The topic to be discussed involves a conventional oil reservoir undergoing a horizontal waterflood evaluation to increase production rates and overall recovery. The EOR scheme to be employed has been used in vertical wells in the area, and the switch to horizontal wells comes with the challenge of ensuring equal distribution of water along the horizontal well path. With the thin pay reservoir bearing heavier oil, the challenge of the flood was fingering through the permeable formation. A standard completion with 30 sets of perforations was run, and an inner injection liner was designed, with the help of a numerical simulator, and deployed with flow control devices to distribute the water across the length of the horizontal. The goal of the completion was to delay water fingering as much as possible to allow for increased oil production rates and ultimate recovery and, after six months of water injection, an injection log was performed to determine design performance.
This presentation will compare the initial injection wellbore model versus the actual performance six months after installation. The presentation will also include a discussion of lessons learned, opportunities for improvement, and plans for the next installation.