Simulation models of the low net to gross zones of the Kekiktuk Formation have, historically, been difficult to history match. Traditional mapping of the zones, e.g., isopach, netto gross ratio, and porosity, tended to oversimplify the internal heterogeneities within the reservoir sandstones and the spatial distribution of sand bodies. Current reservoir simulations address this problem through the use of deterministic and stochastic fine-scale geological models. Fluid movement is appropriately modeled and history matched in both simulations without significant pore volume modifications. Contrary to previous simulations, current simulation data shows that up dip gas injection combined with down dip water injection increases ultimate recovery of Zone 3 oil. Results from both types of simulations can be used in synergy or separately to address global reservoir and well specific issues to optimize ultimate recovery.