With the use of well log data and stress tests, reservoirs can be characterized by layers with different values of porosity, permeability, in-situ stress, Young’s modulus, and fracture toughness.1,2  These fluid flow and mechanical properties dictate not only the height, length, and width of a created fracture, but also affect the distribution of proppant in the fracture. Also, the location of the perforated interval in a layered reservoir plays an important role in the overall propped fracture dimensions.

We have developed a finite-difference, hydraulic fracture treatment simulator that computes fracture dimensions in a layered reservoir.3 Each layer can have different mechanical properties. The model allows initiation of the fracture in multiple producing intervals simultaneously. In this paper, we have used this model to illustrate the effects of mechanical properties on fracture dimensions and proppant transport profiles. In reservoirs with multiple producing zones, we have generated examples where the fracture is initiated in one or several intervals simultaneously, so that we can illustrate the effects of perforation placement upon the distribution of proppant within the fracture. These examples illustrate that the location of the perforations can substantially affect the final proppant profile. We have then taken the propped fracture geometry and used a single-phase finite-difference reservoir simulator to show the production increase and long-term production performance for the different scenarios.

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