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The development effects of horizontal wells in tight oil reservoirs vary greatly. Current microseismic monitoring of hydraulic fracture propagation is costly, while numerical simulation of stimulated reservoir volume (SRV) faces grid distortion issues. In response to these challenges, the Material Point Method (MPM) was applied to evaluate fracturing adaptability in unconventional reservoirs. This method simulates rock strain near wellbores, hydraulic fracture geometry, and SRV, assessing their impacts on well productivity. The results show that the stress field, fracture geometry, and SRV align closely with microseismic data, demonstrating high reliability. The mudstone near the horizontal section can cause local artificial fractures to extend shorter. It will result in a slightly smaller area for hydraulic fracturing. The longer the penetrated sandstone length of the horizontal well, the larger SRV. The larger the angle between natural fractures and artificial fractures, and the larger the angle between the horizontal section and the maximum horizontal principal stress, the more it helps to expand SRV. Initial production correlates positively with SRV, penetrated sandstone length, and reservoir quality. It also indicates that there is poor adaptability between current fracturing techniques and reservoir. A proppant size blend mainly composed of coarse sand is an important factor for effective reservoir utilization. The optimal fracturing section length for horizontal wells in tight oil reservoir is 50–60 m. And the intersection angle between the horizontal section and the maximum horizontal principal stress should be maintained at 60°–90°. The optimal well spacing should be 400–600 m. The optimized proppant size blend is mainly coarse sand, resulting in a larger fracturing volume. The research results have guided the design of tight oil horizontal wells. The stable daily oil production per well reached 8.0t/d. This is of great significance for promoting the development of tight oil reservoirs by reducing costs and increasing efficiency.

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The Application of Material Point Method Simulation in the Adaptability Evaluation of Tight Oil Fracturing

  • 会议论文

  • 发表日期：

    2026年

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  • Mei Zhang,
  • Qing-bin Zhang,
  • Mei-feng Sun,
  • Jun-mei Gao,
  • Yang-dong Liu,
  • Jin-long Chen

摘要

The development effects of horizontal wells in tight oil reservoirs vary greatly. Current microseismic monitoring of hydraulic fracture propagation is costly, while numerical simulation of stimulated reservoir volume (SRV) faces grid distortion issues. In response to these challenges, the Material Point Method (MPM) was applied to evaluate fracturing adaptability in unconventional reservoirs. This method simulates rock strain near wellbores, hydraulic fracture geometry, and SRV, assessing their impacts on well productivity. The results show that the stress field, fracture geometry, and SRV align closely with microseismic data, demonstrating high reliability. The mudstone near the horizontal section can cause local artificial fractures to extend shorter. It will result in a slightly smaller area for hydraulic fracturing. The longer the penetrated sandstone length of the horizontal well, the larger SRV. The larger the angle between natural fractures and artificial fractures, and the larger the angle between the horizontal section and the maximum horizontal principal stress, the more it helps to expand SRV. Initial production correlates positively with SRV, penetrated sandstone length, and reservoir quality. It also indicates that there is poor adaptability between current fracturing techniques and reservoir. A proppant size blend mainly composed of coarse sand is an important factor for effective reservoir utilization. The optimal fracturing section length for horizontal wells in tight oil reservoir is 50–60 m. And the intersection angle between the horizontal section and the maximum horizontal principal stress should be maintained at 60°–90°. The optimal well spacing should be 400–600 m. The optimized proppant size blend is mainly coarse sand, resulting in a larger fracturing volume. The research results have guided the design of tight oil horizontal wells. The stable daily oil production per well reached 8.0t/d. This is of great significance for promoting the development of tight oil reservoirs by reducing costs and increasing efficiency.