When modeling fractured horizontal wells with longitudinal fractures, simplified methods are currently used. They do not take into account the change in the reservoir stress-strain state caused by hydraulic fractures of previous stages. The most important task is to improve hydraulic fracturing modeling methods. Therefore, this work objective is to compare the results of hydraulic fracture geometry field studies with the results of modeling multi-fractured horizontal wells with wellbores drilled in the maximum horizontal reservoir stress direction, accounting for changes in the pre-fractured reservoir stress-strain state. Data on hydraulic fracture propagation in rocks, obtained from the results of borehole microseismic monitoring, is currently of particular interest due to the lack of alternatives among the methods for monitoring the hydraulic fracture geometry in horizontal wells. The paper presents the microseismic study results of a multi-fractured horizontal well, located in one of the large fields of Western Siberia. Microseismic monitoring data was used to be compared with the results of mathematical modeling of multi-stage hydrofracturing in horizontal wells in the hydraulic fracturing simulator RN-GRID. The fracture geometry calculations took into account changes in the reservoir stress state from the previous fracturing stages. It is demonstrated that the proppant distribution in the subsequent hydraulic fracturing stages relative to the frac ports position is almost always laterally asymmetrical. In addition, there is a risk of hydraulic fracture breakthrough, which is not predicted by simulators taking no account of the local change in the reservoir stress-strain state from previous stages. It is shown that the results of hydrofracturing microseismic monitoring can be used to improve hydraulic fracturing designs and reservoir engineering.
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