Distributed temperature sensing (DTS) based on fiber-optics has successfully been applied for injection monitoring, see e.g. [1, 2], as well as production monitoring, see e.g. [3]. In the current paper we combine a transient well flow model and the ensemble Kalman filter into a tool for interpretation of high frequency downhole temperature measurements. Our case study clearly demonstrates the feasibility of automatic identification of reservoir influx distribution from temperature measurements.

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