The impact of implementation of the flask-based water cut sampling method on the Samotlor field development

UDK: 622.276.43.05

DOI: 10.24887/0028-2448-2025-11-26-30

Key words: oil and gas industry, well production, water cut, mature field, production optimization, graduated flasks, water cut sampling, group gathering efficiency factor

Authors: D.V. Emelyanov (Samotlorneftegas JSC, RF, Nizhnevartovsk); R.R. Khazigaleev (Samotlorneftegas JSC, RF, Nizhnevartovsk); I.F. Sharipov (Samotlorneftegas JSC, RF, Nizhnevartovsk); K.A. Neustroev (Rosneft Oil Company, RF, Moscow); A.A. Gilderman (RN-Geology Research Development LLC, RF, Tyumen); T.P. Populova (RN-Geology Research Development LLC, RF, Tyumen); E.R. Salimova (RN-Geology Research Development LLC, RF, Tyumen)

The existing methods for determining water cut of well production have limitations in the context of mature fields, justifying the development of a new approach that combines accessibility, simplicity, and high measurement accuracy. The article examines the impact of implementing improved water cut measurement technique on the current development status of the Samotlor field. The proposed solution differs from traditional methods by using a 2-liter glass flask (according to GOST 1770) for sample collection, followed by thermostating, settling, and calculation of the separated water volume and oil sample volume. The method, based on 2-liter flasks, enhanced the accuracy of water cut determination in high-water-cut wells, enabling precise assessment of well profitability and subsequent shutdown of the high-water-cut production unit. To prevent system imbalance and maintain production-injection balance during shutdown, a systematic approach was applied, involving analysis of interactions between production and injection wells and evaluation of injection efficiency. Shutting down 939 unprofitable production wells and 247 inefficient injection wells increased the group gathering efficiency factor

(oil production) from 0,77 to 0,98, reduced infrastructure load by 27 %, and lowered pressure in the oil gathering system (linear) by 0,35 MPa, while restoring reservoir pressure potential. Monitoring of implemented measures confirmed the effectiveness of the proposed approach.

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