This article, written by Assistant Technology Editor Karen Bybee, contains highlights of paper SPE 92255, "Use of Advanced Completion Solutions to Maximize Reservoir Potential - Experiences in the Snorre Field," by L.T. Skarsholt, SPE, A.F. Mitchell, and A.H. Bjornsgaard, SPE, Statoil ASA, prepared for the 2005 SPE/IADC Drilling Conference, Amsterdam, 23-25 February. Snorre Blocks 34/4 and 34/7 were the first in the Norwegian North Sea to have sur-face-operated zonal control installed to allow selective production from different sections of the reservoir. The concept of downhole instrumentation and control systems (DIACSs) has been further developed and refined and today is used by many operators. The Snorre field remains at the forefront of this development, and the technology has been used in an additional 17 wells across the field. The full-length paper focuses on the use and advantages of advanced completions. Introduction The Snorre field, operated by Statoil ASA, is in Blocks 34/4 and 34/7 of the Norwegian North Sea, approximately 150 km northwest of Bergen. Snorre A, which started production in 1992, consists of a tension-leg platform and a subsea production system in a water depth of approximately 350 m. Produced oil is exported to Statfjord A, while part of the gas is reinjected and part is exported to Statfjord A. As of November 2004, Snorre A consisted of 30 oil producers and 23 injectors, including subsea wells. Snorre B, which came on stream in June 2001, is a semisubmersible drilling, process, and accommodation platform. Oil is exported to Statfjord B, and the produced water and gas are reinjected. Currently, six production wells and three injectors are connected to Snorre B. The Snorre field is a complex reservoir consisting of fluvial sandstones representing various fluvial styles and subfacies. The lateral extent of the channel belts varies from 300 m to several kilometers and the permeability from a few hundred millidarcies to several darcies. The channel belts are stacked and interbedded with mudstone, and under dynamic flowing conditions, several pressure regimes have been developed because of the limited vertical and lateral communication. It was originally planned that the undersaturated oil would be recovered with downdip water injection as the drive mechanism, but this was changed at an early stage to water-alternating-gas (WAG) injection to improve oil recovery as well as provide a method to use excess gas. As of November 2004, the Snorre field had an expected stock-tank oil originally in place of 532×106 m3, with expected oil reserves of 242×106 m3.