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<p>Hydraulic fracturing is widely used to enhance hydrocarbon production in low-permeability reservoirs, but its application in loosely cemented sandstone reservoirs presents unique challenges. These formations exhibit high pore permeability and low rock strength, making frac-packing susceptible to fracture conductivity damage. To address this, a novel experimental framework was developed to investigate the combined effects of proppant compression, embedment, and fines migration under varying closure pressures. Experimental results demonstrate a significant decline in fracture conductivity with increasing closure stress, primarily governed by closure pressure, proppant size, and formation strength. Over time, fines migration into the packed proppant bed further reduces fracture conductivity. Based on these findings, an integrated fracture conductivity model for weakly consolidated sandstone reservoirs was developed and validated through its application in the Bohai oilfield. Quantitatively, conductivity loss was attributed to proppant compression (34%), embedment into the fracture face (19%), and fines plugging (23%), resulting in an overall reduction of approximately 59%. This study provides a comprehensive understanding of the coupled mechanisms driving fracture conductivity degradation in frac-packing wells. Key recommendations include selecting larger proppant sizes, maintaining an initial fracture width of at least 12.5&#xa0;mm, and controlling early production rates to minimize conductivity loss. The proposed model and findings contribute to improving frac-packing design and performance in unconsolidated sandstone formations.</p>

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Weakly-consolidated sandstone fracture conductivity under combined action of compressing, proppant embedding and fines plugging: experiments, model and application

  • 期刊论文

  • 出版模式：

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  • 发表日期：

    2025年6月10日

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  • Guolong Li,
  • Changyin Dong,
  • Haobin Bai,
  • Yaotu Han,
  • Qilong Zhang

摘要

Hydraulic fracturing is widely used to enhance hydrocarbon production in low-permeability reservoirs, but its application in loosely cemented sandstone reservoirs presents unique challenges. These formations exhibit high pore permeability and low rock strength, making frac-packing susceptible to fracture conductivity damage. To address this, a novel experimental framework was developed to investigate the combined effects of proppant compression, embedment, and fines migration under varying closure pressures. Experimental results demonstrate a significant decline in fracture conductivity with increasing closure stress, primarily governed by closure pressure, proppant size, and formation strength. Over time, fines migration into the packed proppant bed further reduces fracture conductivity. Based on these findings, an integrated fracture conductivity model for weakly consolidated sandstone reservoirs was developed and validated through its application in the Bohai oilfield. Quantitatively, conductivity loss was attributed to proppant compression (34%), embedment into the fracture face (19%), and fines plugging (23%), resulting in an overall reduction of approximately 59%. This study provides a comprehensive understanding of the coupled mechanisms driving fracture conductivity degradation in frac-packing wells. Key recommendations include selecting larger proppant sizes, maintaining an initial fracture width of at least 12.5 mm, and controlling early production rates to minimize conductivity loss. The proposed model and findings contribute to improving frac-packing design and performance in unconsolidated sandstone formations.