Estimating flow rate distribution along the depth in the wellbore is very important for reservoir and production management purposes, because it provides information for distinction of the production rates from different layers. This is critical for optimizing well performance and maximizing recovery of reserves. The temperature and pressure sensors in the well are small and inexpensive, while flowmeters are cumbersome and expensive, and affect the flow in the well. In this study, a mathematical model for pressure and temperature profiles along a gas well has been developed, which is readily used for prediction of flow rates in different layers. Temperature and pressure measurements from gas well in field C (Australia) have been matched with the mathematical model to determine the flow rates from different layers in the well. The proposed model considers the variables as functions of thermal properties at different depth, which is more accurate than previous methods. A simple and effective method is developed for fast estimation of rate distribution along the depth. The proposed approach has been applied to field case for determining gas flow rate in the wellbore and thermal conductivity of the formation from the acquired pressure and temperature data. It allows for recommending well stimulation of layers with low production rate.

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