, showing the relationship between δ13C1 (PDB, the Vienna Pee Dee Belemnite standard) and easy Ro value (%).
Figure 8. Cross plot of δ13C1 versus C1/(C2+C3) ratio for the gaseous hydrocarbons generated by the source rocks in the Pinghu Formation, based on the results of gold-tube pyrolysis experiments.
Figure 9. Pr/nC17-Ph/nC18 cross plot of liquid hydrocarbons generated by the source rocks in the Pinghu Formation.
Figure 10. The relationship between the sedimentary facies and the geochemical characteristics the source rocks in the Pinghu Formation in Well 25. Stra.: stratum; Mem.: member; AC: acoustic curve; GR: gamma ray; Lith.: lithology; TOC: total organic carbon, %; HI: hydrogen index, mg/g.
Figure 11. The relationship between the sedimentary facies and the geochemical characteristics the source rocks in the Pinghu Formation in Well A13. Stra.: stratum; Mem.: member; AC: acoustic curve; GR: gamma ray; Lith.: lithology; TOC: total organic carbon, %; HI: hydrogen index, mg/g.
Figure 12. The relationship between the sedimentary facies and the geochemical characteristics the source rocks in the Pinghu Formation in Well A40. Mem.: member; GR: gamma ray; Lith.: lithology; TOC: total organic carbon, %; HI: hydrogen index, mg/g.
Figure 13. Microscopical photos of palynological analysis of coal measure source rocks in the Pinghu Formation. a. 3721 m, Well A23; b. 3470 m, Well A29. W: woody, C: coaly.
Figure 14. Comparison of the content of the woody and coaly organic matter between different sedimentary subfacies in the Pinghu Formation.
Figure 15. Back-scattered electron microscopic images of coal measure source rocks in the Pinghu Formation. a. Light color layer (poor carbon mudstone) of massive mudstone of the top of 4th member of Pinghu Formation (3 709 m) in Well A13; b. dark layer (micro coal seam) of continuous carbonaceous mudstone of the 4th member of Pinghu Formation (3 896 m) in Well A13. C: carbon; Si: silicon; Al: aluminum; S: sulfur; O: oxygen.
Figure 16. Cross-plot of Pr/nC17 and Ph/nC18 ratio showing the origin of the oil in the Xihu Depression.
Figure 17. Cross-plot of δ13C1 and C1/(C2+C3) ratio showing the origin of the natural gas in the Xihu Depression.
Figure 18. Cross-plots of the sulfur-silicon and silicon-carbon ratio (a) and the silicon-carbon and aluminum-carbon atomic ratio (b) of coal measure source rocks in the Pinghu Formation.
Figure 19. Cross plot of sulfur content and TOC in coal measure source rocks derived from different sedimentary subfacies in the Xihu Depression.
Figure 20. The colloid chemistry-based metallogenic depositional model on the formation of coal measure source rocks of Pinghu Formation in the Pinghu Slope.
Figure 21. Statistical comparison of pollen content between different sedimentary subfacies in the Pinghu Formation.
Figure 22. Statistical comparison ratio of the coal/formation thickness (a) and coal seam thickness (b) between the source rocks from different sedimentary subfacies in the Pinghu Formation.
Figure 23. TOCs (a) and hydrogen indices (b) of the source rocks collected from different sedimentary subfacies in the Pinghu Formation.
Figure 24. Distribution of source rocks across different organic facies in the Pinghu Formation in the Xihu Depression. a. The 5th, b. 4th, c. 3rd and d. 1st/2nd member of the Pinghu Formaiton.
Table 1. Geochemical informations of the source rock samples from the Pinghu Formation used for gold-tube pyrolysis
No. Well Depth/m Sample type Lithology TOC/% Ro/% 1 A1 3678−3681 cutting coal measure mudstone 0.68 0.73 2 A35 3570 cutting coal 63.15 0.63 3 A36 3008 cutting coal measure mudstone 0.48 0.76 4 A37 2624 cutting coal 48.64 0.50 
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Table 2. Geochemical parameters of isoprenoids in the liquid hydrocarbons generated by the source rocks in the Pinghu Formation in Well A35
No. Sample
typeHeating rate/
(℃·h−1)Pr/nC17
ratioPh/nC18
ratioPr/Ph
ratio1 coal 20 3.20 0.58 7.00 2 coal 20 2.85 0.58 6.50 3 coal 20 2.94 0.57 7.05 4 coal 20 3.51 0.59 7.58 5 coal 20 3.47 0.59 7.38 6 coal 20 3.31 0.55 7.44 7 coal 20 2.95 0.55 6.39 8 coal 20 2.30 0.42 5.75 9 coal 20 1.86 0.35 5.78 10 coal 20 1.28 0.25 5.38 11 coal 20 0.93 0.18 5.46 12 coal 20 0.68 0.15 5.00 13 coal 2 3.00 0.52 7.50 14 coal 2 3.43 0.64 6.67 15 coal 2 3.75 0.65 7.06 16 coal 2 3.64 0.61 7.06 17 coal 2 2.90 0.53 5.95 18 coal 2 2.33 0.42 5.67 19 coal 2 1.66 0.31 5.42 20 coal 2 0.99 0.18 5.92 21 coal 2 0.69 0.12 5.73 22 coal 2 0.50 0.09 5.67 23 coal 2 0.21 0.04 6.25 24 coal 2 0.07 0.02 5.33 Note: Sample informations are showed in Table 1.
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