SPE Production & Operations
Volume 26, Number 4, November 2011, pp. 368-380

SPE-140253-PA

Modeling of Hydraulic-Fracture-Network Propagation in a Naturally Fractured Formation

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DOI  More information 10.2118/140253-PA http://dx.doi.org/10.2118/140253-PA

Citation

  • Weng, X., Kresse, O., Cohen, C., Wu, R., and Gu, H. 2011. Modeling of Hydraulic-Fracture-Network Propagation in a Naturally Fractured Formation. SPE Prod & Oper 26 (4): 368-380. SPE-140253-PA. http://dx.doi.org/10.2118/140253-PA.

Discipline Categories

  • 5.3.3 Hydraulic Fracturing and Gravel Packing

Keywords

  • hydraulic fracturing, fracture model, shale gas, natural fractures

Summary

Hydraulic fracturing in shale-gas reservoirs has often resulted in complex-fracture-network growth, as evidenced by microseismic monitoring. The nature and degree of fracture complexity must be understood clearly to optimize stimulation design and completion strategy. Unfortunately, the existing single-planar-fracture models used in the industry today are not able to simulate complex fracture networks.

A new hydraulic-fracture model is developed to simulate complex-fracture-network propagation in a formation with pre-existing natural fractures. The model solves a system of equations governing fracture deformation, height growth, fluid flow, and proppant transport in a complex fracture network with multiple propagating fracture tips. The interaction between a hydraulic fracture and pre-existing natural fractures is taken into account by using an analytical crossing model and is validated against experimental data. The model is able to predict whether a hydraulic-fracture front crosses or is arrested by a natural fracture it encounters, which leads to complexity. It also considers the mechanical interaction among the adjacent fractures (i.e., the "stress shadow" effect). An efficient numerical scheme is used in the model so it can simulate the complex problem in a relatively short computation time to allow for day-to-day engineering design use.

Simulation results from the new complex-fracture model show that stress anisotropy, natural fractures, and interfacial friction play critical roles in creating fracture-network complexity. Decreasing stress anisotropy or interfacial friction can change the induced-fracture geometry from a biwing fracture to a complex fracture network for the same initial natural fractures. The results presented illustrate the importance of rock fabrics and stresses on fracture complexity in unconventional reservoirs. These results have major implications for matching microseismic observations and improving fracture stimulation design.

© 2011. Society of Petroleum Engineers

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History

  • Original manuscript received: 11 February 2010
  • Meeting paper published: 25 January 2011
  • Revised manuscript received: 12 July 2011
  • Manuscript approved: 10 September 2011
  • Published online: 25 October 2011
  • Version of record: 22 November 2011