An overall geomechanical model was developed in the Wilcox sands of the Arcabuz-Culebra field, a tight gas reservoir in the Burgos Basin, northern México. Multiple technologies were integrated to build a geomechanical model of the field, which was used as a primary tool to predict fracture direction and stress field distribution. Advanced fracture diagnostic technologies that measure the created fracture geometry were used to support the geomechanical modeling.
The technical approach combined geomechanical modeling, hydraulic fracture mapping, fracture engineering and reservoir engineering studies to optimise fracture treatment designs and improve the planning of well location and spacing. This methodology can be very important to avoid drilling unnecessary wells or leaving gas in place.
By integrating geomechanical techniques through single well reservoir modeling, it was observed that ineffective well positioning could inhibit production by as much as 0.5 Bcf per well. Fracture engineering analysis identified significant potential cost savings by reducing fracture treatment size and changing proppant type. In addition potential production increase of 3 Bcf per well may be possible with refracture treatments. This paper discusses these results, and presents a case history that details the application and integration of reservoir geomechanics technologies to improve the practices in the gas reservoir management.
Author(s): Sergio Berumen; Pemex E&P, Craig Cipolla; StrataGen Engineering, Thomas Finkbeiner; Geomechanics International, Steve Wolhart; Gas Research Institute, Fernando Rodriguez; Pemex E&P
Paper Number: SPE 594180