Maximizing production in low-permeability or naturally fractured reservoirs requires either exploiting pre-existing natural fracture systems or creating new networks of fractures to reach otherwise inaccessible reserves. The properties of natural fractures are controlled in many cases by the stress magnitudes and orientations relative to the fracture orientations. The far-field and near-well orientations and propagation pressures of induced fractures also are predominantly controlled by stress. Furthermore, in a naturally fractured reservoir, fracture stimulation performance depends on the relative pressure required to stimulate pre-existing fractures compared with the pressure required to propagate a hydrofrac. This has created considerable controversy and a variety of recommended “best practices” to maximize production in the Barnett and similar formations.

This talk will briefly review methods for determining in situ stress orientations and magnitudes and address how knowledge of the in situ stress can impact operational decisions. For example:
• What is the optimal drilling direction to maximize productivity from natural fractures?
• What is the optimal direction to drill a well to be hydraulically stimulated?
• What is the best direction to drill a well to maximize production from the largest volume of rock based on hydraulic stimulation and natural fractures?
• What conditions and stimulation practices lead to the largest stimulated volume?
• What information does microseismic fracture mapping provide about the stimulation process and result?

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