Inversion of DTS Logs To Measure Zonal Coverage During and After Wellbore Treatments With Coiled Tubing

Abstract

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 mostly been 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.

Estimating reliable gas rate with transient-temperature modeling for interpreting early-time cleanup data during transient testing

“…Duru and Horne (2010) made use of DTS data for estimating formation parameters, such as permeability and porosity, among others, during transient testing. Muradov and Davies (2011), Li et al (2011), andTardy et al (2012), among others, demonstrated the use of distributed measurements in zonal contribution assessment in horizontal wells. The coupled nature of fluid and heat flows in transient testing of gas wells has been the subject of many studies.…”