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• W2088750897 abstract "ABSTRACT This paper will describe how a resettable pump packer was designed and tested for use in the North Sea. A fully reset table packer where the setting forces are locked in can save the operator the cost of a workover in a situation where only minor wellhead repairs are required. The RESETTABLE PUMP PACKER was designed specifically to overcome this problem. It is unset by straight pull release and automatically re-cocks itself to allow for a further setting. It will also totally relax and allow safe manipulation of the string between settings as there is a device to prevent premature resetting INTRODUCTION Since the early 1980's ESP's have been run in the North Sea and their-use and application will increase significantly as the larger fields mature and and new fields come on stream. The packers used in ESP completions are essentially dual packers with the long string commonly 4.1/2 tubing and the short string 2.3/8 tubing which is used to allow passage of the heavy duty power cable. They are hydraulically set and released by straight pull on the tubing. They have, however, suffered from the major drawback that once unset they cannot be reset and must be pulled from the well for replacement. On many occasions, immediately after installation, there have occurred minor mechanical or electrical problems at or near the wellhead. This necessitates raising the tubing string to gain access which, of course, unsets the packer. The operator now has a costly and time consuming trip to perform. Many ESP completions do not include a packer which means that the fluid in the annulus is allowed to find its own level. This practice is not acceptable in the North Sea and so a packer is used to anchor the tubing 'and seal off the annulus. High GOR wells will normally locate the packer near the surface to allow for gas venting. Resettability is not such a strong requirement in gas vented wells as the time taken to pull and re-run a packer to say, 600' is minimal. However, with deep set non-gas vented packers the argument for using a resettable packer is strong as the cost of a workover on an offshore well can exceed one million U.S. dollars. Fig 1 shows a cross section of a typical pump packer. The main string (1) is usually maximised in size and would normally be 4.1/2 OD for a packer set in 9.5/8 casing, 3.1/2 if set in 7.5/8 and 2.7/8 set in 7. The electrical cable string (2) is used to house the electrical penetrator which is normally fed through from the lower end of the packer and sealed off at the top end. A third string is often included and used to attach a pressure/temperature gauge or used for gas venting. Fig 2 illustrates other features such as a chemical injection or instrument line but as packers become multi-stringed there is more potential for things going wrong and hence resettability becomes more attractive." @default.
• W2088750897 created "2016-06-24" @default.
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• W2088750897 date "1992-05-04" @default.
• W2088750897 modified "2023-09-25" @default.
• W2088750897 title "Downhole Packers for Use With ESP Completions" @default.
• W2088750897 doi "https://doi.org/10.4043/7066-ms" @default.
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