Volume 40 Issue 2
Mar.  2023
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SUN Chenhao, HUANG Sha, DONG Sailiang, et al.A new reservoir wettability characterization method for fracturing fluid performance[J]. Drilling Fluid & Completion Fluid，2023, 40（2）：251-258 doi: 10.12358/j.issn.1001-5620.2023.02.014
Citation: SUN Chenhao, HUANG Sha, DONG Sailiang, et al.A new reservoir wettability characterization method for fracturing fluid performance[J]. Drilling Fluid & Completion Fluid，2023, 40（2）：251-258 doi: 10.12358/j.issn.1001-5620.2023.02.014
shu

A New Reservoir Wettability Characterization Method for Fracturing Fluid Performance

doi: 10.12358/j.issn.1001-5620.2023.02.014
  • 1.

    State Key Laboratory of Petroleum Resources and Prospecting, China University of Petroleum, Beijing 102249

  • 2.

    College of Geosciences, China University of Petroleum, Beijing 102249

  • 3.

    Engineering & Design Institute, CNPC Offshore Engineering Company Limited, Beijing 100028

  • Received Date: 2022-12-30
  • Accepted Date: 2023-02-01
  • Rev Recd Date: 2023-02-15
  • Publish Date: 2023-03-30
    Abstract
  • Unconventional reservoirs have characteristics of complex pore geometry, high heterogeneity and low permeability. The wetting behavior between the fluid and solid is the dominant factor that controlling the static and dynamic fluid displacements, which is of great crucial for evaluating the fracturing fluid performance, enhancing the oil recovery during the fracturing fluid imbibition, and optimizing the fracturing fluid formulation. In this paper, we propose a new in-situ wettability characterization method based on the Gauss-Bonnet theorem and 3D micro-computed tomography experiments. In addition, we systematically analyze the effect of complex wetting condition on fracturing fluid performance during the imbibition process of fracturing fluids by applying digital rock technology and lattice-Boltzmann method simulations. It is elucidated that the wettability characterization method by the topological principles is more accurate than in-situ microscopic contact angles, of which accuracy is higher than 95%. It is also capable of characterizing the wettability that is influenced by different wetting characteristics. Simultaneously, the tight oil recovery in the homogeneous water-wet reservoir is 33.8% higher than that of mixed-wet reservoirs, which leads to a better performance of fracturing fluid. The initial condition of reservoir is commonly mixed-wet. Therefore, the formulation of fracturing fluid needs to be optimized to reduce the rock wettability and enhance tight oil recovery.

     

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