|dc.description.abstract||According to the 2017 outlook on energy conducted by the EIA, the production of natural gas from shale reservoirs is expected to increase by 2040. This increase is dependent on multiple factors like technology, resources, and market conditions. In order to meet production increases, improvements in industry practices must happen in order to achieve better economic development of these reservoirs. One of the primary tools used in economic development is reservoir simulation.
However, modeling and simulating low permeability reservoirs, like shale, can be complex due to the presence of natural fractures. Knowing that fractures have a significant role in the total recovery of a field, modeling the influence of these fractures is of utmost importance. There are two common methods used to model naturally fractured reservoirs, the dual continuum model and the discrete fracture model.
In this study, an embedded discrete fracture model (EDFM) was used to simulate and match a hydraulically fractured vertical gas well in the Barnett Shale in 3D. EDFM was proposed by Li and Lee (2008) to couple the dual continuum model with the discrete fracture model to take advantage of both methods. The results show that EDFM can be validated and can be an efficient tool for future reservoir simulation. In addition, a parametric study was conducted to visualize how fracture orientation and fracture density impact fluid flow. It was concluded that fracture orientation plays an important part in fracture connectivity, which is a result of fracture orientation. If the fractures are highly connective, the better the well performance. The same was seen with fracture density, an increased fracture density leads to better well performance.||en