Microseismic imaging technology can help in providing the answers to many previously unknown questions involving the process and results of hydraulically fracturing the sandstones in the Upper Devonian wells of the Appalachian Basin. Uncertainties surrounding fracture orientation, fracture length, fracture height, the effect of treatment size, and identification of potential fracture complexities can be reduced. Developing an understanding of fracture geometry is vital and can lead to improvements in reservoir management and development.

Every year thousands of wells are drilled and completed in the Upper Devonian sands throughout the Appalachian Basin. Nearly all of these wells are fracture stimulated in some manner. The tools available to the completion engineer in designing these treatments are limited and uncertainties regarding their efficiency and optimization often exist. Process improvement can be limited or delayed by the lag time involved in determining stimulation effectiveness based upon production results. Even then inferences must be made concerning fracture geometries based upon well testing or fracture modeling. The use of microseismic fracture imaging allows real time or near real time decisions to be made.

This paper will present a case history of the implementation and utilization of microseismic fracture imaging conducted in three multi-stage stimulation treatments in Devonian Sand tight gas wells in Pennsylvania. The created fracture geometries and their implications for future treatment design, fracture model calibration, and reservoir management will be explored.

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