Development of a Geological and Oil Reservoir Numerical Simulation Model to Predict the Effectiveness of Surfactant Imbibition Enhanced Oil Recovery for the Bakken Formation in North Dakot

This research employs an integrated geological modeling and numerical simulation method on an ultra-tight rock formation to determine if the surfactant imbibition process is a feasible enhanced oil recovery method. The ultra-tight rock formation studied was the Bakken Formation in East Mountrail County, North Dakota. A detailed geological model and numerical simulation model of the formation was established by various technologies, e.g. ArcGIS 10.4, Geologic Evaluation System (GES2016), and Computer Modeling Group (CMG) -- STARS programs. All data was collected from actual field measurements and well-log readings of in place formations. The reservoir model provided a 500 ft. x 500 ft. grid resolution 3D model of the Bakken Formation with 20-layer vertical resolution showing the formation lithology and petrophysical property distributions. The analysis of the reservoir numerical simulation model was focused on Well Patten 1-27H #16799 from Hunt Oil Company. The results from the simulation produced a production history match in oil production and water cut histories along with forecasting results. An ethoxy-sulfate alcohol nonionic surfactant of 0.1% formulation was the basis concentration and was able to simulate an increase in production of Well # 16799 by about 800,000 ft3 of oil and an incremental oil recovery factor of 9.8% OOIP compared to using current hydraulic fracturing method. In summery the simulation of huff-n-puff surfactant imbibition produced similar results found in lab core sample testing. This outcome suggests that future field-testing of surfactant imbibition enhance oil recovery is needed in order to support or modify the results found in this research.