This course is designed to help geoscientists develop a strong understanding of how reservoir simulators function and how to effectively capture key heterogeneities in static models to better replicate the true flow behavior of wells and fields. The program focuses on fluid and rock properties, reservoir drive mechanisms, well productivity, and ultimate recovery. Fundamental concepts of well testing are covered to provide insight into how tests are conducted, how results are analyzed, and what information can be derived from them. Various dynamic simulation approaches are reviewed, including black oil and compositional models, with particular emphasis on black oil model initialization. Inflow Performance Relationship (IPR) and Vertical Lift Performance (VLP) curves are introduced before progressing to resource definitions and reserve calculation methodologies.

The course concludes with economic evaluation and screening metrics, highlighting the reservoir engineer’s role in reserves estimation and project economic assessment based on dynamic modeling results. Optimization of well numbers and well placement is addressed, with emphasis on minimizing capital and operating expenditures while maintaining best industry practices.

The course structure combines morning lectures with afternoon tutorial sessions. Participants work in teams of three to four and are provided with a static model and detailed instructions to develop a Field Development Plan (FDP). Different development and injection scenarios are evaluated to identify the most technically and economically optimal solution.