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Volume 45 Issue 6
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Article Navigation >  PETROLEUM GEOLOGY & EXPERIMENT  > 2023  >  45(6): 1178-1188
LIU Ming, YANG Ruiqing, YANG Fengli, LIU Haojuan, ZHANG Zhiping, WANG Wei, HU Panpan. Numerical modeling of in-situ stress and prediction of favorable area of shale gas layer in Wufeng to Longmaxi formations, Nanchuan region, southeastern Chongqing[J]. PETROLEUM GEOLOGY & EXPERIMENT, 2023, 45(6): 1178-1188. doi: 10.11781/sysydz2023061178
Citation: LIU Ming, YANG Ruiqing, YANG Fengli, LIU Haojuan, ZHANG Zhiping, WANG Wei, HU Panpan. Numerical modeling of in-situ stress and prediction of favorable area of shale gas layer in Wufeng to Longmaxi formations, Nanchuan region, southeastern Chongqing[J]. PETROLEUM GEOLOGY & EXPERIMENT, 2023, 45(6): 1178-1188. doi: 10.11781/sysydz2023061178
shu

Numerical modeling of in-situ stress and prediction of favorable area of shale gas layer in Wufeng to Longmaxi formations, Nanchuan region, southeastern Chongqing

doi: 10.11781/sysydz2023061178
  • 1.

    Research Institute of Exploration and Development, SINOPEC East China Oil & Gas Company, Nanjing, Jiangsu 210000, China

  • 2.

    School of Ocean and Earth Science, Tongji University, Shanghai 200092, China

  • Received Date: 2023-03-29
  • Rev Recd Date: 2023-10-07
  • Publish Date: 2023-11-28
    Abstract
  • Upper Ordovician Wufeng to Lower Silurian Longmaxi formations in Nanchuan region, as an important shale gas productive layer, is characterized by large shale thickness, deep burial depth, and complex in-situ stress with rapid direction changes. Therefore, the study of in-situ stress field is of significance for effective deve-lopment of shale gas in the study area. In order to clarify the characteristics and distribution of the in-situ stress field, the SHELLS finite element stress field modeling method, with faults, topography, heat flow, petrophysical parameters and boundary conditions as constraints, was used in the study of the stress field in the Wufeng-Longmaxi formations in the Nanchuan region.The results indicate that the maximum compressive horizontal principal stress is in thrust regime and that there are four principal stress directions and regions in general: NW-SE, NE-SW, near EW and near SN. The strain rate is in thrust regime, with three regions of low strain rate (magnitude ≤ -18), medium strain rate (magnitude between -18 and -17.6) and high strain rate (magnitude ≥ -17.6) and their corresponding NE-SW, NW-SE, SN and EW spreading directions. The fault slip rate regime is in thrust, the fault slip rates range from 0 to 0.001 2 mm/a. The modeled results of the maximum compressive horizontal principal stress, the strain rate and fault slip rate were compared with the measured data respectively, including the maximum compressive horizontal principal stress directions measured in drilled wells, the regime and magnitude of strain rate in Guizhou and Chongqing, and the properties of regional faults. The modeled results showed high agreement with the measured data, indicating the accuracy of the predicted results. Finally, based on fracture openness and fracture development revealed by modeled results, favorable fractured reservoir development zones for shale gas was evaluated, and class Ⅰ and Ⅱ zones for further exploration and development were predicted.

     

    • All authors disclose no relevant conflict of interests.
    The profile and data were provided by LIU Ming, LIU Haojuan and ZHANG Zhiping. The manuscript was drafted and revised by LIU Ming, YANG Ruiqing, YANG Fengli, HU Panpan and WANG Wei. All the authors have read the last version of paper and consented for submission.
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