A New Analytical Model for the Multi-Fractured Horizontal Well in the Naturally Fractured Reservoir
- Y. Gao (Khalifa University of Science and Technology) | M. M. Rahman (Khalifa University of Science and Technology) | J. Lu (Khalifa University of Science and Technology)
- Document ID
- Society of Exploration Geophysicists
- SEG/AAPG/EAGE/SPE Research and Development Petroleum Conference and Exhibition, 9-10 May, Abu Dhabi, UAE
- Publication Date
- Document Type
- Conference Paper
- 85 - 88
- 2018. Society of Exploration Geophysicists
- permability, horizontal well, porosity
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- 42 since 2007
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This document is an expanded abstract.
This study mainly puts forward a new analytical trilinear dual-porosity & dual-permeability flow model for the multi-fractured horizontal well (MFHW) in the naturally fractured reservoir (NFR) based on the trilinear dual-porosity flow model (Brown et al., 2011). This model is an upgraded trilinear flow model, a simple but versatile one to integrate horizontal-well-related parameters and petrophysical characteristics of the NFR, including wellbore storage, chocking skin factor, intrinsic properties of matrix and fracture systems, and even different properties of the stimulated area and the unstimulated area. The model incorporates a dual-permeability model for the stimulated flow region and a dual-porosity model for the unstimulated flow region respectively. In common sense, the traditional flow model for the fractured horizontal well with the line-source solution is computationally intensive and time-consuming, while this model makes itself a practical alternative with computational convenience and also incorporates most of the distinct flow patterns identical as the line-source solution does. The new trilinear flow model would show a field-friendly way to analyze transient pressure behaviors of the MFHW in the reservoir with well-developed natural fractures.
Increasing demand for oil and gas resources in a cost-efficient way has significantly accelerated the development of MFHWs which have considerably enlarged the reservoir exposure and efficiently connected comparatively low-permeability flow regions in reservoirs with well-developed natural fractures. Hydraulic fractures are generally created to connect with existing natural fractures for larger productivity. Due to the complex communication of hydraulic fractures to natural fractures, flow behaviors through the porous reservoir and from the reservoir to the horizontal wellbore have become much more complicate (Gu et al., 2017). To cope with such situation, as illustrated in the Figure 1 and Figure 2, Brown et al. (2009) first put forward a practical Trilinear Dual-Porosity Flow Model for MFHWs and took into account the effect of the outer reservoir flow region and the influence of natural fractures in the inner reservoir flow region on transient pressure behaviors by using the dual-porosity model (Warren and Root, 1963).
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