This article, written by Assistant Technology Editor Karen Bybee, contains highlights of paper SPE 94039, "Cementing a Long Horizontal Wellbore Using CT Squeeze Technology," by W. Rauchenstein and C.G. Blount, SPE, ConocoPhillips Alaska Inc., prepared for the 2005 SPE/ICoTA Coiled Tubing Conference and Exhibition, The Woodlands, Texas, 12-13 April. Coiled-tubing (CT) cementing has been used widely and has been highly successful for remedial squeeze and plugback operations for more than 20 years. However, most of these wells had deviations less than 90°. A long horizontal well in the Alpine field on the North Slope of Alaska was drilled early in the development phase and was out of pattern. The well required a plugback and sidetracking to maintain desired off-take strategy. On the basis of the successful CT squeeze program in Alaska, the decision was made to use CT cement-squeeze technology to seal the lateral portion of the wellbore and leave a cement base for subsequent sidetracking operations. Field Overview The Alpine field is in the Colville River delta a few miles south of the Arctic Ocean and approximately 70 miles west of the TransAlaska Pipeline. The facilities are connected to the North Slope road system by ice road for approximately 3 months of the year. Aircraft provide the only mode of transportation at other times. As a result of the depositional environment and minor fault offset, excellent vertical permeability is observed, and the productive sands are pressure connected across large distances. A water-alternating-miscible-gasflood is being conducted in the Alpine reservoir. The field is developed with line-drive patterns, using horizontal producers and injectors in a one-to-one ratio. Given the high mechanical strength of the clean fine-grained Alpine sandstones, the operator elected to leave the horizontal sections of the wellbore uncased, to minimize the chance of formation damage. A 7-in. intermediate casing shoe is set just below the top of the producing formations at high angle. The uncased horizontal production hole typically extends 3,000 to 4,000 ft beyond the intermediate casing shoe. Production and injection tubing is primarily 4½ in., although some lower-rate wells are completed with 3½-in. tubing. While performing above expectations, this completion practice has proved to be a difficult environment to access. Early attempts at logging these wells using CT memory tools and conductor-line tractors provided less than ideal results in reaching the total depth (TD) in the extended horizontal openhole sections. Drilling and formation debris and abrasive formations combined with wellbore geometry limited the ability to reach the full measured depth (MD) of the lateral sections. Portions of openhole lateral sections with fill or debris are not the only potential challenge to successfully cementing these wells; recent caliper logs suggest that the wells also may have sections that are washed out or significantly out of gauge.