Productivity Determination and Pump Resizing Using Variable-Speed Electric Submersible Pumps
- Robert S. Kelley (Amoco Production Co.)
- Document ID
- Society of Petroleum Engineers
- Journal of Petroleum Technology
- Publication Date
- September 1980
- Document Type
- Journal Paper
- 1,503 - 1,508
- 1980. Society of Petroleum Engineers
- 5.6.8 Well Performance Monitoring, Inflow Performance, 5.6.4 Drillstem/Well Testing, 3.1.2 Electric Submersible Pumps, 3.1 Artificial Lift Systems, 1.10.1 Drill string components and drilling tools (tubulars, jars, subs, stabilisers, reamers, etc), 1.6 Drilling Operations, 2.2.2 Perforating, 5.4.1 Waterflooding
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This paper discusses a variable-speed electric submersible pump system used as a tool to provide productivity information for resizing electric submersible pumps. Use of this equipment enabled the generation of productivity information without having to pull the existing downhole equipment. Field results using this method are presented.
Waterflood expansion and developmental drilling programs are being pursued actively in the Lost Soldier Tensleep reservoir in central Wyoming. Response to the increased injection has resulted in frequent resizing to larger artificial lift equipment. As new injection wells are drilled and existing wells converted to injection to complete the pattern flood, adjacent areas are experiencing significant increases in static and operating bottomhole pressures. To handle the increased fluid withdrawals possible, the majority of producing wells are being changed from beam to electric submersible pump (ESP) lift and existing ESP's are being resized.
The production of ESP-pumped wells in the Lost Soldier Tensleep reservoir ranges from 400 to 6,200 BFPD (64 to 986 m3/d fluid). Average depth of the reservoir is 5,000 ft (1524 m). Producing-well bottomhole temperature is approximately 175 degrees F (79 degrees C). ESP lift plays an important role in this reservoir. At the end of 1978, 31 well, or 61% of all producing wells, were on ESP lift. These wells account for 87% of the total fluid produced. During the year there were 10 new ESP installations and 14 ESP installations that were resized. It has been found that traditional methods of predicting productivity characteristics for ESP sizing cannot be used in all cases. Several different size installations have been required in some wells before an acceptable operating fluid level has been achieved.
As a solution to reducing the uncertainty in sizing ESP's, a variable-speed electric submersible pump (VSESP) was employed. By varying the frequency to the downhole motor, it is possible to increase fluid production without pulling the existing downhole equipment. This paper discusses the results obtained by using this equipment on two Lost Soldier Tensleep wells.
Resizing still will be necessary as response to injection is seen in certain areas. However, once it has been determined that a resize is justified economically, the VSESP can be used as a tool to aid with sizing for the existing conditions. Other applications for this equipment also exist. A third well tested is discussed briefly because it resulted in a further application.
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