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

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 multidisciplin...

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Vydáno v:Energies (Basel) Ročník 18; číslo 10; s. 2617
Hlavní autoři: Liu, Zhong, Wang, Hui, Lu, Xiuqin, Zhang, Qianqian, Yang, Yanhui, Zhang, Tao, Zhang, Chen, Wang, Zihan
Médium: Journal Article
Jazyk:angličtina
Vydáno: Basel MDPI AG 01.05.2025
Témata:
Accuracy
Analysis
Coal
Coalbed methane
Computer simulation
Computer-generated environments
Deformation
Fault lines
geological modeling
Geology
Integrated approach
Methane
Optimization
Permeability
production simulation
Productivity
reservoir evaluation
Simulation
Simulation methods
stress field modeling
China
ISSN:1996-1073, 1996-1073
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Shrnutí: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 km2 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 m3/t residual gas content, 0.8–1.0 mD permeability, 8–12% porosity), type II (northern/central: 20–26 m3/t residual gas content, 0.5–0.6 mD permeability, 5–8% porosity), and type III (<20 m3/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.
Bibliografie:ObjectType-Article-1
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ISSN:1996-1073
1996-1073
DOI:10.3390/en18102617