SPE Production & Operations
Volume 27, Number 1, February 2012, pp. 52-66

SPE-128003-PA

From Operations to Desktop Analysis to Field Implementation: Well and ESP Optimization for Production Enhancement in the Cliff Head Field

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DOI  More information 10.2118/128003-PA http://dx.doi.org/10.2118/128003-PA

Citation

  • Dholkawala, Z.F., Daniel, S., and Billingsley, B. 2012. From Operations to Desktop Analysis to Field Implementation: Well and ESP Optimization for Production Enhancement in the Cliff Head Field. SPE Prod & Oper  27 (1): 52-66. SPE-128003-PA. http://dx.doi.org/10.2118/128003-PA.

Discipline Categories

  • 5.2.2 Electric Submersible Pumps
  • 5.3 Production Enhancement
  • 5.1.4 Monitoring and Control

Keywords

  • ESP optimization, interaction with well and reservoir performance

Summary

Understanding the integrated performance of complex artificially lifted wells on not normally manned (NNM), offshore platforms without invasive techniques represents a challenge not only to minimizing operating costs but also to optimizing production and thereby maximizing value. Often the analysis of such problems is hindered by the complex interactions between identified production constraints and by a lack of operating data.

The Cliff Head oil field (offshore Western Australia) is developed with an innovative coiled-tubing deployed-electrical-submersible-pump (CT-ESP) artificial-lift system. This paper describes the process by which ESP and well data, in conjunction with a well-performance-modeling software, have been used as a powerful tool to diagnose well-performance issues and optimize production. Production trends were created on the basis of real-time production data to understand ESP performance. Individual-well models were created to identify potential causes of declining performance--in this case, the use of an ESP performance-limiting factor (PLF) indicating deteriorating ESP performance because of solids buildup.

On the basis of the model results, chemical soaks were implemented on two production wells to remove flow restrictions within and around the ESPs. The treatments increased the oil-production rates by 17 to 48%.

Following a debottlenecking study, reservoir simulation in combination with detailed ESP-performance analysis concluded that total-field-production improvements of up to 50% were possible. Consequently, the next phase of field development will install larger-capacity ESPs.

This paper outlines how field data and desktop tools were combined successfully to monitor and diagnose well-performance issues to deliver material production enhancements.

© 2012. Society of Petroleum Engineers

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History

  • Original manuscript received: 22 March 2010
  • Meeting paper published: 14 February 2010
  • Revised manuscript received: 11 October 2010
  • Manuscript approved: 1 November 2010
  • Published online: 16 February 2012
  • Version of record: 28 February 2012