Reinjection of produced gas is a well-known technique of enhanced oil recovery. In offshore fields, the production units do not always have the proper infrastructure to export the produced gas to shore. In these cases, if the gas volumes are too high, reinjecting it into the reservoir may require elevated flow rates, increasing the risk of mechanical failures due to flow induced vibration on the well completion equipment. This problem may be even more critical in the case of injector wells with intelligent completion systems, which are monitored and controlled with the aid of electrical and optical cables running along the injection tubing. In many instances, to avoid fatigue damage in the intelligent completion equipment, the production unit has to be restricted to allowable rates. This work focus on the problem of flow induced vibration in injector wells equipped with intelligent completion systems. A real well has been modeled in order to perform computational fluid dynamic analysis and understand the turbulent flow near the discharge of the downhole inflow control valves. The problem was modeled using both the Averaged-Reynolds Navier-Stokes and Large Eddy Scale turbulent models. In the first, the flow is stationary and the variables are time-averaged. In the second model, transient analysis is performed considering only the large length scales. Combining the two models, the amplitudes and frequency spectra of the dynamic forces that excite the components of the injector well are estimated. In the case studied, a well with tubing of 4 1/2´´ in a 9 5/8´´ casing and with a maximum nominal gas injection flow rate of 4.5 x 10(6) m(3)/d, the dynamical loads on the critical intelligent completion components were estimated presenting amplitudes of the order of 10 N/m and frequency ranges up to 150 Hz, values that were considered safe for the operation of the analyzed well. The methodology developed in this work can be extended to model other configurations of high flow rate injector wells.