Inversion of Distributed-Temperature-Sensing Logs To Measure Zonal Coverage During and After Wellbore Treatments With Coiled Tubing
- Philippe M.J. Tardy (Schlumberger) | Pierre Ramondenc (Schlumberger) | Xiaowei Weng (Schlumberger) | Rex Burgos (Schlumberger) | Fernando Baez (Schlumberger) | Kaveh Yekta Ganjeh (Schlumberger)
- Document ID
- Society of Petroleum Engineers
- SPE Production & Operations
- Publication Date
- February 2012
- Document Type
- Journal Paper
- 78 - 86
- 2012. Society of Petroleum Engineers
- 5.1.5 Geologic Modeling, 3.2.4 Acidising, 5.6.11 Reservoir monitoring with permanent sensors, 5.8.7 Carbonate Reservoir, 4.1.2 Separation and Treating
- DTS, Coiled-Tubing, Matrix Acidizing
- 5 in the last 30 days
- 800 since 2007
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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.
|File Size||1 MB||Number of Pages||9|
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