A Finite Difference Approach To Modeling Geomechanics In Hydraulic Fracturing
The ability to both model the growth of a fracture system from a hydraulic fracture treatment and its closure over time due to pressure depletion is critical to understand and improve hydraulic fracture methodology. If the Stimulated Rock Volume (SRV) is pre-determined by the engineer and flowback water is discounted during history matching using a conventional reservoir simulator, the actual hydraulic fracturing treatment has no impact on the model. A holistic approach that incorporates the entire life of the well is key to history matching hydraulically fractured wells. The new reservoir simulation technology presented here contains novel features that allow for such a complete match of hydraulically fractured wells. Field reported fracture fluid volumes are injected at the measured rates, stage by stage, in order to generate the SRV. If the hydraulic fracture design is changed it will change the generated SRV. This technique has been applied to wells in the Wolfcamp, Three Forks, and Bakken shale oil fields. The quality of the history match has been higher than what was possible using pre-existing technology.