In February 2003 BP installed the first coiled-tubing deployed electric submersible pump in the Gulf of Mexico. The Grand Isle 40 F-1 well had been producing for several years with 27/8" jointed tubing, and the two previous electric submersible pumps lasted 16 and 30 months. Once the ESP failed, the well was produced at a much lower rate using gas lift for another 11 months or more until the ESP replacement could be scheduled and executed. The project discussed in this paper utilized a rig to replace the entire 9,700’ of production tubing with a 2-3/8" coil string that had the ESP at the bottom. The benefits of this deployment method include a reduction in the down time between pump change outs and a reduction in project cost. When the ESP fails, a liftboat and coiled tubing unit can be mobilized sooner, and at a lower cost, than a rig. The added cost of this first coil installation will pay out with the first rig-less pump replacement.

The goals of the paper are to document this successful case study and to illustrate the value that CT-ESP has in the Gulf of Mexico offshore operating environment. We start with a history of CT-ESP's installed elsewhere, and then discuss our well and why it was a candidate for a coil-deployed ESP. We then discuss our rationale for running the 2-3/8" diameter coil instead of other available sizes, and why we decided to run the cable external to the production string. Pre-job planning, regulatory issues, HS&E and equipment testing will also be addressed. Additionally, key elements of the operation, and the procedure to terminate and test the coil while running in the hole are presented. The conclusion will detail some of the lessons learned during the operation and the overall project economics.

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