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Integrated 3D Geological Modeling, Stress Field Modeling, and Production Simulation for CBM Development Optimization in Zhengzhuang Block, Southern Qinshui Basin

Author

Listed:
  • Zhong Liu

    (Petro China Huabei Oilfield Company, Renqiu 062550, China)

  • Hui Wang

    (School of Emergency Management and Safety Engineering, North China University of Science and Technology, Tangshan 063210, China
    School of Energy Resource, China University of Geosciences (Beijing), Beijing 100083, China)

  • Xiuqin Lu

    (Petro China Huabei Oilfield Company, Renqiu 062550, China)

  • Qianqian Zhang

    (Petro China Huabei Oilfield Company, Renqiu 062550, China)

  • Yanhui Yang

    (Petro China Huabei Oilfield Company, Renqiu 062550, China)

  • Tao Zhang

    (Petro China Huabei Oilfield Company, Renqiu 062550, China)

  • Chen Zhang

    (Petro China Huabei Oilfield Company, Renqiu 062550, China)

  • Zihan Wang

    (Petro China Huabei Oilfield Company, Renqiu 062550, China)

Abstract

The Zhengzhuang Block in the Qinshui Basin is one of the important coalbed methane (CBM) development areas in China. As high-quality CBM resources become depleted, remaining reserves exhibit complex geological characteristics requiring advanced development strategies. In this study, a multidisciplinary workflow integrating 3D geological modeling (94.85 km 2 seismic data, 973 wells), geomechanical stress analysis, and production simulation was developed to optimize development of the Permian No. 3 coal seam. Structural architecture and reservoir heterogeneity were characterized through Petrel-based modeling, while finite-element analysis identified stress anisotropy with favorable stimulation zones concentrated in southwestern sectors. Computer Modeling Group (CMG) simulations of a 27-well group revealed a rapid initial pressure decline followed by a stabilization phase. A weighted multi-criteria evaluation framework classified resources into three tiers: type I (southwestern sector: 28–33.5 m 3 /t residual gas content, 0.8–1.0 mD permeability, 8–12% porosity), type II (northern/central: 20–26 m 3 /t residual gas content, 0.5–0.6 mD permeability, 5–8% porosity), and type III (<20 m 3 /t residual gas content, <0.4 mD permeability, <4% porosity). The integrated methodology provides a technical foundation for optimizing well patterns, enhancing hydraulic fracturing efficacy, and improving residual gas recovery in heterogeneous CBM reservoirs.

Suggested Citation

  • Zhong Liu & Hui Wang & Xiuqin Lu & Qianqian Zhang & Yanhui Yang & Tao Zhang & Chen Zhang & Zihan Wang, 2025. "Integrated 3D Geological Modeling, Stress Field Modeling, and Production Simulation for CBM Development Optimization in Zhengzhuang Block, Southern Qinshui Basin," Energies, MDPI, vol. 18(10), pages 1-21, May.
    • Handle: RePEc:gam:jeners:v:18:y:2025:i:10:p:2617-:d:1659012
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    References listed on IDEAS

    as
    1. Bo Wang & Qingtian Zhang & Zhenghui Qu & Yiteng Zhang, 2023. "South Anze Structure and Its Control on Coalbed Methane Aggregation in the Qinshui Basin and the Mechanism of Syncline Gas Enrichment in the Qinshui Basin," Energies, MDPI, vol. 16(11), pages 1-20, June.
    2. Youzhuang Sun & Junhua Zhang & Zhengjun Yu & Zhen Liu & Pengbo Yin, 2022. "WOA (Whale Optimization Algorithm) Optimizes Elman Neural Network Model to Predict Porosity Value in Well Logging Curve," Energies, MDPI, vol. 15(12), pages 1-14, June.
    3. Xingying Ma & Aitao Zhou & Xiaoyu Cheng & Cheng Cheng & Wei Zhao, 2024. "Multi-Field Coupling Models of Coal and Gas and Their Engineering Applications to CBM in Deep Seams: A Review," Energies, MDPI, vol. 17(24), pages 1-27, December.
    4. Chen Li & Lichun Sun & Zhigang Zhao & Jian Zhang & Yong Li & Yanjun Meng & Lei Wang, 2024. "A Method for Evaluating Coalbed Methane Reservoir Productivity Considering Drilling Fluid Damage," Energies, MDPI, vol. 17(7), pages 1-16, April.
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