The current state of automation of artificial oil lift allows monitoring the operation of downhole equipment in on-line mode on a large well stock from a single monitoring center. This was due to the large-scale introduction of measuring sensors and the development of transmission and storage systems that took place in the last 3-5 years. It turned out that information collected in continuous mode from submersible pressure sensors, which are installed on the intake of the electric centrifugal pump (ESP), can in some cases help with the determination of reservoir parameters: reservoir pressure, permeability, skin factor, and others. Such studies, which do not require special manipulations with the well, were called "passive" or auto wells testing. In this paper, we propose approaches to the development of a "virtual flowmeter" for the purpose of conducting auto well testing. The description of the algorithms that formed the basis of the calculation method for determining the well production rate from indirect data, as well as the results of their testing at various well samples, are described. It is shown that even in the presence of a complete set of initial data, the error in calculating the production rate of the well is about 10% and cannot be significantly reduced because of the errors in the parameter measurements that serve to calculate the production rate.
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