Hydraulic fracturing is the primary method for realizing reserves out the conventional oil and gas wells. Million of dollars are spent in year basis in the US and little is known on how effective these treatments are and what it is required for optimization, the big question is: is the selected treatment optiumum? Current practices are mainly focused on completion trials in which different approaches are exercised to get a trend of possible optimum treatments. This learning curve takes years and lot resources are left behind.

In the presented study, a fracturing job done a horizontal well from Haynesville shale was evaluated using a 3D planar fracture simulator to get an insight on how effective the fracture treatment was, explore possible ways for optimization and ultimately delve into the causes of low recovery experienced in this particular well. The fracturing job consisted of a cross link gel type job in a multi stage horizontal well.

The stress profile used in the simulator was estimated based on the vertical transverse isotropic (VTI) model which takes into account vertical/horizontal variations on static Young modulus and Poisson’s ratio. Fracture height prediction from the planar 3D simulator was compared to microseismic events and a good agreement was found. Furthermore horizontal fracture growth occurred predominantly away from the target formation leaving low proppant coverage near wellbore and poor connectivity which explains the low expected ultimate recovery obtained from this well compared its neighbors treated with Slickwater. Finally, scenarios for fracture designs were evaluated to minimize water usage and it was found in general that frac jobs are rather conservative in this aspect and a lot of room is available for water reduction.

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