The incorporation of the smart technologies in injection wells has not been widely considered before this work, hence the originality.The world's demand for oil product is increasing gradually and lack of new significant discoveries has made it imperative to look for secondary processes and better technology that will help increase oil production. One of the secondary recovery mechanism used all over the world is waterflooding. Waterflooding is used in nearly all the fields in the world, it is used after natural depletion, and it's used for pressure maintenance and volumetric sweep of the reservoir. Smart well technology is another technology that is assisting in increasing oil production, it's a non-convectional well with downhole instrumentation (sensors, valves and inflow control devices) installed on the production or injection tubing. This work presents a methodology where waterflooding is been controlled by smart injector well technology to help optimize or increase the net present value of the Field. The optimization procedure was done on three different case studies of commingled reservoir having different layer characteristics; it involves vertical smart injector well and production well penetrating fully through the commingled reservoir. A set-up optimization procedure was applied, were rate allocation method was used at each zone of the smart injector well. In this research, the right rate allocation to each zone that gives the maximum Oil recovery or highest Net Present Value gives the answer to the Waterflood Optimization setback. The smart injector well use in this research has Inflow control Valves which can automatically open and close in order to meet certain reservoir or production requirements. Installing Smart Completion on the injector well gives an opportunity to control all cases of early water breakthrough and reduce water recycling in some reservoir layers; which will ultimately lead to an increase of 2% -8% in the Net Present Value and 6% -9% Cumulative Production of from the field. This Technology is highly recommended for Niger Delta fields to improve recovery and delay water breakthrough.

Water flooding is a promising oil recovery mechanism, which has inherent potentials to recover more oil from the reservoir. Quite unfortunately, the mechanism has been under utilized due to improper consideration of quality of water to be injected. The quantity of water injected into the reservoir has always been of interest to the Engineer, until recently when they became interested in the quality. They soon discovered that if proper consideration is given to the quality of the ionic composition of the injected water by lowering its TDS, oil recovery can be greatly enhanced, and residual oil saturation immensely reduced (Tang and Morrow 1999). Its evidences in the literature are undisputable. Lowering the salinity or TDS of injected water results in lowering the oil-rock capillary pressure, reduction in oil-water interfacial tension, and finally a change in the relative permeability, which results into a wettability change, usually to a mixed-wet or water-wet state. This project aims at determining the impact of low salinity water flooding on oil recovery in a carbonate reservoir in the Middle East. It was decided to use ECLIPSE and an analytical solution as methodologies for solving the problem. Quite interestingly, ECLIPSE was not able to predict increase in oil recovery due to non- dependence of salt concentration on relative permeability in the model. The analytical solution predicted an oil recovery of about 9% FOE, with an additional oil volume of three million and seventy-six thousand barrels (3,076,000 STB) to be recovered at the surface. This increased the worth of the company by one hundred and twenty three million, and sixty-four thousand Dollars ($123,064,000), when a pessimistic oil price of $40/barrel is used. Indeed, it is a cost effective oil recovery mechanism with little or no investment cost. It is however recommended to inject water in the range of 1500ppm or lower.