The assessment of well modeling quality for wells equipped with electrical submersible pumps operating in periodic short-term operation mode in the OLGA transient flow simulator under limited verified data and restricted telemetry availability

UDK: 622.276.53.054:681.5

DOI: 10.24887/0028-2448-2025-9-66-72

Key words: electrical submersible pump (ESP), periodic short-term operation mode (PSOM), OLGA transient flow simulator, hydrodynamic modeling, gas separator, model adaptation

Authors: E.V. Yudin (Gazprom Neft Companу Group, RF, Saint Petersburg); K.V. Moiseev (Ufa State Petroleum Technological University, RF, Ufa); B.M. Latypov (Ufa State Petroleum Technological University, RF, Ufa); V.A. Shishulin (Gubkin University, RF, Moscow; Research and Education Center Gazprom Neft – UGNTU, RF, Ufa); I.V. Grigorev (Research and Education Center Gazprom Neft – UGNTU, RF, Ufa); I.V. Gavrilov (Research and Education Center Gazprom Neft – UGNTU, RF, Ufa); M.D. Shabunin (Research and Education Center Gazprom Neft – UGNTU, RF, Ufa); A.V. Ryzhikov (Association «Digital technologies in industry», RF, Saint Petersburg); D.V. Usikov (NEDRA LLC, RF, Saint Petersburg)

This paper presents a methodology for modeling wells equipped with electrical submersible pumps (ESP) systems operating in periodic short-term operation mode (PSOM) under conditions of limited verified data and restricted telemetry availability. The research focuses on adapting hydrodynamic models to real field conditions when measurement data is scarce or of low resolution. The study develops a transient hydrodynamic well model using the OLGA flow simulator coupled with a Multiflash thermodynamic fluid model. Special emphasis is placed on creating a methodology for simulating submersible gas separator operation and adapting the model to PSOM conditions. Experimental validation was conducted on a real well of Western Siberian oil field. Key parameters affecting simulation accuracy were identified. Reducing the number of pump stages leads to a significant increase in pump intake pressure with only minor negative impact on flow rate, while increasing the productivity index substantially boosts flow rate with minimal effect on pressure. Particular attention is given to analyzing «gas lock» phenomena and methods for its prevention under PSOM conditions. The paper explores different approaches to mitigate gas accumulation issues, including forced gas removal from behind the casing and redirection into the annulus. The developed methodology enables more accurate prediction of well performance and improved production efficiency even with minimal input data. The results provide valuable insights for optimizing monitoring and management of ESP-equipped well fleets operating in PSOM. This research demonstrates how to achieve reliable modeling outcomes despite data constraints, ultimately supporting better decision-making in well management and field development strategies.

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