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This paper discusses how a fully-compositional, dual permeability numeric reservoir simulation was used to model flow from a Duvernay well pair after fracture stimulation. A geologic model based on well log data, referenced to coordinates on the Universal Transverse Mercator (UTM) coordinate system, utilizing North American Datum 83 (NAD83), Zone 11 UTM, was constructed. A sub-grid of this, containing permeability and porosity data, was imported as the grid for the dynamic reservoir simulator. The subject wellbore location was loaded into the model using UTM coordinates for the wellhead location and the wellbore trajectory survey. Microseismic event locations were also imported, relative to the treatment wellbore, measured during the time the fracturing treatments were conducted.
The use of a compositional reservoir simulator allows studying of the contribution of the secondary fracture system with liquids rich production. The matching of simulation results to actual production through changes in primary and secondary fracture system conductivity values allows investigation of the contribution each fracture system makes to both early and later time production. Through a better understanding of the contributions of both primary and secondary fracture systems in liquids rich production, operators can much better understand how to optimize a fracturing treatment design while helping minimize costs.
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© Copyright 2014. Society of Petroleum Engineers
Presented at the SPE/CSUR Unconventional Resources Conference – Canada, 30 September – 2 October 2014, Calgary, Canada