SPE Production & Operations
Volume 27, Number 1, February 2012, pp. 78-86

SPE-143331-PA

Inversion of Distributed-Temperature-Sensing Logs To Measure Zonal Coverage During and After Wellbore Treatments With Coiled Tubing

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DOI  More information 10.2118/143331-PA http://dx.doi.org/10.2118/143331-PA

Citation

  • Tardy, P.M.J., Ramondenc, P., Weng, X., Burgos, R., Baez, F., and Yekta-Ganjeh, K. 2012. Inversion of Distributed-Temperature-Sensing Logs To Measure Zonal Coverage During and After Wellbore Treatments With Coiled Tubing. SPE Prod & Oper  27 (1): 78-86. SPE-143331-PA. http://dx.doi.org/10.2118/143331-PA.

Discipline Categories

  • 5.3.4 Acidizing
  • 5.1.4 Monitoring and Control
  • 5.1.5 Wireline, Coiled Tubing and Telemetry

Keywords

  • Matrix Acidizing, DTS, Coiled-Tubing

Summary

Distributed temperature sensing (DTS) is a fiber-optic technology that provides continuous temperature profiles along the length of a well. When placing the fiber inside a coiled tubing (CT), one can monitor the temperature evolution while pumping as well as during a shut-in period. This evolution, in turn, yields some indications about the fluid-placement performance or zonal coverage. So far, interpretation of such DTS traces has been mostly qualitative. The work presented here demonstrates how DTS data can be used, coupled with an inversion algorithm and a forward model of fluid injection into a reservoir, to quantify the intake profile of treatment fluid along the wellbore. Recent field cases of matrix acidizing treatments in carbonate reservoirs are analyzed to illustrate the workflow and how it may yield valuable information.

© 2012. Society of Petroleum Engineers

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History

  • Original manuscript received: 11 April 2011
  • Meeting paper published: 5 April 2011
  • Revised manuscript received: 20 July 2011
  • Manuscript approved: 27 July 2011
  • Published online: 16 January 2012
  • Version of record: 28 February 2012