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Overpressure: Origin, Prediction, and Its Impact in the Xihu Sag, Eastern China Sea

Author

Listed:
  • Li Wang

    (College of Geoscience and Surveying Engineering, China University of Mining and Technology-Beijing, Beijing 100083, China)

  • Ruizhao Yang

    (College of Geoscience and Surveying Engineering, China University of Mining and Technology-Beijing, Beijing 100083, China)

  • Zhipeng Sun

    (College of Geoscience and Surveying Engineering, China University of Mining and Technology-Beijing, Beijing 100083, China)

  • Lingda Wang

    (College of Geoscience and Surveying Engineering, China University of Mining and Technology-Beijing, Beijing 100083, China)

  • Jialiang Guo

    (College of Geoscience and Surveying Engineering, China University of Mining and Technology-Beijing, Beijing 100083, China)

  • Ming Chen

    (Shanghai Petroleum Company, Shanghai 200041, China)

Abstract

The complex relationship between deep overpressure, abnormal porosity, and hydrocarbon generation in the Pinghu Formation is interesting and challenging for hydrocarbon exploration and development in the East China Sea Shelf Basin. It shows three-stage pore pressure evolution based on the characteristics of logs in the west slope of the Xihu Sag. Disequilibrium compaction was identified as the dominant overpressure mechanism in stage II (1.0 < PC < 1.6). The fluid expansion was identified as the predominant mechanism of overpressure generation in stage III (PC > 1.6), and tectonic compression occurs in Well B. Pore pressure was predicated by the Fillippone method based on the combination of raw velocity spectra and high-resolution velocity parameters obtained by seismic inversion. The overpressure at the bottom of the Pinghu Formation is mainly distributed in the F2 and F3 fault blocks. The deep gas reservoir of the Pinghu Formation is controlled by both lithology and pressure. The overpressure distribution area is consistent with the center of hydrocarbon generation. The overpressure distribution illustrated that overpressure was positively correlated with the porosity and permeability of the reservoir. The first porosity and permeability inversion zone of the Pinghu Formation formed because the overpressure caused by under-compaction offsets the pressure of some overlying strata and slows down diagenesis. Due to a large amount of hydrocarbon generation in source rocks, the acidic fluid with high temperature promoted the development of secondary pores, resulting in the second pore permeability inversion zone of the Pinghu Formation. The index of porosity preserving (IPP) is proposed here to quantitatively describe the relationship between overpressure and porosity. The index of porosity preserving in the second stage is 1.16%/10 MPa, and in the third stage is 1.75%/10 MPa. The results can be used to guide the exploration of the deep-basin gas reservoir of the Xihu Sag in the Eastern China Sea Basin.

Suggested Citation

  • Li Wang & Ruizhao Yang & Zhipeng Sun & Lingda Wang & Jialiang Guo & Ming Chen, 2022. "Overpressure: Origin, Prediction, and Its Impact in the Xihu Sag, Eastern China Sea," Energies, MDPI, vol. 15(7), pages 1-20, March.
    • Handle: RePEc:gam:jeners:v:15:y:2022:i:7:p:2519-:d:782769
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    References listed on IDEAS

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    1. Chao Li & Xiaorong Luo & Likuan Zhang & Bing Wang & Xiaoyan Guan & Hongmei Luo & Yuhong Lei, 2019. "Overpressure Generation Mechanisms and Its Distribution in the Paleocene Shahejie Formation in the Linnan Sag, Huimin Depression, Eastern China," Energies, MDPI, vol. 12(16), pages 1-24, August.
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    Cited by:

    1. Zhong Chen & Wei Wei & Yongchao Lu & Jingyu Zhang & Shihui Zhang & Si Chen, 2022. "The Control of Sea Level Change over the Development of Favorable Sand Bodies in the Pinghu Formation, Xihu Sag, East China Sea Shelf Basin," Energies, MDPI, vol. 15(19), pages 1-26, September.

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