The development plan of the new oil field discovered in a remote offshore environment, Niger Delta, Nigeria was evaluated. As the oil in place is uncertain, a probabilistic approach was used to estimate the STOOIP using the low, mid, and high cases. The STOOIP for these cases were 95 MMSTB, 145 MMSTB and 300 MMSTB which are the potential amount of oil in the reservoir. Rock and fluid properties were determined using PVT sample and then matched to the Standing correlations with an RMS of 4.93%. The performance of the different well models were analyzed, and sensitivities were run to provide detailed information to reduce the uncertainties of the parameters. Furthermore, production forecast was done for the field for the different STOOIP using the predicted number of producer and injector wells. The timing of the wells was accurately allocated to provide information for the drillers to work on the wells. From the production forecast, the different STOOIP cases had a water cut ranging from 68-73% at the end of the 15-year field life. The recoverable oil estimate was accounted for 33.25 MMSTB for 95 MMSTB (low), 55.1 MMSTB for 145 MMSTB (mid) and 135 MMSTB for 300 MMSTB (high) at 35%, 38% and 45% recovery factor. Based on the proposed development plan, the base model is recommended for further implementation as the recovery factor is 38% with an estimate of 55.1 MMSTB. The platform will have 6 producers and 2 injectors. The quantity of oil produced is estimated at 15000 stbo/day which will require a separator that has the capacity of hold a liquid rate of about 20000 stb/day. The developmental wells are subsequently increased to achieve a water cut of 90-95% with more recoverable oil within the 15-year field life. This developmental plan is also cost effective as drilling more wells means more capital expenditure.

the development of a fluvial reservoir oil or gas field poses complex challenges in field development strategies during appraisal and exploration stage due to some subsurface uncertainties. In this study, the channel geometries such as straight-channel, Y-shaped channel and U-shaped channel are assessed based on conceptual geological modelling. In order to provide robust information, a case scenario for both oil and gas fluvial producing reservoir are simulated using ECLIPSE 100a black oil simulator, with data which has been adopted from Walsh and Gringarten [2]; Hogg et al. [6]. The result of the study shows that the pressure behaviour in the different channels is because of the change in channel geometry. This property determines the hydrocarbon recovery method and as such integration of analytical method, numerical simulation and geological modelling are employed as tools for planning field development strategies in fluvial reservoirs.