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Proppant Settlement and Long-Term Conductivity Calculation in Complex Fractures.

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This study introduces a new method to calculate complex fracture conductivity, considering proppant placement and deformation. Results show conductivity declines over time due to proppant embedment and creep, influenced by closure pressure and sand concentration.

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Area of Science:

  • Petroleum Engineering
  • Geomechanics
  • Fluid Dynamics

Background:

  • Current fracture conductivity models often overlook proppant placement in complex fracture networks.
  • Single-fracture testing inadequately represents the overall conductivity of intricate fracture systems.

Purpose of the Study:

  • To develop a novel calculation method for long-term complex fracture conductivity.
  • To incorporate proppant placement, embedment, and deformation under stress into conductivity calculations.

Main Methods:

  • Developed a calculation method integrating fracture morphology, proppant placement, and deformation.
  • Analyzed fracture conductivity changes over time and under varying closure pressures.
  • Investigated the impact of proppant placement, sand concentration, and fracturing fluid viscosity.

Main Results:

  • Fracture conductivity decreases over time in three distinct stages: embedding, creep, and stabilization.
  • Main fractures exhibit higher long-term conductivity than branching fractures.
  • Increased closure pressure reduces both main and branching fracture conductivities due to accelerated proppant embedment and creep.

Conclusions:

  • Proppant placement significantly impacts fracture conductivity, with higher sand ratios improving conductivity in both main and branching fractures.
  • Fracturing fluid viscosity enhances proppant migration, promoting better distribution in branching fractures and improving their conductivity.
  • The proposed method provides a more accurate assessment of long-term fracture conductivity in complex systems.