Gas condensate wells within the Khuff C formation in Saudi Arabia are typically acid fracture stimulated following drilling. Early PTA tests conducted after stimulation indicate excellent fracture conductivity and length properties. After tie - in, the wells experience a rapid production loss, which stabilizes after 2 to 5 months. Well producing BHP is below the dew point pressure. This study was undertaken to identify the source of productivity loss. Possible causes include near well liquid dropout, fracture conductivity loss and reservoir permeability loss due to increased effective stresses.

The study was successful in determining the changing total skin with time and allocating it to each of the potential damage mechanisms. This was accomplished by using a reservoir simulation model, which adequately represented stress dependent properties as a simpler function of pressure. A number of type curves were used to assist in making pragmatic decisions as to what parameters to adjust during the history matching process.

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