The Agbami project team was challenged to generate a field development plan and to assess that plan over a wide range of uncertainty. Complete stakeholder alignment around the technical aspects of the development plan was a critical issue. Field data, laboratory data, and analog data were incorporated into a range of reservoir simulation models. The field data included appraisal well logs, cores, 3D seismic, fluid samples, pressure data, and drill stem tests. Three hundred reservoir models were constructed and ranked using streamline simulation for both static and dynamic attributes to assess the range of subsurface uncertainty. A project team with significant but diverse deepwater development experience was formed and co-located. A formal phased decision making process was implemented. During each phase of the process key parameters of uncertainty were identified and ranked in terms of project impact. Field development options were evaluated in distinct phases over the full range of uncertainty. Experimental Design (ED) methodology was used throughout the evaluation to obtain the maximum information with the minimum computational effort. The paper shows how the results from this process facilitated the identification of the key uncertainties and provided direct input into economic models for decision analysis. In Phase Two of the evaluation the pressure maintenance scheme selected for the 17 million year (MY) reservoir was crestal gas re-injection with peripheral water injection. Crestal gas re-injection was selected for the 14MY and 16MY reservoirs. The facility capacity requirements were also selected during this phase at 250,000 stock tank bbl of oil per day (STB/D) and 450,000 thousand standard cubic ft per day (Mscf/D). Peer reviews and assists were held and alignment was obtained along with action items to be included in the subsequent phase. In Phase Three of the evaluation the well count parameter was investigated and an optimum number of 38 wells was selected. Production profiles were generated and presented in terms of P10, P50, and P90. Introduction This paper will focus on the application of Experimental Design (ED) during Phase Three at Agbami. With drilling depths of up to 10,000 ft below mudline in 4,800 ft of water, well costs at Agbami are at the high end of typical deepwater costs. Therefore, the number of wells including their type and location is an important optimization parameter in the field development plan. The probabilistic forecast of all produced and injected fluids is also a key deliverable of the field development plan. Agbami project stakeholders are aligned on all technical aspects of the field development plan and the project is rapidly proceeding toward sanction and awarding of major contracts.