Rigless Multi-zone Recompletion Using a Cement Packer Placed with Coiled Tubing: A Case History
- T.W. Nowak (Chevron USA Production Company) | T.S. Patout (Dowell)
- Document ID
- Society of Petroleum Engineers
- SPE Drilling & Completion
- Publication Date
- December 1997
- Document Type
- Journal Paper
- 244 - 248
- 1997. Society of Petroleum Engineers
- 2.4.5 Gravel pack design & evaluation, 5.7 Reserves Evaluation, 2.4.3 Sand/Solids Control, 2.2.2 Perforating, 3 Production and Well Operations, 4.3.4 Scale, 1.6 Drilling Operations, 1.14 Casing and Cementing, 4.1.2 Separation and Treating, 2.7.1 Completion Fluids, 1.10 Drilling Equipment, 1.14.3 Cement Formulation (Chemistry, Properties)
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Cement packers have been utilized for some time when reserve estimates have not justified the cost of major rig remedial work. They typically provide a means of zonal isolation of the last reserves in an existing wellbore. The success of these operations has historically been low. This is predominantly due to poor cement bonding in the annulus between the tubing and production casing. Due to the minimal amount of equipment on location and lack of upfront design work involved, most cement packers are doomed to failure before they are even placed. Cement packers have been placed utilizing a large number of methods. In the Ship Shoal 181 field, the No. B-4 well would not economically justify a major rig workover, even though there were several uphole gas sands capable of producing in this well. With proper upfront planning and design, it would be economic however, if all these reserves could be produced in a through tubing process utilizing a cement packer.
This case history presents a refined look at existing technology involving placement of a cement packer and reviews problems common to cement packer completions including a case history. Also discussed are the solutions for successfully completing and recovering reserves from not one but several remaining gas intervals. The following reviews the design considerations and precautions taken to place what is believed to be the largest cement packer placed through coiled tubing along with the production results and economics.
The Ship Shoal 181 No. B-4 completion was originally intended to produce several uphole stacked gas sands through a major rig workover. (See Figure 1) After reviewing 3-D seismic data, that was not available at the initial completion, it was determined that the cost involved in performing a major rig workover would be better utilized on other projects within the field. The remaining recoverable reserves in the B-4 consisted of several stacked gas sands, each estimated at producing 0.3 to 0.5 BCF of gas. The multi-discipline field management team concluded that the only profitable means to recover the existing reserves in this wellbore would be achieved through a rigless recompletion utilizing a cement packer. There were six possible productive intervals. Although four or fewer of the zones would probably be tested for production in this well, the intervals spanned 1000' of interval that would need to be covered by the cement packer. It would be necessary to place an 80 barrel slurry in the large 9-5/8" casing by 2-7/8" tubing annulus to cover and effectively pressure isolate each of these intervals. (See Figure 2)
Inherent to this problem was the inability to provide a consistent cement slurry to the coiled tubing unit as well as the large volume of slurry necessary to achieve a competent bond between the tubing and casing throughout the desired interval. Described below is a method to minimize the risk associated with these problems as illustrated through a successful case history.
|File Size||498 KB||Number of Pages||5|