Modeling of Hydraulic-Fracture-Network Propagation in a Naturally Fractured Formation
- Xiaowei Weng (Schlumberger) | Olga Kresse (Schlumberger) | Charles-Edouard Cohen (Schlumberger) | Ruiting Wu (Schlumberger) | Hongren Gu (Schlumberger)
- Document ID
- Society of Petroleum Engineers
- SPE Production & Operations
- Publication Date
- November 2011
- Document Type
- Journal Paper
- 368 - 380
- 2011. Society of Petroleum Engineers
- 5.8.1 Tight Gas, 5.8.6 Naturally Fractured Reservoir, 3.2.3 Hydraulic Fracturing Design, Implementation and Optimisation, 5.5 Reservoir Simulation, 5.8.2 Shale Gas, 3 Production and Well Operations, 1.2.2 Geomechanics, 2.5.1 Fracture design and containment, 5.1 Reservoir Characterisation, 1.2.3 Rock properties, 5.8.7 Carbonate Reservoir, 2.4.3 Sand/Solids Control, 2.2.2 Perforating, 5.1.2 Faults and Fracture Characterisation, 5.3.2 Multiphase Flow, 2.5.2 Fracturing Materials (Fluids, Proppant)
- shale gas, fracture model, hydraulic fracturing, natural fractures
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- 4,837 since 2007
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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.
|File Size||4 MB||Number of Pages||13|
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