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Experimental Investigation into Hydraulic Fracture Network Propagation in Gas Shales Using CT Scanning Technology

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Abstract

Multistage fracturing of the horizontal well is recognized as the main stimulation technology for shale gas development. The hydraulic fracture geometry and stimulated reservoir volume (SRV) is interpreted by using the microseismic mapping technology. In this paper, we used a computerized tomography (CT) scanning technique to reveal the fracture geometry created in natural bedding-developed shale (cubic block of 30 cm × 30 cm × 30 cm) by laboratory fracturing. Experimental results show that partially opened bedding planes are helpful in increasing fracture complexity in shale. However, they tend to dominate fracture patterns for vertical stress difference Δσ v  ≤ 6 MPa, which decreases the vertical fracture number, resulting in the minimum SRV. A uniformly distributed complex fracture network requires the induced hydraulic fractures that can connect the pre-existing fractures as well as pulverize the continuum rock mass. In typical shale with a narrow (<0.05 mm) and closed natural fracture system, it is likely to create complex fracture for horizontal stress difference Δσ h  ≤ 6 MPa and simple transverse fracture for Δσ h  ≥ 9 MPa. However, high naturally fractured shale with a wide open natural fracture system (>0.1 mm) does not agree with the rule that low Δσ h is favorable for uniformly creating a complex fracture network in zone. In such case, a moderate Δσ h from 3 to 6 MPa is favorable for both the growth of new hydraulic fractures and the activation of a natural fracture system. Shale bedding, natural fracture, and geostress are objective formation conditions that we cannot change; we can only maximize the fracture complexity by controlling the engineering design for fluid viscosity, flow rate, and well completion type. Variable flow rate fracturing with low-viscosity slickwater fluid of 2.5 mPa s was proved to be an effective treatment to improve the connectivity of induced hydraulic fracture with pre-existing fractures. Moreover, the simultaneous fracturing can effectively reduce the stress difference and increase the fracture number, making it possible to generate a large-scale complex fracture network, even for high Δσ h from 6 MPa to 12 MPa.

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Acknowledgments

This paper was support by the Major National Science and Technology Projects of China (No. 2012ZX05018-004) and the National Basic Research Program of China (No. 2013CB228004).

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Authors and Affiliations

  1. CMOE Key Laboratory of Petroleum Engineering, China University of Petroleum, Beijing, China

    Zou Yushi, Zhang Shicheng, Zhou Tong & Zhou Xiang

  2. China University of Petroleum, Qingdao, China

    Guo Tiankui

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  1. Zou Yushi
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  2. Zhang Shicheng
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Correspondence to Zou Yushi.

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Yushi, Z., Shicheng, Z., Tong, Z. et al. Experimental Investigation into Hydraulic Fracture Network Propagation in Gas Shales Using CT Scanning Technology. Rock Mech Rock Eng 49, 33–45 (2016). https://doi.org/10.1007/s00603-015-0720-3

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