In order to optimize production of a SAGD process many strategies have been adopted. These strategies may include; a Dual-Tubing completion which contains short and long tubing strings to inject steam in to the reservoir, Proportional-Integral-Derivative (PID) to control steam injection, flow control devices (FCDs), and others. In all these methods; operators try to maximize ultimate recovery by increasing thermal communication between well pairs, enhancing steam conformance, and improving oil displacement efficiency. Currently flow control devices (FCDs) are widely used in thermal operations. This tool can be installed on both production and injection wells in a SAGD well pair. The FCD tool in an injection well is also known as a steam splitter, which gives the operator the opportunity to target sections of the wellbore to receive steam. In a production well, FCDs are used to develop a uniform inflow along the horizontal section of the wellbore. This helps in managing the interface between the injection and production wells to maximize the productivity. The effects of orifice type FCD properties on a SAGD process have not yet been investigated. These properties include port (orifice) size and port quantities. Locations of FCDs in both injector and producer are another important parameter that needs to be addressed and optimized in a SAGD operation. This paper investigates the impact of each of these FCDs properties along with the location of FCDs on a SAGD process through coupled wellbore-reservoir modeling. In addition; a detailed study is carried out to present a workflow for the FCD optimization that can help engineers to design FCDs in both injector and producer in a SAGD well pair.
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