Subsurface Dynamics was tasked with determining the optimal water injector location(s) and injection rate waterflood scenario for an undisclosed pool in the conventional formation in Alberta containing horizontal multi-fractured wells. The operator was looking to evaluate response time and incremental recoveries.
FORMATION: Conventional Oil with MultiStage Fracking, Alberta
Scope of Work
Using publicly available data and proprietary data from the Client including expected completion characteristics, Subsur-face Dynamics constructed a static and history matched dy-namic model. Using the history matched model, existing hori-zontal wells were converted to water injectors to test the im-pact of injector location and injection rate.
As a result of the full cycle modeling, the following operational improvements were achieved:
- Optimal existing horizontal well location for an injector was determined. Location can serve as the template for additional future waterflood locations
- Impact of injection rate on repressurization rate and corresponding production profile was determined
- Optimal scenario improved incremental recovery by fifty percent in impacted wells