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A hybrid hydraulic fracture (HHF) model composed of (1) complex discrete fracture networks (DFN) and (2) planar fractures is proposed for modeling the stimulated reservoir volume (SRV). Modeling the SRV is complex and requires a synergetic approach between geophysics, petrophysics, and reservoir engineering. The objective of this paper is to characterize and evaluate the SRV considering the initial hydraulic fracturing efficiency, fracture network complexity, mechanics, and microseismicity distribution along 145 stimulated stages in a multilateral horizontal well on the Muskwa, Otter Park and Evie Formations in the Horn River Shale in Canada. Hydraulic fracturing jobs in shale reservoirs are designed with a view to achieve economic production by exploiting fracture network complexity. The task involves significant challenges in modeling and forecasting, which complicates the examination of operations to enhance their performance, including refracturing or infill drilling. In this study, an HHF is run in a numerical simulation model to evaluate the SRV performance in planar and complex fracture networks using microseismicity data collected during 75 stages of hydraulic fracturing in the Horn River shale. Post-fracturing production is appraised with Rate Transient Analysis (RTA) for determining effective permeability under flowing conditions, compare to the numerical simulation and the hydraulic fracturing design. Fracturing stages with larger fracture patch sizes, associated with the microseismic events in a fixed stress drop, correspond to higher stimulated areas, fracture conductivity, and gas production. Several microseismic events are observed in the heel of the laterals that are aligned to the far field NE stresses, indicated a loss of efficiency along the wellbore lateral during hydraulic fracturing. The hydraulic propagation modeling revealed increment of the leak-off coefficient, related to the natural fractures and communication with other stages. The production performance is evaluated in the numerical model, to measure interference between stages. The SRV, modeled with HHF networks, is able to match the post-fracturing production history. Fracture mechanics is important in order to understand the flowing performance of the reservoir. The inclusion of propagating models and RTA allowed to characterize possible fracture geometries in the reservoir and to observe limitations inherent to large dispersion and uncertainty of the microseismicity cloud. Also, to observe areas where the stimulation may have propped natural fractures totally or partially, which will benefit the production of gas. This study presents a better understanding and characterization of the SRV in shale gas reservoirs, especially in those cases where microseismicity dispersion is problematic and where the SRV is not easily delimited.

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A methodology to determine and delimitate the magnitude of the principal in-situ stresses in the Glauconite Formation of the Willesden Green Field in the Western Canada Sedimentary Basin (WCSB) is presented. The result is used to correlate with several failure scenarios including confirmation of hydraulically fractured zones and to optimize net stress conditions for drilling and wellbore stability. Geomechanical rock properties (Poisson's ratio, Young's Modulus, Biot vertical constant, rock strength, and the coefficient of angel friction) and the minimum horizontal stress (Shmin) are calculated from well logs. The Mohr failure criteria is considered in other to determine possible failure magnitude of normal stress. Based on the minimum horizontal stress, the magnitude of the maximum horizontal stress (Shmax) is delimited. This permits estimating failure magnitudes of normal, reverse, strike-slip faulting planes, wellbore and tensile breakout scenarios. Based on the theory of wellbore equilibrium, the Shmax is calculated in the fractured interval. This is corroborated with different failure scenarios predicted with the Mohr-Coulomb envelopes, and the unconfined rock strength (UCS) estimated from well logs. The stress polygon that describes the in situ stress magnitudes limitations before failure for the Willesden Green Field is elaborated, and defines a very low-stress zone in the highly gas saturated and permeable interval. The polygon is suitable for drilling design and geomechanical analysis, particularly in those intervals where wellbore stability may be a problem. The methodology can have practical and wide application in several fields where the predictions are limited due to restricted geomechanical information. The approach permits a quick delimitation of in-situ stresses valuable in those reservoirs with wellbore stability problems due to abnormal pressures.

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