How To Submersible Well Pump Installation

The electrical submersible pump, typically called an ESP, is an efficient and reliable artificial-lift method for lifting moderate to high volumes of fluids from wellbores. These volumes range from a low of 150 B/D to as much as 150,000 B/D (24 to 24,600 thou^three/d). Variable-speed controllers tin can extend this range significantly, both on the loftier and low side. The ESP's main components include:

• Multistaged centrifugal pump
• Three-phase induction motor
• Seal-sleeping accommodation department
• Power cable
• Surface controls

The components are normally tubing hung from the wellhead with the pump on acme and the motor fastened beneath. There are special applications in which this configuration is inverted.

Every bit area in which ESPs are applied extensively, THUMS Long Beach Co. was formed in April 1965 to drill, develop, and produce the vi,479-acre Long Beach unit in Wilmington field, Long Beach, California. ESPs take been the primary method of lifting fluids from the approximately 1,100 deviated wells from four man-made offshore islands and one onshore site.

History of ESPs^{[one] [two]}

In 1911, eighteen-twelvemonth-erstwhile Armais Arutunoff organized the Russian Electrical Dynamo of Arutunoff Co. in Ekaterinoslav, Russian federation, and invented the first electrical motor that would operate in water. During World State of war I, Arutunoff combined his motor with a drill. It had limited utilise to drill horizontal holes between trenches so that explosives could exist pushed through. In 1916, he redesigned a centrifugal pump to be coupled to his motor for dewatering mines and ships. In 1919, he immigrated to Berlin and changed the name of his company to REDA. In 1923, he immigrated to the United States and began looking for backers for his equipment. Initially, he approached Westinghouse simply was turned down because their engineers idea it would non work because it was impossible under the laws of electronics.

In 1926, at the American Petroleum Found (API) briefing in Los Angeles, two parties joined together to showtime the ESP manufacture. But earlier this conference, Arutunoff had joined forces with Samual VanWert, a sucker-rod salesman who saw the potential of the new device. Together, they initiated a prototype test in a Baldwin Hills oil well. The 2d party involved Clyde Alexander, a vice president of a 9-yr-old Bartlesville, Oklahoma, oil company—Phillips Oil Co. He was at the conference to await for ways of lifting oil from wells that besides required producing big amounts of water. Arutunoff and Phillips signed a contract to field test the concept in the El Dorado field about Burns, Kansas. After a successful exam, Bart Mfg. was organized. On 15 March 1930, Phillips sold his rights to Charley Brownish, a Bart stockholder and executive in Marland Oil Co., and Arutunoff. This was the birth of REDA Pump Co. In 1969, REDA merged with TRW Inc., and in 1987, information technology was sold to Camco Intl., which merged with Schlumberger in 1998.

In 1957, a second company was established. This product line started at the Byron Jackson Pump facility in Vernon, California. Byron Jackson was a partitioning of Borg Warner Corp. In 1959, the oilfield production line of Byron Jackson Pump was moved to Tulsa and chop-chop became known as a "BJ" pump. In 1979, it became Centrilift Inc., a subsidiary of Borg Warner Corp., and was moved to Claremore, Oklahoma, in 1980. Just later on the relocation in 1980, Centrilift was sold to Hughes Tool Co. Then, in 1987, Hughes Tool and Baker International merged to go Baker Hughes Inc.

In 1962, Goulds Pump Oil Field Submergible Division approached Franklin Electric to detect a better motor for their oilfield-pump production. By 1967, they had designed a new production and had formed a articulation venture visitor, Oil Dynamics Inc. (ODI). In 1997, ODI was sold to Baker Hughes Inc., and its product line was merged into Centrilift's.

The story behind the third company becomes a little more than convoluted. In 1965, Hydrodynamics was formed as a part of Peerless Pump to develop an oilfield submersible product. Afterwards express financial success, it was sold to FMC Corp. and renamed Oiline. In 1976, it was sold again, this time to Kobe, and became Kobe Oiline. Kobe was sold to Trico in 1983, simply the Kobe Oiline product was spun off to Baker International, and it became Bakerlift Systems. Trico had also just purchased the Standard Pump water-well line from REDA. A side branch to this tree starts with the emergence of Western Technologies in 1978. It was sold to Dresser Industries and renamed WesTech in 1982. And so, in 1985, information technology was sold to Bakerlift Systems. When Bakery International and Hughes merged in 1987, the US operation of Bakerlift was divested and sold to Trico, only Baker Hughes retained the international segment of the Bakerlift business. Trico's product line was fabricated up of equipment from Kobe Oiline, Standard Pump, WesTech, and Bakerlift Systems. It was renamed Trico Sub Services. On another side branch, ESP Inc. was formed in 1983. Wood Group purchased it in 1990. So, in 1992, Trico Sub Services was purchased by Wood Grouping and was merged into ESP Inc.

ESP arrangement

Examples of normal ESP organization configuration are shown in Figs. 1 and 2. It shows a tubing-hung unit with the downhole components comprising of:

• A multistage centrifugal pump with either an integral intake or separate, bolt-on intake
• A seal-sleeping accommodation department
• A three-phase induction motor, with or without a sensor package

The balance of the organization includes a surface control package and a iii-phase ability cablevision running downhole to the motor. Considering of the ESP's unique application requirement in deep, relatively minor-diameter casings, the equipment designer and manufacturer are required to maximize the lift of the pump and the power output of the motor as a part of the diameter and length of the unit. Therefore, the equipment is typically long and slender. The components are manufactured in varying lengths up to approximately 30 ft, and for certain applications, either the pump, seal, or motor tin be multiple components continued in series.

• 

  Fig. i-ESP system configuration [after Centrilift Graphics, Claremore, Oklahoma (2003)].

• 

  Fig. 2—Schematic of typical ESP system. [Courtesy of Schlumberger (REDA).]

Throughout their history, ESP systems take been used to pump a multifariousness of fluids. Normally, the production fluids are crude oil and alkali, but they may exist chosen on to handle:

• Liquid petroleum products
• Disposal or injection fluids
• Fluids containing costless gas
• Some solids or contaminates
• CO₂ and H₂S gases or handling chemicals

ESP systems are also environmentally esthetic considering only the surface power control equipment and power cable run from the controller to the wellhead are visible. The controller can exist provided in a weatherproof, outdoor version or an indoor version for placement in a edifice or container. The control equipment tin can exist located within the minimum recommended altitude from the wellhead or, if necessary, up to several miles abroad. API RP11S3 provides the guidelines for the proper installation and handling of an ESP system. ^[3] All the API recommended practices for ESPs are listed in Table 1.

• 

  Table 1

Advantages

ESPs provide a number of advantages.

• Adaptable to highly deviated wells; up to horizontal, but must be fix in straight section.
• Adaptable to required subsurface wellheads six ft apart for maximum surface-location density.
• Permit utilise of minimum infinite for subsurface controls and associated production facilities.
• Quiet, safe, and sanitary for adequate operations in an offshore and environmentally witting area.
• Generally considered a loftier-volume pump.
• Provides for increased volumes and water cuts brought on past pressure maintenance and secondary recovery operations.
• Permits placing wells on product even while drilling and working over wells in firsthand vicinity.
• Applicable in a range of harsh environments.

Disadvantages

ESPs accept some disadvantages that must be considered.

• Volition tolerate just minimal percentages of solids (sand) production, although special pumps with hardened surfaces and bearings exist to minimize article of clothing and increase run life.
• Costly pulling operations and lost product occur when correcting downhole failures, especially in an offshore environment.
• Below approximately 400 B/D, power efficiency drops sharply; ESPs are non peculiarly adaptable to rates below 150 B/D.
• Need relatively large (greater than 4½-in. outside diameter) casing size for the moderate- to loftier-production-rate equipment.

Long life of ESP equipment is required to go along production economical.

Components of an ESP system

• ESP centrifugal pump
• ESP seal section
• ESP motors
• ESP ability cable
• ESP surface motor controllers
• ESP optional components

Installation and treatment

Although in that location tin exist many factors that influence or directly affect the run-life of an ESP system, proper installation and handling procedures are critical. The recommended installation and treatment procedures are detailed in API RP11S3. ^[3] In addition to these, manufacturers should be contacted for specific recommendations on their equipment.

Maintenance and troubleshooting

Operating, maintenance, and troubleshooting recommendations are covered in API RP11S. ^[four] Additionally, much can be learned from the disassembly of the ESP components after they are pulled from the well. This is true whether they are in reusable condition or take been through a catastrophic failure. The equipment and the wellbore e'er bespeak items that tin can be changed or improved. API RP11S1 provides guidelines on the disassembly of ESP components and the evaluation of the findings. ^[5] Also, each ESP manufacturer has recommendations and guidelines on this topic.

Baillie^{[half dozen]} provides a practical checklist for optimizing the life of an ESP system. It covers all the critical or sensitive steps, from the design and manufacture to the operational procedures. At that place accept been several papers written that deal with literature on ESP application issues and solutions. ^{[7] [8] [9] [10]} These papers summarize and categorize ESP reference literature by a number of different application or trouble topics. They are an splendid bibliography prepare for troubleshooting application-related problems or issues.

References

1. ↑ Williams, J. 1980. A Story of People and a Company Called TRW REDA, 19-33. Bartlesville, Oklahoma: TRW REDA Pump Div.
2. ↑ Brookbank, E.B. 1988. Electric Submersible Pumps—The First Threescore Years. Paper presented at the 1988 European ESP Workshop, London, 24 May.
3. ↑ ^{three.0 three.one} API RP 11S3, Recommended Practise for Electrical Submersible Pump Installations, second edition. 1999. Washington, DC: API.
4. ↑ API RP 11S, Recommended Exercise for the Operation, Maintenance, and Troubleshooting of Electric Submersible Pumps, third edition. 1997. Washington,DC: API.
5. ↑ API RP 11S1, Recommended Do for Electrical Submersible Pump Teardown Report, 3rd edition. 1997. Washington, DC: API.
6. ↑ Baillie, A. 2002. Optimizing ESP Run Life—A Practical Checklist. Paper presented at the 2002 European ESP Roundtable, Aberdeen, 6 February.
7. ↑ Lea, J.F., Wells, Thou.R., Bearden, J.Fifty. et al. 1994. Electrical Submersible Pumps: On and Offshore Problems and Solutions. Presented at the International Petroleum Conference and Exhibition of Mexico, Veracruz, United mexican states, ten-xiii October 1994. SPE-28694-MS. http://dx.doi.org/10.2118/28694-MS
8. ↑ Lea, J.F., Wells, M.R., Bearden, J.L. et al. 1994. Electrical Submersible Pumps: On and Offshore Problems and Solutions. Presented at the International Petroleum Conference and Exhibition of Mexico, Veracruz, United mexican states, 10-13 October 1994. SPE-28694-MS. http://dx.doi.org/10.2118/28694-MS
9. ↑ Lea, J.F. and Bearden, J.L. 1999. ESP'due south: On and Offshore Problems and Solutions. Presented at the SPE Mid-Continent Operations Symposium, Oklahoma Metropolis, Oklahoma, 28-31 March 1999. SPE-52159-MS. http://dx.doi.org/10.2118/52159-MS
10. ↑ Lea, J. and Bearden, J. 2002. ESP's: On and Offshore Problems and Solutions. Paper presented at the 2002 Southwestern Petroleum Short Course Conference, Lubbock, Texas, 23–24 April.

Noteworthy papers in OnePetro

Lea, J. F., Wells, One thousand. R., Bearden, J. L., Wilson, Fifty., & Shepler, R. (1994, Jan 1). Electric Submersible Pumps: On and Offshore Problems and Solutions. Society of Petroleum Engineers. doi:10.2118/28694-MS

Powers, M. L. (1994, May one). The Depth Constraint of Electrical Submersible Pumps. Society of Petroleum Engineers. doi:10.2118/24835-PA

Scott, P. A., Bowring, K., & Coleman, B. (1991, January 1). Electrical Submersible Pumps in Subsea Completions. Club of Petroleum Engineers. doi:x.2118/23050-MS

Online multimedia

Noonan, Shauna. 2022. Electrical Submersible Pump (ESP) Reliability. https://webevents.spe.org/products/electrical-submersible-pump-esp-reliability

External links

Use this section to provide links to relevant textile on websites other than PetroWiki and OnePetro

See also

Alternating ESP configurations

Use of ESPs in harsh environments

ESP system selection and performance calculations

PEH:Electrical_Submersible_Pumps

Page champions

Jose Caridad, BSME & MSc ME

Category

Source: https://petrowiki.spe.org/Electrical_submersible_pumps

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