TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractThis paper will outline the history, and operation of a Through-Tubing selective injection tool used for the purpose of water shutoffs. This tool is an inflatable, re-settable, coiled tubing-conveyed straddle packer assembly designed to run through production tubing and isolate a portion of perforated, screened, slotted, or open hole allowing precise placement of water blocking chemicals, Acidizing, or chemical fluids.The paper will include a description of 18 field runs of this tool used for water blocking chemicals from 1995 through October 1999 and will examine the 3 case histories listed below in more detail: 1. Through-Tubing selective water shut-off polymer job through casing perforations with a single packer 2. Through-Tubing selective water shut-off polymer job of an intermediate zone in 4.5" casing 3. Through-Tubing selective water shut-off polymer job of an intermediate zone in 3.5" screen linerSpacing of Straddle Packers 49 ft. Figure 134746 ft. 4790 ft.
TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractThis paper discusses the advantages that accrue to remedial operations as a result of using coiled tubing to enable the fast and safe removal of the latest-generation composite bridge plugs in an underbalanced environment. The paper addresses the development and early field history of latest-generation composite bridge plugs, which are designed to set securely in the casing and then be easily removed using coiled-tubingconveyed downhole motors and drilling tools in an underbalanced environment after remedial operations are complete.The new technology is particularly applicable in multizone, commingled gas wells with varying bottom-hole pressure, where there is a need to reduce overall operator expense and minimize formation damage, without compromising reliability of safety.Field experience verifies that a reliable and easily removable composite bridge plug requires substantially less rig time than conventional cast iron bridge plugs while at the same time reducing formation damage. These benefits result from the ability of coiled tubing conveyance to eliminate the need for kill weigh fluid and to enable the well to be worked over "live".The paper includes a listing with brief descriptions of more than 100 field runs to date for zonal isolation and treatment using this new technology (see Figure 1). It also examines in detail the following two case histories: 1.Phillips Davis Lease Well #8 in Louisiana's Webster Parish 2. Marathon's J. Kaye Field Well #3-33 in Oklahoma's Grady County.
This paper was prepared for presentation at the 1999 SPE/ICoTA Coiled Tubing Roundtable held in Houston, Texas, 25–26 May 1999.
TX 75083-3336, U. S:A., fax 01-972-952-9435. AbstractThis paper outlines the history, deployment into a live well, and operation of a through-tubing selective injection tool. This tool is an inflatable, re-settable, coiled tubing-conveyed straddle packer assembly designed to run through production tubing and isolate a portion of perforated casing to allow precise injection of stimulation or water block chemicals.
Increased production and lower costs in shallow gas wells are closely linked to developing and refining new coiled-tubing drilling, completion, and production techniques. Innovations in coiled tubing have reduced the costs of drilling and completing these wells and increased their productivity and life cycles. Coiled-tubing fracturing is one such innovation. This has been used for some time now, predominantly in North American shallow gas wells. In these wells, the cost advantages associated with working over the well in a live condition while reducing job time are attractive. Coiled-tubing fracturing operations usually employ straddle-type tool configurations. However, with a typical maximum lubricator length of about 30 ft, straddle interval lengths have been restricted, which increases the amount of resets required to effectively fracture individual zones. This restriction also increases the potential risk of communication above the assembly. This paper describes the development of an economical and reliable coiled-tubing fracturing system that allows selective fracturing of previously bypassed pay zones. This is now possible because the system can be conveyed in a tandem configuration that works within current lubricator restrictions, but is capable of setting repeatedly as a retrievable bridge plug and treating packer combination. This allows longer zones to be precisely isolated multiple times in a single trip in hole. This innovative technique can not only reduce intervention costs but also reduce the total time required to complete the operation. This paper examines a case history, with emphasis on pre-job planning, equipment selection, wellsite execution and post-job results. Introduction A recently developed coiled-tubing fracturing system gives the operator an alternative to conventional completion techniques. Using coiled-tubing fracturing and a tandem tool configuration, the system allows the cost-effective completion of zones of interest previously regarded as uneconomical. These tools are run as a retrievable bridge plug and treating packer combination on coiled tubing, which allows the system to be set downhole in varying intervals repeatedly. The benefits of this new system in shallow to intermediate gas wells include:Multiple zones of any interval length can be isolated and stimulated efficiently and economically;Total completion time can be greatly reduced compared to conventional methods;Production results are improved over conventional methods that require kill-weight fluids. Completion Techniques The most common completion technique for shallow gas zones involves a rig-assisted plug and packer system conveyed on threaded pipe. Normally, these zones of interest would be completed as either a re-entry or workover procedure. Perforation and stimulation of multiple zones with a standard plug and packer system requires kill-weight fluid to be placed in the wellbore prior to moving up hole and relocating the assembly. This method of completion is time consuming, costly, and can cause formation damage. Stimulation equipment, and in many cases the workover rig itself, must be mobilized for each zone. Newly developed coiled-tubing deployed, fixed-interval straddle systems enable an isolation system to be placed and relocated in a live well. These straddle systems enable multiple zones to be stimulated individually without requiring kill-weight fluids on the formation. This method can greatly reduce the total cost of completion, but it does have problems. If channeling occurs and communication is established above the tools, the treatment of the zone must be suspended. Also, with a typical maximum lubricator length of thirty feet, the length of perforated interval that the tool can isolate is restricted.
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