The analysis of the size distribution of particles in sandy rocks is a crucial sedimentological approach that enables us to understand the hydrodynamic conditions in aquatic environments, as well as the methods of transportation and deposition of these rocks. However, in Russia, this technique is not given much attention, with most research focusing on the quantification of the fine pelitic fraction and using these results to plan the bottomhole screen for well completion. Various methods such as grain-size statistical parameters, bivariate analysis, linear discriminate functions, Passega and Ludwikowska diagrams were used to reveal the depositional processes, sedimentation mechanisms, hydrodynamic energy and facies conditions. All studies were performed for fields and sandy deposits that are actively being studied by Rosneft's laboratory centers. The results of the discriminant analysis showed that Cretaceous sandstones from the BS and Achimov formations were formed in shallow-water environments under the influence of active internal tides. Jurassic sandstones, on the other hand, have a wide distribution of possible sedimentological environments, including coastal facies and beaches. The Bobrikov Horizon sandstones tend to be near-shore facies, but also can be considered as aeolian dunes, while the Vendian B-8 sandstones may have formed as aeolian deposits when they were actively discharged and deposited into shallow sea waters.

References

1. Bikkenin V.T., Rozhkov G.F., A critical review of genetic diagrams in granulometry (In Russ.), Litologiya i poleznye iskopaemye, 1982, no. 6, pp. 3–14.

2. Romanovskiy S.I., Fizicheskaya sedimentologiya (Physical sedimentology), Leningrad: Nedra Publ., 1988, 240 p.

3. Burleva O.V., Genetic interpretation of granulometric data of sandy-silty rocks of the Yu1 horizon in the southeast of the West Siberian Plate (In Russ.), Geologiya, geofizika i razrabotka neftyanykh i gazovykh mestorozhdeniy, 2001, no. 10, pp. 95–100.

4. Vakulenko L.G., Predtechenskaya E.A., Chernova L.S., Experience of using granulometric analysis for reconstructing the formation conditions of sandstones in productive strata of the Vasyugan horizon (Western Siberia) (In Russ.), Litosfera, 2003, no. 3, pp. 99–108.

5. Kudryashova L.K., Granulometric analysis as the main method for substantiating the conditions of formation of reservoirs YuK2-5 of the Em-Egovskaya area (Western Siberia) (In Russ.), Izvestiya TPU. Inzhiniring georesursov, 2015, V. 326, no. 10, pp. 143–149. 6. Folk R.L., Ward W., Brazos river bar: a study in the significance of grain size parameters, Journal of Sedimentary Petrology, 1957, V. 27, pp. 3–26, DOI: https://doi.org/10.1306/74D70646-2B21-11D7-8648000102C1865D

7. Folk R.L., A review of grain-size parameters, Sedimentology, 1966, V. 6, pp. 73–93, DOI: https://doi.org/10.1111/j.1365-3091.1966.tb01572.x

8. Sahu B.K., Depositional mechanism from the size analysis of elastic sediments, Journal of Sedimentary Petrology, 1964, V. 34, pp. 73–83,

DOI: https://doi.org/10.1306/74D70FCE-2B21-11D7-8648000102C1865D

9. Baiyegunhi C., Liu K., Gwavava O., Grain size statistics and depositional pattern of the Ecca Group sandstones, Karoo Supergroup in the Eastern Cape Province, South Africa Open Geoscience, 2017, V. 9, pp. 554–576, DOI: https://doi.org/10.1515/geo-2017-0042

10. Sinha A., Rais S., Granulometric analysis of Rajmahal inter-trappen sedimentary rocks (Early Cretaceous), Eastern India, implications for depositional history, International Journal of Geosciences, 2019, V. 10, pp. 238–253, DOI: https://doi.org/10.4236/ijg.2019.103015

11. Sahu B.K., Multigroup discrimination of depositional environments using size distribution statistics, Indian Journal of Earth Sciences, 1983, V. 10, pp. 20–29.

12. Passega R., Grain size representation by C-M pattern as a geological tool, Journal of Sedimentary Petrology, 1964, V. 34, pp. 830–847,

DOI: https://doi.org/10.1306/74D711A4-2B21-11D7-8648000102C1865D

13. Mycielska-Dowgiałło E., Ludwikowska-Kędzia M., Alternative interpretations of grain-size data from Quaternary deposits, Geologos, 2011, V. 17(4), pp. 189–203,

DOI: https://doi.org/10.2478/v10118-011-0010-9

14. Shaldybin M.V., Wilson M.J., Wilson L. et al., Jurassic and Cretaceous clastic petroleum reservoirs of the West Siberian sedimentary basin: Mineralogy of clays and influence on poro-perm properties, Journal of Asian Earth Sciences, 2021, V. 222, DOI: https://doi.org/10.1016/j.jseaes.2021.104964

15. Cacchione D.A., Pratson L.F., Ogston A.S., The shaping of continental slopes by internal tides, Science, 2002, V. 296(5568), DOI: https://doi.org/10.1126/science.1069803

16. Shaldybin M., Kvachko S., Rudmin M. et al., Ancient Aeolian reservoirs of the East Siberia Craton, Geosciences, 2023, V. 13(8), DOI: https://doi.org/10.3390/geosciences13080230

This paper presents the results of the search for new oil accumulations based on the application of 3D Common Depth Point (CDP) seismic surveys in the peripheral areas of a mature oil field. The 3D CDP seismic survey conducted in 2016 revealed a structural high associated with the Bobrikovo-Radaevsky horizon and led to the discovery of new accumulations in terrigenous strata and in the overlying carbonate deposits. Analysis of data acquired after the initial well penetrated the reservoir highlighted the need for further investigation of the accumulation through deep drilling to delineate its complex geometric outline and determine the geological structure of the flank zones. Subsequently drilled pilot holes enabled the refinement of reservoir boundaries and oil-water contacts. The commissioning of the first horizontal well targeting the Bobrikovo-Radaevsky horizon confirmed predictions of high reservoir productivity. The study demonstrates how multidisciplinary collaboration among geologists, seismologists, geophysicists, and reservoir engineers enabled high-quality seismic-geological analysis of the 3D CDP data, justifying an optimal development strategy aimed at maximizing the oil recovery factor. The obtained results indicate the potential for modernizing approaches to the development of mature fields, which can extend the period of active production for fields with a long development history, thereby increasing production efficiency and opening new prospects for replenishing the resource base.

References

1. Lozin E.V., Razrabotka unikal’nogo Arlanskogo neftyanogo mestorozhdeniya vostoka Russkoy plity (Developing a unique Arlan oil field of the East of the Russian Plate), Ufa: Publ. of BashNIPIneft, 2012, 704 p.

2. Gareev A.T., Nurov S.R., Faizov I.A. et al., Production features and concept of further development of the unique Arlanskoye field (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2023, no. 4, pp. 40–45, DOI: http://doi.org/10.24887/0028-2448-2023-4-40-45

3. Shvetsova N.N., Timerkhanov R.F., Vagizov A.M. et al., Non-standard tasks and standard solutions for 3D seismic exploration for additional exploration (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2025, no. 3, pp. 32–36, DOI: https://doi.org/10.24887/0028-2448- 2025-3-32-36

4. Vagizov A.M., Khabibullin T.D., Lukmanov N.F. et al., Integration of facies analysis into adaptation of terrigenous reservoir simulation model (In Russ.), Ekspozitsiya Neft’ Gaz, 2025, no. 3, pp. 32–38, DOI: https://doi.org/10.24412/2076-6785-2025-3-32-38

5. Vagizov A.M., Timerkhanov R.F., Gareev A.T. et al., On localization of residual recoverable reserves zones lower Carboniferous terrigenous deposits of Arlanskoye field at the late stage of development (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2024, no. 3, pp. 56–61, DOI: https://doi.org/10.24887/0028-2448-2024-3-56-61

In the article, a brief historical overview and the current state of electrical logging problems are given, their relevance and practical significance are discussed, the formulation of the generalized Fok – Stefanescu problem is provided, and various approaches to its solution are discussed, including those which were obtained by the participants of the Academic Tournament. Academic Tournaments are held annually by Rosneft Oil Company with the aim of attracting young scientists to solve current physical and mathematical problems of the oil and gas industry. In 2024, the Academic Tournament was timed to coincide with the 90th anniversary of the publication of the fundamental monograph by academician V.A. Fok «Theory of determining the resistance of rocks by the logging method». V.A. Fok is a renowned specialist in the field of quantum mechanics and general relativity, who laid the foundations of the theory of electrical logging in our country. The problem proposed to the competition participants was aimed at assessing the possibility of constructing effective algorithms for identifying reservoir parameters. Multilayer reservoirs with a variable size of the invasion zone, which are close to practical conditions, were considered. The results of the tournament showed that the computational complexity of such a problem is significantly higher than the classic formulation. Despite the fact that the algorithms proposed by the tournament participants made it possible to solve the problem with accuracy acceptable for practice, an acceptable solution time is a task for the future.

References

1. Fok V.A., Teoriya opredeleniya soprotivleniya gornykh porod po sposobu karotazha (Theory of determining rock resistance using well logging), Moscow: Gostekhteorizdat Publ., 1933.

2. Schlumberger A. Gruner, La Boîte magique ou les Sources du pétrole, Fayard, 1977, 213 p.

3. Dzhafarov K.I., Dzhafarov A.K., Electric methods for exploration of mineral resources in USSR (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2001, no. 2,

pp. 99–102.

4. Komarov S.G., Karotazh po metodu soprotivleniy. Interpretatsiya (Resistance logging interpretation), Moscow: Gostoptekhizdat Publ., 1950, 229 p.

5. Al’pin L.M., K teorii elektricheskogo karotazha burovykh skvazhin (On the theory of electrical logging of boreholes), Moscow: ONTI Publ., 1938, 88 p.

6. Dakhnov V.N., Elektricheskie i magnitnye metody issledovaniya skvazhin (Electrical and magnetic methods of well exploration), Moscow: Nedra Publ., 1981, 344 p.

7. Al’pin L.M., Paletki bokovogo karotazhnogo zondirovaniya (Lateral well logging palettes), Moscow: Gostoptekhizdat Publ., 1958, 45 p.

8. Belash P.M., Dakhnov V.N., Neyman E.A., Modeling of industrial geophysics problems using an electrical integrator (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 1953, no. 7, pp. 33–38.

9. Dakhnov V.N., Neyman E.A., Paletki PKM-MNI (Palettes of finite-thickness formations - Moscow Oil Institute), Moscow: Gostoptekhizdat Publ., 1953, 17 p.

10. Chaadaev E.V., Razvitie teorii i metodiki interpretatsii dannykh elektricheskogo i induktsionnogo karotazha (Development of the theory and methodology for interpreting electrical and induction logging data): thesis of doctor of technical science, Tver, 1991.

11. Al’bom teoreticheskikh krivykh elektricheskogo karotazha skvazhin (Album of theoretical curves for electrical well logging), Moscow: Nedra Publ., 1964, 52 p.

12. Druskin V.L., Razrabotka metodov interpretatsii bokovogo karotazhnogo zondirovaniya v neodnorodnykh osesimmetrichnykh sredakh (Development of methods for interpreting lateral logging in heterogeneous axisymmetric environments): thesis of candidate of physical and mathematical science, Moscow: Publ. of MSU, 1984.

13. Shein Yu.L., Pantyukhin V.A., Kuz’michev O.B., Algoritmy modelirovaniya pokazaniy zondov BKZ, BK, IK v plastakh s zonoy proniknoveniya (Algorithms for modeling readings from BKZ, BK, and IR probes in formations with an invasion zone), Collected papers “Avtomatizirovannaya obrabotka dannykh geofizicheskikh i geologo-tekhnologicheskikh issledovaniy neftegazorazvedochnykh skvazhin i podschet zapasov nefti i gaza s primeneniem EVM” (Automated processing of data from geophysical and geological-technological studies of oil and gas exploration wells and calculation of oil and gas reserves using computers), Kalinin: Publ. of USSR Ministry of Geology, Soyuzpromgeofizika, 1989, pp. 75–81.

14. Surodina I.V., Parallel GPU solvers for the solution of direct electric logging problems (In Russ.), Matematicheskie zametki SVFU, 2015, V. 22, no. 2, pp. 51–61.

15. Kuz’michev O.B., The capabilities of production logging methods for hydrocarbon field development monitoring (In Russ.), Karotazhnik, 2019, no. 6(300), pp. 53–65.

Nowadays, due to the depletion of reserves in areas with increased filtration and capacitance properties, the study of geological structure of complex objects is becoming particularly relevant, dictating the need to find ways to reliable geological and hydrodynamic modeling. The object under study is characterized by a complex geology, thus standard approaches to constructing geological and hydrodynamic models demonstrate low accuracy in the inner-well space. The adaptation of the filtration model is very difficult and requires the addition of fictitious aquifers, modifiers, etc., without which it shall not reflect the actual picture of oil filtration. This article presents an algorithm for constructing a permeability cube that enables taking into account the following complicating factors: the void space of the reservoir (due to Flow Zone Indicators), the influence of fault tectonics, and a small amount of information from wells (including horizontal). The algorithm includes the use of machine learning methods «random forest» and ML inversion of seismic, as well as a two-parameter distribution tool that enables to take into account the distribution of point information (primary attribute) due to the correlation with the seismic cube (secondary attribute). The paper identifies 4-5 reservoir classes (petroclasses) for each reservoir and constructs new correlations of the permeability-porosity type. The verification of the constructed 3D cubes of the permeability coefficient with the data obtained from the petrophysical description of the core from exploration and production wells showed high convergence in the borehole of the cube obtained using a two-parameter distribution.

References

1. Semanov A.S., Semanova A.I., Fattakhov I.G. et al., Modeling tools used for operational field development management (In Russ.), Neftegazovoe delo, 2023, no. 5,

pp. 91–98, DOI: https://doi.org/10.17122/ngdelo-2023-5-91-98

2. Makhmutov A.A., Shabrin N.V., Malyarenko A.M. et al., Improving methods of three-dimensional geological models of oil fields with complex structure (In Russ.), Geologiya. Izvestiya Otdeleniya nauk o Zemle i prirodnykh resursov, 2023, no. 30, pp. 62–80, DOI: https://doi.org/10.24412/2949-4052-2023-1-62-80

3. Bakirov I.I., Makhmutov A.A., Minnullin A.G. et al., Experience of oil-saturated cube simulation in reservoirs, heterogeneous in their reservoir characteristics, at the latest stage of their development (In Russ.), Geologiya, geofizika i razrabotka neftyanykh i gazovykh mestorozhdeniy, 2017, no. 12, pp. 69–70.

4. Sten’kin A.V., Kotenev Yu.A., Sultanov Sh.Kh., Umetbaev V.G., Methodical substantiation of increasing production of oil reserves on the fields complicated by tectonic disturbances (In Russ.), Izvestiya Tomskogo politekhnicheskogo universiteta. Inzhiniring georesursov = Bulletin of the Tomsk Polytechnic University, 2019, no. 1,

pp. 214–223, DOI: https://doi.org/10.18799/24131830/2019/1/71

5. Bakhtizin R.N., Lutfullin A.A., Makhmutov A.A., Improvement of the methodology for modeling the permeability cube taking into account the heterogeneity of the structure of the pore space of the pay zones of the South Tatar arch (In Russ.), Neftegazovoe delo, 2023, V. 21, no. 2, pp. 25–34, DOI: https://doi.org/10.17122/ngdelo-2023-2-25-34

6. Chudinova D.Yu., Kotenev A.Yu., Makhnytkin E.M. et al., The influence of geological structure productive sediments Middle Ob on efficiency production enhancement operations (In Russ.), Geologiya. Izvestiya Otdeleniya nauk o Zemle i prirodnykh resursov, 2023, no. 32, pp. 38–51, DOI: https://doi.org/10.24412/2949-4052-2023-3-38-51

7. Mel’nikov A.V., Sultanov Sh.Kh., Makhmutov A.A., Chibisov A.V., Drilling challenges and technological solutions in the development of oil deposits in fractured carbonate reservoirs (In Russ.), Nanotekhnologii v stroitel’stve, 2024, V. 16, no. 6, pp. 567–575, DOI: https://doi.org/10.15828/2075-8545-2024-16-6-567-575

8. Mustafaev M.K., Sultanov Sh.Kh., Makhmutov A.A. et al., Improving the reliability of the three-dimensional geological basis of complex development targets (In Russ.), Neftegazovoe delo, 2024, V. 22, no. 5, pp. 8–16, DOI: https://doi.org/10.17122/ngdelo-2024-5-8-16

9. Mustafaev M.K., Izuchenie vliyaniya neodnorodnosti produktivnykh plastov po FES na kharakter raspredeleniya neftenasyshchennosti (Study of the influence of heterogeneity of productive formations by reservoir properties on the nature of oil saturation distribution), Proceedings of International scientific and practical conference dedicated to the 75th anniversary of the Mining and Petroleum Faculty of Ufa State Petroleum Technical University and the 100th anniversary of the scientist Alexander Ivanovich Spivak, Ufa, 2023, p. 190.

10. Yatsenko V.M., Antonenko D.A., Nigmatullin R.R., The technique of permeability estimation by a method of hydraulic units on an example of Vankorskoye field reservoirs (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2009, no. 12, pp. 69–72.

11. Amaefule J.O., Altunbay M., Tiab D. et al., Enhanced reservoir description: Using core and log data to identify hydraulic (flow) units and predict permeability in uncored intervals/wells, SPE-26436-MS, 1993, DOI: https://doi.org/10.2118/26436-MS

12. Zalevskiy O.A., Kotenev Yu.A., Sultanov Sh.Kh., Sharafutdinov A.R., Identification of lithological and facies features of sediments based on machine learning methods (In Russ.), Neftegazovoe delo, 2024, V. 22, no. 6, pp. 16–25, DOI: https://doi.org/10.17122/ngdelo-2024-6-16-25

13. Sharafutdinov A.R., Sultanov Sh.Kh., Chilikin V.M., The application of machine learning algorithms to detail the geological structure of productive sedimentary rocks

(In Russ.), Inzhener-neftyanik, 2025, no. 1, pp. 86–89.

Methods of seals identification above the prospective reservoir horizons are considered for the purpose of researching and predicting the petroleum potential of natural reservoirs in terrigenous formations, including those in the West Siberia. It is shown that cyclically structured terrigenous formations contain not only high-capacity, high-production reservoirs and seals, but also layers, packs and stratums of interbedded clays, mudstones, siltstones, clay sandstones, dense carbonate interlayers and coals that are neither reservoirs nor seals. These layers are composed parts of natural reservoirs in which hydrocarbons migrate under the seals. Seals in non-reservoir stratums are identified by signs of a lack of hydrocarbon saturation based on the interpretation of well logging data. Hydrocarbon-permeable non-reservoir rocks, deposited between reservoirs and seals, are determined by the presence of hydrocarbon saturation which is considered as evidence of the permeability of layers, packs and stratums non-reservoir rocks. The process of identifying a seal in an Upper Jurassic-Lower Cretaceous sequence of interbedded non-reservoir rocks is described using well logging data and author's methodology - NEGAEL. Main part of the methodology is the determination of non-reservoir-seal boundary values using a special parameter F. This parameter is represented by neutron-gamma (or neutron logging) readings reflecting hydrogen content, divided by gamma ray readings reflecting clay content. A method is proposed for comparing the F parameter and electrometry (lateral logging) in two well sections: inner and outer. This enables to identify and correlate seals between wells and also to construct fundamentally new reservoir models by mapping seal bottoms above reservoir horizons.

References

1. Kazanenkov V.A., Geologiya, paleogeografiya i neftegazonosnost’ malyshevskogo gorizonta (verkhniy bayos-bat) Zapadnoy Sibiri (Geology, paleogeography and oil and gas potential of the Malyshevsky horizon (upper Bajocian-Bathonian) of Western Siberia): thesis of doctor of geological and mineralogical science, Novosibirsk, 2024.

2. Zhemchugova V.A., Berbenev M.O., Basic principles for modeling reservoir structure (on the example of cretaceous deposits of the Western Siberia) (In Russ.), Georesursy, 2015, no. 2, pp. 54–62.

3. Belozerov V.B., Ivanov I.A., Platform deposition in the West Siberian Plate: A kinematic model (In Russ.), Geologiya i geofizika, 2003, V. 44, no. 8, pp. 781–795.

4. Filippov B.V., Tipy prirodnykh rezervuarov nefti i gaza (Types of natural oil and gas reservoirs), Leningrad: Nedra Publ., 1967, 124 p.

5. Khanin A.A., Porody-kollektory nefti i gaza neftegazonosnykh provintsiy SSSR (Oil and gas reservoir rocks of the oil and gas provinces of the USSR), Moscow: Nedra Publ., 1973, 304 p.

6. Lokal’nyy prognoz neftegazonosnosti na osnove analiza stroeniya lovushek v trekhsloynom rezervuare. Metodicheskie rekomendatsii (Local oil and gas potential forecast based on trap structure analysis in a three-layer reservoir. Methodological recommendations), Compilers: Il’in V.D., Maksimov S.P., Zolotov A.N. et al., Moscow: Publ. of VNIGNI, 1982, 52 p.

7. Danilova E.M., Konovalova I.N., Popova M.N., Khitrov A.M., Seals and methodology of hydrocarbons deposits searching in sedimentary formations (In Russ.), Geologiya, geofizika i razrabotka neftyanykh i gazovykh mestorozhdeniy, 2024, no. 11(395), pp. 13–20.

8. Kabyshev B.P., Chuprynin D.I., Shevyakova Z.P., Methodology for separating fluid seals and false seals of gas and oil (In Russ.), Sovetskaya geologiya, 1983, no. 12, pp. 14–23.

9. Gurova D.I., Danilova E.M., Konovalova I.N. et al., Seals identification and mapping based on geophysical data (In Russ.), Geologiya, geofizika i razrabotka neftyanykh i gazovykh mestorozhdeniy, 2023, no. 11(383), pp. 5–13, DOI: https://doi.org/10.33285/2413-5011-2023-11(383)-5-13

The conveyor batch drilling method was first implemented in Vietsovpetro JV in 2020 using Tam Dao 03 jack-up drilling rig during well construction on the new offshore fixed platform conductor block - BK-20. The project featured drilling and installation of 508 mm diameter surface casing in seven wells as part of a single technological program. The purpose of implementing this method was to reduce overall costs during the construction of a group of wells, as well as to increase the efficiency of interaction between various departments and services. The drilling experience on the BK-20 confirmed the high efficiency of the conveyor drilling method. The successful implementation of the method at BK-20 predetermined its application at other offshore facilities of Vietsovpetro JV. However, despite the obvious advantages, the implementation of the conveyor drilling method also revealed some peculiarities. For example, the start of operation of individual wells in a group is delayed for some time compared to sequential drilling, which in turn can potentially affect production volumes in certain periods. This paper examines both the positive aspects of using the conveyor drilling method, as well as the identified limitations and technical features that affect its further implementation within the framework of the drilling programs of Vietsovpetro JV.

Drilling in difficult mining and geological conditions involves the use of high-quality flushing and process fluids with the possibility of operational control of the component composition and properties. Currently, the use of emulsion drilling and technological solutions, the liquid basis of which is a direct or reverse emulsion of water and a hydrocarbon liquid, is relevant in the well construction processes. Insufficient efficiency of mass-produced preparation equipment leads to a decrease in the quality of the solution, which unreasonably increases the cost of materials, time and energy. The solution of this problem is related to the development of high–tech dispersant devices that combine cavitation and hydrodynamic effects. The principle of operation and technical characteristics of a cavitation dispersant are given, and approaches for such devices are formulated. By performing computational and experimental studies, a full-scale sample of a linear cavitation dispersant was developed and manufactured. The production process includes the preparation of a hydrocarbon-based solution for the process of wiring the trunk of the exploration well of the Chayandinsky oil and gas condensate field under the production column. During operation, the reduction in time for the preparation of hydrocarbon-based solutions compared to the standard dispersant was reduced by 55 %. Equipping solution preparation units with cavitation dispersants shall increase productivity and create more advanced technologies for producing drilling fluids, achieving design parameters within a few cycles.

References

1. Blaz S., Zima G., Jasinski B., Kremieniewski M., Invert drilling fluids with high internal phase content, Energies, 2021, no. 14, DOI: https://doi.org/10.3390/en14010014

2. Kravchuk M.V., Obosnovanie i razrabotka tekhnologicheskikh parametrov burovogo rastvora na uglevodorodnoy osnove dlya bureniya naklonno-napravlennykh skvazhin gidromonitornymi dolotami (Justification and development of technological parameters of hydrocarbon-based drilling mud for drilling directional wells with hydromonitor bits): thesis of candidate of technical science, Ukhta, 2017.

3. Mancuso G., Langone M., Andreottola G., A critical review of the current technologies in wastewater treatment plants by using hydrodynamic cavitation process: principles and applications, Journal of Environmental Health Science and Engineering, 2020, V. 18, pp. 311–333, DOI: https://doi.org/10.1007/s40201-020-00444-5

4. Omelyanyuk M.V., Pakhlyan I.A., Gidrodinamicheskie i kavitatsionnye struynye tekhnologii v neftegazovom dele (Hydrodynamic and cavitation jet technology in oil and gas business), Krasnodar: Publ. of CSTU, 2017, 215 p.

5. Xu S., Wang J., Cheng H. et al., Experimental study of the cavitation noise and vibration induced by the choked flow in a Venturi reactor, Ultrasonics Sonochemistry, 2020, V. 67, no. 105183, 11 p., DOI: https://doi.org/10.1016/j.ultsonch.2020.105183

6. Pakhlyan I.A., Effectiveness of the use of cavitation phenomena for dispersion and homogenization of components of drilling and grouting solutions (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2023, no. 12, pp. 109–111, DOI: https://doi.org/10.24887/0028-2448-2023-12-109-111

The article studies features of experimental studies of dynamic characteristics of two-phase filtration in carbonate reservoirs. The most important dynamic characteristics of two-phase flow are the relative permeabilities for fluids saturating the pore space. The objective of this study is to investigate the dynamic characteristics of two-phase flow in carbonate sediments of the Mendym horizon of one of fields in the Samara region, whose reservoir rocks are porous and cavernous organogenic-clastic limestones. There were selected standard and full-size samples with similar porosity and permeability in order to study the relative permeabilities. To facilitate comparison of the obtained results and further analysis, the total flow rate of fluids injected into the samples for each experimental series and for each flow regime was the same. Capillary measurements were additionally conducted to assess the pore size distribution to study pore structure. Analysis of the obtained results revealed differences in the conditions for the formation of residual oil saturation and the pace of change in relative oil permeability, which should be taken into account in further simulation modelling of reservoir development processes in complex carbonate reservoirs. Furthermore, for carbonate reservoir conditions, the dynamic characteristics should be studied comprehensively using additional studies, including capillary measurements, Nuclear Magnetic Resonance Logging, study of thin sections and other.

References

1. Kovalev A.A., Vliyanie anizotropii gornykh porod na fil'tratsionnye kharakteristiki produktivnykh plastov i effektivnost' protsessov dobychi nefti (The influence of rock anisotropy on the filtration characteristics of productive formations and the efficiency of oil production processes), Proceedings of Giprovostokneft, Samara, 1999,

pp. 58–65.

2. Kovalev A.A., Problems of identification of two-phase filtration process for hydrodynamic calculations (In Russ.), Izvestiya Samarskogo nauchnogo tsentra RAN, 2003, Special Issue “Problemy nefti i gaza” (Oil and Gas Problems), pp. 89–94.

Most of the oil and gas fields of Western Siberia have been developed since the 1970s. Currently, a significant part of these deposits is at the final stage of development, characterized by large recovery of oil and gas reserves and high waterlogging of the producing well stock. For the most comprehensive extraction of hydrocarbon reserves from fields that are in the late stages of development, chemical methods of waterflooding (CMW) regulation, hydrodynamic methods for enhanced oil recovery (HMEOR), thermal, gas and other methods are applied. The aim of this work is to increase oil recovery at site A characterized by fractured layers with heterogeneous permeability and oil saturation in one of the oil and gas condensate fields of the Surgut arch by sequentially applying CMW and HMEOR. The first stage of the proposed technology involves the use of CMW in injection wells to equalize the inflow profile. This technology is most effective in fractured and heterogeneous layers. At the second stage, HMEOR is conducted. This stage includes regulating the injection and fluid extraction modes by periodically shifting the injection front between two rows of injection wells with symmetrical cyclicity. The study identifies the most suitable areas of the field for testing the technology and calculates the optimal operating modes of the wells to achieve additional oil production.

References

1. Eremin N.A., Zolotukhin A.B., Nazarova L.N., Chernikov O.A., Vybor metoda vozdeystviya na neftyanuyu zalezh’ (Choice of method of oil reservoir stimulation), Moscow: Publ. of Gubkin University, 1995, 190 p.

2. Darishchev V.I., Sovremennye proekty KhMUN v Rossii (Modern projects of chemical EOR in Russia), Proceedings of International Scientific and Technical Conference on Chemical EOR, Kazan’, 2022.

3. Malinovskiy I.V., Avtomatizatsiya podbora khimicheskikh metodov uvelicheniya nefteotdachi na osnove otsenki ikh effektivnosti (Automation of the selection of chemical methods for enhanced oil recovery based on an assessment of their effectiveness), Proceedings of XXXlX scientific and technical conference of young scientists and specialists of Surgutneftegas PJSC, Surgut: Neft’ Priob’ya Publ., 2019, pp. 395–401.

An algorithm for modeling three-phase equilibrium in multicomponent petroleum mixtures containing water is presented. The relevance of this work is defined by the requirement for accurate prediction of the phase behavior of water-containing reservoir fluids at all field development stages. It is important for preventing flow assurance issues associated with hydrate formation. Existing methods (direct Gibbs energy minimization) are often computationally expensive and complex to implement, while simplified algorithms may not be stable enough, especially with a significant increase in the number of components. The proposed approach combines several previously developed techniques: the generation of initial equilibrium constants based on stability analysis; the application of a simplified model for hydrocarbon solubility in water (reduces the three-phase equilibrium problem to a pseudo-two-phase problem); the use of the Newton method for solving the system of equations. The algorithm is implemented using the Soave-Redlich-Kwong equation of state and tested on several mixtures, including simple ternary systems and multicomponent gas-condensate mixtures with compositions corresponding to real petroleum reservoir fluids. A comparison of the calculation results obtained using the developed software module with data from the PVTSim software was conducted. It is shown that even the simplified free-water flash (FWF) model provides good agreement with the commercial software data, while solving the equilibrium problem improves the accuracy of the results, reducing the average absolute relative error to less than one percent. The algorithm demonstrates high stability across the entire range of thermobaric conditions, making it a practical tool for PVT modeling.

References

1. Andrianova A., Yudin E., Shestakov A. et al., Development of a hydrate-free operating mode model for gas lift wells, SPE-217651-MS, 2023,

DOI: https://doi.org/10.2118/217651-MS

2. Peng D.Y., Robinson D.B., Two and three phase equilibrium calculations for systems containing water, The Canadian Journal of Chemical Engineering, 1976, V. 54,

no. 6, pp. 595–599, DOI: https://doi.org/10.1002/cjce.5450540620

3. Peng D.Y., Robinson D.B., A new two-constants equation of state, Industrial and Engineering Chemistry. Fundamentals, 1976, V. 1, pp. 59–64,

DOI: https://doi.org/10.1021/i160057a011

4. Aksenov O.A., Kozlov M.G., Usov E.V. et al., Implementation of methodology to calculate three-phase equilibrium of hydrocarbons and water phase (In Russ.), Neft’. Gaz. Novatsii, 2022, no. 12, pp. 38–43.

5. Michelsen M.L., The isothermal flash problem. Part I. Stability, Fluid Phase Equilibria, 1982, V. 9, no. 1, pp. 1–19, DOI: https://doi.org/10.1016/0378-3812(82)85001-2

6. Xuesong Ma, Shuhong Wu, Gang Huang, Tianyi Fan, Three-phase equilibrium calculations of water/hydrocarbon/nonhydrocarbon systems based on the equation of state (EOS) in thermal processes, ACS Omega, 2021, no. 6(50), pp. 34406–34415, DOI: https://doi.org/10.1021/acsomega.1c04522

7. Ruixue Li, Huazhou Andy Li, Improved three-phase equilibrium calculation algorithm for water/hydrocarbon mixtures, Fuel, 2019, V. 244, pp. 517–527,

DOI: https://doi.org/10.1016/j.fuel.2019.02.026

8. Yushchenko T.S., Mathematical modeling of three-phase equilibrium in natural gas condensate systems in the presence of a mineralized water solution (In Russ.), Trudy MFTI, 2015, V. 7, no. 2(26), pp. 70–82.

9. Mahmudi M., Sadeghi M.T., A novel three pseudo-component approach (ThPCA) for thermodynamic description of hydrocarbon-water systems, Journal of Petroleum Exploration and Production Technology, 2014, no. 4, pp. 281–289, DOI: https://doi.org/10.1007/s13202-013-0072-z

10. Ruixue Li, Huazhou Andy Li, New two-phase and three-phase Rachford-Rice algorithms based on free-water assumption for the Three-Fluid-Phase VLLE Flash Calculation, The Canadian Journal of Chemical Engineering, 2018, V. 96, no. 1, pp. 390–403, DOI: https://doi.org/10.1002/cjce.23018

11. Yiping Tang, Sanjoy Saha, An efficient method to calculate three-phase free-water flash for water−hydrocarbon systems, Industrial & Engineering Chemistry Research, 2003, no. 42(1), pp. 189–197, DOI: https://doi.org/10.1021/ie010785x

12. Lapene A., Nichita D.V., Debenest G., Quintard M., Three-phase free-water flash calculations using a new Modified Rachford–Rice equation, Fluid Phase Equilibria, 2010, V. 297, no. 1, pp. 121–128, DOI: https://doi.org/10.1016/j.fluid.2010.06.018

13. Hinojosa-Gómez H., Solares-Ramírez J., Bazúa-Rueda E.R., An improved algorithm for the three-fluid-phase VLLE flash calculation, AIChE J., 2015, no. 61,

pp. 3081–3093, DOI: https://doi.org/10.1002/aic.14946

14. Nazari M., Asadi M.B., Zendehboudi S., A new efficient algorithm to determine three-phase equilibrium conditions in the presence of aqueous phase: Phase stability and computational cost, Fluid Phase Equilibria, 2019, V. 486, pp. 139–158, DOI: https://doi.org/10.1016/j.fluid.2018.12.013

15. Nichita D.V., Gomez S., Luna-Ortiz E., Multiphase equilibria calculation by direct minimization of Gibbs free energy using the tunnelling global optimization method, Journal of Canadian Petroleum Technology, 2004, no. 43, DOI: https://doi.org/10.2118/04-05-TN2

16. Brusilovskiy A.I., Fazovye prevrashcheniya pri razrabotke mestorozhdeniy nefti i gaza (Phase transformations in the development of oil and gas fields), Moscow: Graal’ Publ., 2002, 575 p.

17. Nichita D.V., Broseta D., De-Hemptinne J.C., Multiphase equilibrium calculation using reduced variables, Fluid Phase Equilibria, 2006, V. 246, no. 1–2, pp. 15–27,

DOI: https://doi.org/10.1016/j.fluid.2006.05.016

18. Connolly M., Pan H., Tchelepi H., Three-phase equilibrium computations for hydrocarbon–water mixture using a reduced variables method, Industrial & Engineering Chemistry Research, 2019, no. 58(32), pp. 14954–14974, https://doi.org//10.1021/acs.iecr.9b00695

19. Wagner W., Pruss A., The IAPWS formulation 1995 for the thermodynamic properties of ordinary water substance for general and scientific, Journal of Physical and Chemical Reference Data, 2002, no. 31(2), pp. 387–535, DOI: https://doi.org/10.1063/1.1461829

20. Whitson C.H., Brule M.R., Phase behavior, SPE, 2000, 233 p., DOI: https://doi.org/10.29172/5eb78870-d202-4a15-9cf0-1e9e04b107ac

21. Malyshev V.L., Moiseeva E.F., Legkovoy G.V. et al., High-performance calculations of phase equilibrium for gas condensate systems based on the Soave–Redlich–Kwong equation of state (In Russ.), Izvestiya Tomskogo politekhnicheskogo universiteta. Inzhiniring georesursov = Bulletin of the Tomsk Polytechnic University Geo Assets Engineering, 2025, V. 336, no. 12 (in print).

22. Soave G.S., Equilibrium constants from a modified Redlich-Kwong equation of state, Chemical Engineering Science, 1972, V. 27, no. 6, pp. 1197–1203,

DOI: https://doi.org/10.1016/0009-2509(72)80096-4

23. Michelsen M.L., Whitson C.H., The negative flash, Fluid Phase Equilibria, 1989, V. 53, pp. 51–71, DOI: https://doi.org/10.1016/0378-3812(89)80072-X

24. Malyshev V.L., Nurgalieva Ya.F., Moiseeva E.F., Comparative study of empirical correlations and equations of state effectiveness for compressibility factor of natural gas determination, Periodico Tche Quimica, 2021, V. 18, no. 38, pp. 188–213, DOI: https://doi.org/10.52571/PTQ.v18.n38.2021.14_MALYSHEV_pgs_188_213

The article examines the evolution of digital transformation in the oil and gas industry – from the concept of Integrated Operations to multi-agent systems based on Large Language Models (LLMs). Unlike traditional machine learning systems, LLMs are able to understand context, work with unstructured data, interact with corporate knowledge bases, and explain the logic behind decisions. The paper analyzes both international and domestic experience in implementing Integrated Operations Centers, identifies the limitations of existing approaches, and substantiates the need to move toward a new level of production process autonomization. A mathematical formulation of the decision-making optimization problem is proposed, along with a structured system of autonomy maturity levels. Using a practical example of a geological and technical operation for pump frequency control, the architecture of a multi-agent LLM-based system is demonstrated, highlighting its advantages over traditional approaches. It is shown that the transition to multi-agent systems reduces decision-making time from hours to minutes, creating potential for significant reductions in production losses and improvements in operational efficiency. The paper identifies levels of maturity for autonomous systems, ranging from advisory tools to partially and fully autonomous control loops. Implementation of the concept involves a gradual transition between levels based on accumulated experience, increased trust in the system's decisions, and confirmation of their reliability under industrial operating conditions.

References

1. Rosendahl T., Hepsø V., Integrated operations in the oil and gas industry: Sustainability and Capability Development, Business Science Reference, 2013, 427 p.

2. Clark A., Larsen H.W., Nordtvedt J.-E. et al., Integrated operations centers – Planning and delivering improved operational performance through IOC initiatives,

SPE-196148-MS, 2019, DOI: https://doi.org/10.2118/196148-MS. – EDN: PAJVYA

3. Chai C.F., Van den Berg F., Engbers P., Sondak G., Smart fields-10 years of experience in intelligent energy and collaboration, SPE-167872-MS, 2014,

DOI: https://doi.org/10.2118/167872-MS

4. Dickens J., Latin D., Verra G. et al., The BP field of the future programme: The continuing mission to deliver value, SPE-128672-MS, 2010,

DOI: https://doi.org/10.2118/128672-MS

5. Lilleng T., Øyen M., Farestvedt U. et al., Integrated operations in statoil – From ambition to action, SPE-150418-MS, 2012, DOI: https://doi.org/10.2118/150418-MS

6. URL: https://www.rosneft.ru/press/news/item/195043/

7. URL: https://neftegaz.ru/news/dobycha/205440-v-gazpromneft-khantose-sozdan-tsentr-upravleniya-dobychey-is...

8. Hepsø V., Bergum O.J., Kristiansen E., Digital platform for the next generation IO: A prerequisite for the high north, SPE-127550-MS, 2010,

DOI: https://doi.org/10.2118/127550-MS

9. Da Silva J.S., Nogueira I.B.R., Martins M.A.F., Alves R.M.B., Tools, technologies and frameworks for digital twins in the oil and gas industry: An in-depth analysis, Sensors, 2024, V. 24, DOI: https://doi.org/10.3390/s24196457

10. Liu H., Ren Y., Li X. et al., Research status and application of artificial intelligence large models in the oil and gas industry, Petroleum Exploration and Development, 2024, V. 51, pp. 1049–1065, DOI: https://doi.org/10.1016/S1876-3804(24)60524-0

11. Xia Y., Cao J., Duan W. et al., Control industrial automation system with large language model agents, 2024, DOI: https://doi.org/10.48550/arXiv.2409.18009

12. Chen C., Zhao K., Leng J. et al., Integrating large language model and digital twins in the context of industry 5.0: Framework, challenges and opportunities, Robotics and Computer Integrated Manufacturing, 2025, V. 74, DOI: https://doi.org/10.1016/j.rcim.2024.102899

13. Latypov B.M., Yudin E.V., Bondorov R.A. et al., Development of a large language model for data extraction from unstructured text documents: a case study on production geophysical survey reports (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2025, no. 9, pp. 108–111, DOI: https://doi.org/10.24887/0028-2448-2025-9-108-111

The article addresses the problem of evaluating the coefficient of natural gas separation at the intake of an electric submersible pump (ESP), which is of great importance for improving the efficiency and reliability of oil well operation. The aim of this work is to develop a new method for highly accurate calculation of the natural separation coefficient for pumps with a conditionally radial inlet based on available parameters. The authors have developed a new empirical correlation for calculating the natural gas separation coefficient, based on readily available field parameters. The data set used to build the model is a 16-point data set, including data on liquid flow rate, ESP sizes, water cut, casing diameters, and tubing diameters. The model was constructed using regression analysis of field data and incorporates liquid flow rate, water cut, and well geometry. To verify the accuracy of the proposed correlation, a comparison was made with results obtained from established methods and hydrodynamic modeling. The analysis demonstrates strong agreement between the developed correlation and widely accepted approaches, confirming its practical applicability. The simplicity of use and accessibility of the required input data make the proposed model a convenient tool for engineering calculations aimed at optimizing the performance of ESP-equipped wells.

References

1. Yudin E., Lubnin A., Simulation of multilayer wells operating, SPE-149924-MS, 2011, DOI: https://doi.org/10.2118/149924-MS

2. Kuz’min M.I., Ponomareva A.I., Gerasimov R.V., Approach to adaptive management of well stock with electric vane pump installation (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2025, no. 7, pp. 130–134, DOI: https://doi.org/10.24887/0028-2448-2025-7-130-134

3. Mishchenko I.T., Skvazhinnaya dobycha nefti (Oil production), Moscow: Neft’ i gaz Publ., 2003, 816 p.

4. Mishchenko I.T., Bravichesa T.B., Ermolaev A.I., Vybor sposoba ekspluatatsii skvazhin neftyanykh mestorozhdeniy s trudnoizvlekaemymi zapasami (The choice of the method of oil fields with hard-to-recover reserves operation), Moscow: Neft’ i gaz Publ., 2005, 448 p.

5. Dunyushkin I.I., Mishchenko I.T., Eliseeva E.I., Raschety fiziko-khimicheskikh svoystv plastovoy i promyslovoy nefti i vody (Calculations of physicochemical properties of reservoir and field oil and water), Moscow: Neft’ i gaz Publ., 2004, 448 p.

6. Sakharov V.A., Mokhov M.A., Ekspluatatsiya neftyanykh skvazhin (Oil well exploitation), Moscow: Nedra-Biznestsentr Publ., 2008, 250 p.

7. Yudin E., Khabibullin R., Galyautdinov I. et al., Modeling of a gas-lift well operation with an automated gas-lift gas supply control system (In Russ.), SPE-196816-MS, 2019, DOI: https://doi.org/10.2118/196816-MS

8. Brill J.P., Mukherjee H., Multiphase flow in wells, SPE Monograph, Henry L. Dogherty Series, V.17, 1999, 164 p.

9. Den’gaev A.V., Povyshenie effektivnosti ekspluatatsii skvazhin pogruzhnymi tsentrobezhnymi nasosami pri otkachke gazozhidkostnykh smesey (Improving the efficiency of well operation by submersible centrifugal pumps during pumping of gas-liquid mixtures): thesis of candidate of technical science, 2005.

10. Gorid’ko K.A., Vliyanie izmenyayushchikhsya svoystv gazozhidkostnoy smesi po dline nasosa na kharakteristiki pogruzhnoy elektrotsentrobezhnoy nasosnoy ustanovki (The influence of changing properties of a gas-liquid mixture along the length of a pump on the characteristics of a submersible electric centrifugal pumping unit): thesis of candidate of technical science, Moscow, 2023.

11. Drozdov A.N., Tekhnologiya i tekhnika dobychi nefti pogruzhnymi nasosami v oslozhnennykh usloviyakh (Technology and techniques for oil production using submersible pumps in difficult conditions), Moscow: MAKS press Publ., 2008, 312 p.

12. Marquez R., Prado M., A new robust model for natural separation efficiency, SPE-80922-MS, 2003, DOI: https://doi.org/10.2118/80922-MS

13. Lyapkov P.D., Gurevich A.S., On the relative velocity of the gas phase in the wellbore before entering the downhole pump (In Russ.), Neftepromyslovoe delo, 1973,

no. 8, pp. 6–10.

14. Lyapkov P.D., Podbor ustanovki pogruzhnogo tsentrobezhnogo nasosa k skvazhine (Selection of a submersible centrifugal pump installation for a well), Moscow: Publ. of Gubkin Institute, 1987, 71 p.

15. Ivanov V.A., Verbitskiy V.S., Khabibullin R.A. et al., Experimental studies of natural separation at the intake of a submersible electric centrifugal pump (In Russ.),

Delovoy zhurnal Neftegaz.RU, 2024, no. 8(152), pp. 78–84.

16. Shakirov A.M., A model to predict natural separation of free gas at downhole equipment intake (In Russ.), Neft’, gaz i biznes, 2011, no. 6, pp. 27–30.

17. Schlumberger The OLGA 2022 User Manual, Version 2022.

18. Khabibullin R.A., Neftyanoy inzhiniring OLGA (Oil Engineering OLGA), URL: https://t.me/petroleum_olga

19. Gabdrakhmanov N.Kh., Davydova O.V., Field study of gas separation at submersible pump suction (In Russ.), Problemy sbora, podgotovki i transporta nefti i nefteproduktov, 2010, no. 4(82), pp. 59–62.

The drive toward autonomous oil production imposes much stricter requirements on the collection, processing, and transmission of measurement data that characterize equipment condition and the progression of the technological process. A large amount of complex equipment fitted with diverse sensors is concentrated on well pads; therefore, a pressing scientific and practical task is to provide the automated process control system (APCS) with timely and reliable information. Solving this task is complicated by the fact that measuring instruments fairly often experience metrological failure, manifested as a gradual or abrupt degradation of metrological characteristics beyond permissible limits. The danger of such a failure lies in its detection only during metrological control procedures. The paper proposes performing online diagnostics of measurement channels in real time by employing a validated model that links the controlled output variable of the facility to the influencing input parameters. As an example, diagnostics is presented for the measurement channel of a controlled electric submersible pump (cESP) based on a direct (forward) model that relates liquid and gas flow rates to the dynamic fluid level in the well, the ESP active (real) power, and the ESP intake pressure. The predictive accuracy of the resulting model is no worse than 4 %, which confirms the feasibility of its use within the well-pad APCS for operational monitoring of cESP measurement channels.

References

1. Gerasimov R.V., Dubrovin A.N., Kuz’min M.I., Legkov A.N., Technical solutions for autonomous of production at oil and gas field in complicated conditions (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2025, no. 6, pp. 76–80, DOI: https://doi.org/10.24887/0028-2448-2025-6-76-80

2. Grekhov I.V., Kuz’min M.I., Muzychuk P.S., Gerasimov R.V., Concept of autonomous well pad at the fields of Gazprom Neft (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2021, no. 12, pp. 69-73, DOI: https://doi.org/10.24887/0028-2448-2021-12-69-73

3. Khalbashkeev A., Avtonomnoe mestorozhdenie: podschityvaem plyusy, vzveshivaem riski (Autonomous oil field: calculating the benefits, weighing the risks),

URL: https://nprom.online/technology/avtonomnoe-mestorozhdenie-podschityvaem-plyusy-vzveshivaem-riski

4. Yudin E.V., Khabibullin R.A., Galyautdinov I.M. et al., Creation of a proxy-integrated model of the Eastern section of the Orenburgskoye oil-gas-condensate field under the conditions of lack of initial data (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2019, no. 12, pp. 47–51, DOI: https://doi.org/10.24887/0028-2448-2019-12-47-51

5. Ignat’eva A., Uchenye TPU sozdali mnogofaznye raskhodomery dlya tochnogo ucheta nefti (TPU scientists have developed multiphase flow meters for precise oil metering), URL: https://neftegaz.ru/news/standarts/732114-uchenye-tpu-sozdali-mnogofaznye-raskhodomery-dlya-tochnogo...

6. Vasinkin S.A., Analysis of the concept of an unmanned FPSO (In Russ.), Neftegaz.RU, 2025, no. 7.

7. Polyanskiy S., Yudin E., Slabetsky A. et al., Oil and gas production management: New challenges and solutions, SPE-212086-MS, 2022,

DOI: https://doi.org/10.2118/212086-MS

8. Bakhmetova N.A., Kontrol’ dostovernosti informatsii v dublirovannykh informatsionno-izmeritel’nykh kanalakh ASUTP (Control of the reliability of information in duplicated information and measuring channels of the automated process control system): thesis of candidate of technical science, Vladimir, 2008.

9. Asmandiyarov R.N., Kladov A.E., Lubnin A.A. et al., Automatic approach to field data analysis (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2011, no. 6, pp. 58–61.

10. Kalashnikov A.A., On-line monitoring the level measuring channels with differential pressure sensors at a NPP. Part 2. The calibration characteristics (In Russ.), Kontrol’. Diagnostika, 2016, no. 5, pp. 31-35, DOI: https://doi.org/10.14489/td.2016.05.pp.031-035.

11. Batalov S.A., Tairova K.F., Method of technical diagnostics of measuring channels in automated system of control of process in oil field (In Russ.), Kontrol’. Diagnostika, 2010, no. 4, pp. 40–44.

12. Sokolovskiy S.S., Solomakho D.V., Tsitovich B.V., Metrological modeling as a basis of measurement technique design and implementation (In Russ.), Pribory i metody izmereniy, 2010, no. 1(1), pp. 147-152.

13. Serenkov P.S., Savkova E.N., The system approach to measuring channel modelling as the mechanism of maintenance of trust to results of measurements

This article presents an experimental and model-based justification for selecting optimal predictive approaches to estimate the gas separation efficiency of downhole separators used in electrical submersible pump (ESP) systems operating under high free-gas conditions. Gas separation remains a critical challenge in ESP applications, as excessive free gas leads to degradation of pump head–flow performance, cavitation, unstable flow regimes, and reduced run life. To address this issue, a comprehensive experimental investigation was carried out using a patented laboratory flow loop at Gubkin University, enabling controlled generation of gas–liquid mixtures and evaluation of separators of different sizes under varying liquid flow rates, gas rates, and shaft speeds. Based on the collected dataset, the study compares two major classes of predictive models: classical statistical approaches (polynomial regression, Ridge, Lasso, ElasticNet) and a modern machine-learning method, TabPFN - modern machine learning algorithm tailored for small tabular datasets. Model performance was assessed using coefficient of determination R2 and mean absolute percentage error (MAPE) with cross-validation. The results reveal that TabPFN significantly outperforms all classical models in predicting residual gas content. When using all eight input features, TabPFN achieves MAPE equal to 1,45 % and R2 – 0,96. Although classical regression methods show lower accuracy, they provide interpretability and enable identifying key influencing factors, such as inlet gas fraction and separator size. The findings confirm the high potential of advanced machine-learning methods for predictive analytics, enabling development of digital twins and real-time operational optimization tools for ESP systems working in high-gas environments.

References

1. Wilson B.L., ESP Gas separator’s affect on run life, SPE-28526-MS, 1994, DOI: https://doi.org/10.2118/28526-MS

2. Kuz’min N.I., Verbitskiy V.S., Khabibullin R.A. et al., Analysis of oil wells operation parameters and modes effects on electric submersible pumps reliability (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2024, no. 12, pp. 106–111, DOI: https://doi.org/10.24887/0028-2448-2024-12-106-111

3. Yudin E.V., Gorbacheva V.N., Smirnov N.A., Modeling and optimization of wells operating modes under annular flow conditions (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2022, no. 11, pp. 122–126, DOI: https://doi.org/10.24887/0028-2448-2022-11-122-126

4. Yudin E. et al., Modeling and optimization of ESP wells operating in intermittent mode, SPE-212116-MS, 2022, DOI: https://doi.org/10.2118/212116-MS

5. Yudin E. et al., New applications of transient multiphase flow models in wells and pipelines for production management, SPE-201884-MS, 2020,

DOI: https://doi.org/10.2118/201884-MS

6. Harun A.F., Prado M.G., Serrano J.C., A mechanistic model to predict natural gas separation efficiency in inclined pumping wells, SPE-67184-MS, 2001,

DOI: https://doi.org/10.2118/67184-MS

7. Lea J.F., Bearden J.L., Gas separator performance for submersible pump operation, Journal of Petroleum Technology, 1982, V. 34, no. 6, pp. 1327–1333,

DOI: https://doi.org/10.2118/9219-PA

8. Gadbrashitov I.F., Sudeyev I.V., Generation of curves of effective gas separation at the ESP intake on the basis of processed real measurements collected in the Priobskoye oil field, SPE-102272-RU, 2006, DOI: https://doi.org/10.2118/102272-RU

9. Gorid’ko, K.A., Kobzar’ O.S., The approach to determine the gas separator efficiency as a part of an electric submersible pump unit (In Russ.), Nauchnye trudy NIPI Neftegaz GNKAR, 2023, no. S1, pp. 9–20, DOI: https://doi.org/10.5510/OGP2023SI100831

10. Mikhaylov V.G., Petrov P.V., Mathematical model of separation of gas in the working chamber of the rotary gas separator (In Russ.), Vestnik UGATU, 2008, V. 10,

no. 1, pp. 21–29.

11. Harun A.F., Prado M.G., Shirazi S.A., An improved model for predicting separation efficiency of a rotary gas separator in ESP systems, SPE-63044-MS, 2000,

DOI: https://doi.org/10.2523/63044-MS

12. Ojeda, L.C.O., Olubode M., Karami H., Application of machine learning to evaluate the performances of various downhole centrifugal separator types in oil and gas production systems, SPE-213059-MS, 2023, DOI: https://doi.org/10.2118/213059-MS

13. Sharma A., Ojeda C.S., Yuan N., Predicting gas separation efficiency of a downhole separator using machine learning, Energies, 2024, V. 17, no. 11,

DOI: https://doi.org/10.3390/en17112655

14. Okafor C.C., Verdin P.G., 3D computational fluid dynamics analysis of natural gas separation efficiency in multiphase pumping wells with heterogeneous flow regime, Engineering Applications of Computational Fluid Mechanics, 2024, V. 18, no. 1, pp. 2395452–2395473, DOI: https://doi.org/10.1080/19942060.2024.2395452

15. Okafor C.C., Verdin P.G., Hart P., CFD investigation of downhole natural gas separation efficiency in the churn flow regime, SPE-204509-MS, 2021,

DOI: https://doi.org/10.2118/204509-MS

16. Liu B., Prado M., Application of a bubble tracking technique for estimating downhole natural separation efficiency, Journal of Canadian Petroleum Technology, 2004, V. 43, no. 5, DOI: https://doi.org/10.2118/04-05-05

17. Drozdov A.N., Stand Investigations of ESP’s and gas separator’s characteristics on gas-liquid mixtures with different values of free-gas volume, intake pressure, foaminess and viscosity of liquid, SPE-134198-MS, 2010, DOI: https://doi.org/10.2118/134198-MS

18. Drozdov A.N., Verbitckiy V.S., Arseniev A.A., Rotary gas separators in high GOR wells, field and lab tests comparison, SPE-117415-MS, 2008,

DOI: https://doi.org/10.2118/117415-MS

19. McCoy J.N., Podio A.L., Lisigurski O., A laboratory study with field data of downhole gas separators, SPE-96619-PA, 2007, DOI: https://doi.org/10.2118/96619-PA

20. Patent RU2075654C1. Method of tests of hydraulic machines and electric motors to them and test bed for realizing the method, Inventors: Drozdov A.N., Dem’yanova L.A.

The modern hydraulic fracturing (HF) fleet represents a high-end technological complex that comprises different hardware. Effective coordination of this hardware requires integrated control systems to ensure synchronous operation of all system components. The generalizations covering systematization of HF technological processes and specific recommendations for the development of integrated control systems based on cyber-physical principles are presented. A number of fundamental challenges were identified: the synthesis problem for the multiloop control systems with cross-coupling effects and significant delays; the issue of processing large volumes of heterogeneous real-time data; development of hybrid approaches combining deterministic physical models with machine learning methods to formalize the experience of a HF processes engineer under conditions of incomplete certainty. The architecture of next-generation HF process control systems should be modular and scalable. The physical level should include a high-performance data center that provides necessary computing resources; hardware control devices, distributed input-output modules, network infrastructure consisting of reliable high-speed wired communication lines and backup wireless connections to all equipment as well as external remote control systems if needed; ergonomic consoles equipped with multiple displays, voice communication systems, and operator workstation controls. During site and field tests it was determined that the key direction for further development of the HF fleet units’ control system should be a transitioning from centralized rigid architectures towards flexible, intelligent, fault-tolerant cyber-physical systems incorporating artificial intelligence models.

References

1. Kozinov A.E., Valiullina G.K., Kirsanov A.M. et al., Comprehensive scientific and technical approach to flow stimulation in abnormal sections of the Bazhenov suite

(In Russ.), Gazovaya promyshlennost’, 2025, no. 7(884), pp. 52–55.

2. Chen S., Li G, Reynolds A., Robust constrained optimization of short-and long-term net present value for closed-loop reservoir management, SPE-141314-PA, 2012, DOI: https://doi.org/10.2118/141314-PA

3. Okwy M., Nwachukwu A., A review of fuzzy logic application in petroleum exploration, production and distribution operations, Journal of Petroleum Exploration Technology, 2019, no. 9(2), pp. 1555–1568, DOI: https://doi.org/10.1007/s13202-018-0560-2

4. Schwenzer M., Muzaffer A., Bergs T., Abel D. Review on model predictive control: An engineering perspective, The International Journal of Advanced Manufacturing Technology, 2021, V. 117 (5), pp. 1327–1349, DOI: https://doi.org/10.1007/s00170-021-07682-3

5. Chai L., Zhong X., Chen F., Design and development of digital intelligent fracturing platform, Proceedings of the International Field Exploration and Development Conference 2022, pp. 7167–7187.

6. Wanasinghe R., Wroblewski L., Petersen B., Digital twin for the oil and gas industry: Overview research trends, opportunities and challenges, IEEE Access, 2020, V. 8, pp. 104175–104197, DOI: https://doi.org/10.1109/ACCESS.2020.2998723

7. Esipov D.V., Karanakov P.V., Lapin V.N., Chernyy S.G., Mathematical models of hydraulic fracturing (In Russ.), Vychislitel’nye tekhnologii, 2014, V. 19, no. 2, pp. 33–61.

Many oil fields in Russia have entered the final stages of development, accompanied by an increase in water cut, declining flow rates, inflow instability, and the development of a gas-oil ratio. Additional mechanical impurity removal, periodic gas locks, and compliance with electric submersible pump (ESP) operating conditions are required. Under these conditions, switching producing wells to intermittent sequential operation (ISO) is becoming one of the most effective approaches for maintaining stable growth. ISO enables the pump to operate at higher efficiency, reduces the impact of free gas, and lowers the risk of gas lock-in, creating more stable hydrodynamic conditions compared to continuous operation. The methods used to calculate ISO modes have some limitations. Many engineering approaches neglect the acceleration and deceleration stages of the ESP, although at short stages of the cycle, these phenomena significantly reduce the unit's productivity. Non-stationary inflow patterns, dynamic head changes, and the impact of free gas-induced pumping performance degradation are rarely observed. This paper proposes an improved methodology for determining optimal ISO parameters, considering the inertial processes that cause fluid evolution and bottomhole pressure changes during each phase of the cycle. It is shown that correct modeling of acceleration and transient hydrodynamic processes improves the accuracy of production forecasts and improves the balance between the duration of the accumulation and pumping phases. This approach can serve as the basis for the development of digital well management tools, including the integration of equipment degradation models and adaptive system modes for ESP operation at high gas-oil ratio.

References

1. Nazarova L.N., Razrabotka neftyanykh mestorozhdeniy s trudnoizvlekaemymi zapasami (Development of oil and gas fields with hard-to-recover reserves), Moscow: Publ. of Gubkin University, 2019, 340 p.

2. Mishchenko I.T., Skvazhinnaya dobycha nefti (Oil production), Moscow: Neft’ i gaz Publ., 2003, 816 p. 

3. Kuz’min N.I., Verbitskiy V.S., Khabibullin R.A. et al., Analysis of oil wells operation parameters and modes effects on electric submersible pumps reliability (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2024, no. 12, pp. 106–111, DOI: https://doi.org/10.24887/0028-2448-2024-12-106-111

4. Салихова А.Р., Сабиров А.А., Булат А.В., The improvement technique of running efficiency for electric vane pumps in the presence of abrasive particles in extractive fluids (In Russ.), Территория Нефтегаз, 2019, no. 5, pp. 50–55.

5. Yushchenko T.S., Demin E.V., Ivanov V.A. et al., Case studies and operation features of transient multiphase flow in low-flow wells with multistage fracturing and extended horizontal wellbore operated with ESP in PSA mode (In Russ.), PROneft’. Professional’no o nefti, 2024, V. 9, no. 1(31), pp. 78–94, DOI: https://doi.org/10.51890/2587-7399-2024-9-1-78-94

6. Юдин Е.В., Моисеев К.В., Латыпов Б.М. et al., 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 (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2025, no. 9, pp. 66–72, DOI: https://doi.org/10.24887/0028-2448-2025-9-66-72

7. Горидько К.А., Федоров А.Э., Хабибуллин Р.А. et al., The approach to estimating gas separation in a periodic operation mode of a well equipped by an electric submersible pump. Part 1 (In Russ.), Нефтепромысловое дело, 2025, no. 6(678), pp. 36–47.

8. Ivanov V.A., Verbitskiy V.S., Khabibullin R.A. et al., Experimental studies of natural separation at the intake of a submersible electric centrifugal pump (In Russ.), Delovoy zhurnal Neftegaz.RU, 2024, no. 8(152), pp. 78–84.

9. The OLGA 2022 User Manual, Version 2022, Schlumberger

10. Ivanov V.A., Khabibullin R.A., Yushenko T.S. et al., Razrabotka dinamicheskoy modeli skvazhiny v rezhime periodicheskogo kratkovremennogo vklyucheniya pogruzhnogo elektrotsentrobezhnogo nasosa (Development of a dynamic model of a well in the mode of periodic short-term switching on of a submersible electric centrifugal pump), Moscow: Publ. of Gubkin University, 2024, 89 p.

11. URL: https://www.petex.com/pe-engineering/ipm-suite/prosper/

12. URL: https://autotechnologist.com/

13. Rukovodstvo pol’zovatelya RN-ROSPUMP (RN-ROSPUMP User Manual), Moscow, 2023, URL: https://rn.digital/rospump/?ysclid=mgy57kvvkk548378977

14. Khabibullin R.A., Neftyanoy inzhiniring OLGA (Oil Engineering OLGA), URL: https://t.me/petroleum_olga

15. Virnovskiy A.S., Tateyshvili O.S., On the periodic operation of pumping wells (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 1957, no. 8, pp. 40–46.

16. RD 39-1-454-80. Metodika po ekspluatatsii malodebitnykh glubinnonasosnykh skvazhin v rezhime periodicheskoy otkachki (Methodology for the operation of low-flow deep wells in the periodic pumping mode).

17. Pashali A.A., Khalfin R.S., Sil’nov D.V. et al., On the optimization of the periodic mode of well production, which is operated by submergible electric pumps in Rosneft Oil Company (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2021, no. 4, pp. 92-96, DOI: https://doi.org/10.24887/0028-2448-2021-4-92-96 

18. Abdulin I.K., Leont’ev S.A., Development of a methodology for justification of a short-term periodic mode of wells operation equipped by electric centrifugal pumps

(In Russ.), Neftepromyslovoe delo, 2022, no. 9(645), pp. 73–76, DOI: https://doi.org/10.33285/0207-2351-2022-9(645)-73-76

19. Yudin E.V., Piotrovskiy G.A., Smirnov N.A. et al., Methods and algorithms for modeling and optimizing periodic operation modes of wells equipped with electric submersible pumps (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2023, no. 5, pp. 116-122, DOI: https://doi.org/10.24887/0028-2448-2023-5-116-122

Hydraulic fracturing (HF) is a key technology enabling efficient development of hard-to-recover oil reserves in ultra-low permeability reservoirs. The modern approach to field development is characterized by increasing horizontal wellbore length, a growing number of operations during multistage HF, and increasing actual mass of proppant per stage. As part of the Rosneft-2030 strategy, aimed at maintaining leadership in specific production costs with a target of 330 million tons of oil equivalent, Rosneft Oil Company is actively implementing modern approaches to HF. Supplying production companies with proppant, combined with technical and economic optimization of growing HF costs, became a necessary condition for maintaining oil production at a profitable level. A foremost promising direction for ensuring the required amount of proppant is the substitution of the overall share of ceramic proppant with alternative proppant materials, while it is necessary to consider a complex of factors including both physical-mechanical and filtration properties. Among important indicators of the physical-mechanical properties of proppant for conducting HF operations is abrasiveness, which affects equipment wear. In this paper, a historical analysis of approaches to assessing abrasive wear of process equipment was performed, and the current normative-technical framework regulating the process of proppant abrasiveness assessment was examined. Based on the identified limitations of existing methods, the authors propose a concept for creating a new experimental test rig. It’s key feature is the ability to simulate physical processes characteristic of HF operations, which should enable obtaining more reliable and relevant data on equipment wear.

References

1. Sadykov A.M., Kapishev D.Yu., Erastov S.A. et al., Innovative hydraulic fracturing designs and recommendations for putting wells into production in conditions of ultra-low-permeability reservoirs on the example of the Erginsky license block of the Priobskoye field (In Russ.), Ekspozitsiya Neft’ Gaz, 2022, no. 7(92), pp. 80–85,

DOI: https://doi.org/10.24412/2076-6785-2022-7-80-85

2. Woldman M., Van Der Heide E., Schipper D.J. et al., Investigating the influence of sand particle properties on abrasive wear behavior, Wear, 2014, V. 294–295, pp. 419–426.

3. Rosenberg S.J., The resistance of steels to abrasion by sand, Bureau of Standards Journal of Research, 1930, V. 5, no. 3, p. 553.

4. Salik J., Buckley D.H., Effect of erodent particle shape and various heat treatments on erosion resistance of plain carbon steel, NASA Technical Paper, 1981, 7 p.

5. Serdyuk A., Valeev S., Frolenkov A. et al., Improving economics of hard-to-recover reserves development. Case study of Achimov formation at Prirazlomnoe oil field, SPE-191722-18RPTC-RU, 2018, DOI: https://doi.org/10.2118/191722-18RPTC-RU

6. ASTM Standard G76. Standard test method for conducting erosion tests by solid particle impingement using gas jets, ASTM International, West Conshohocken,

PA, 2018, DOI: https://doi.org/10.1520/G0076-18

7. ASTM Standard G73. Standard test method for liquid impingement erosion using rotating apparatus, ASTM International, West Conshohocken, PA, 2021,

DOI: https://doi.org/10.1520/G0076-1810.1520/G0073-10R21

8. ASTM Standard G134. Standard test method for erosion of solid materials by cavitating liquid jet, ASTM International, West Conshohocken, PA, 2023,

DOI: https://doi.org/10.1520/G0076-1810.1520/G0134-17R23

9. ASTM Standard G134. Standard test method for determination of slurry abrasivity (miller number) and slurry abrasion response of materials (SAR Number), ASTM International, West Conshohocken, PA, 2021, DOI: https://doi.org/10.1520/G0076-1810.1520/G0075-15R21

10. Clark H.M., The influence of the flow field in slurry erosion, Wear, 1992, V. 152, no. 2, pp. 223–240, DOI: https://doi.org/10.1520/G0076-1810.1016/0043-1648(92)90122-o

The performed analysis established that the causes of abnormal heating during operation of electric submersible pumps (ESPs) in wells and pumping out water-oil-gas mixtures are associated with abnormal non-stationary operating modes – pump capacity breakdowns due to the negative effect of free gas on pump characteristics and difference in oil and water densities in heavily flooded wells. Various methods are given for preventing supply failures due to the effect of free gas and a large difference in oil and water densities. The failure of the ESP feed is caused by a decrease in the inflow from the formation, clogging of the intake screen, pump stages and tubing with mechanical impurities and solid phase deposits. Once ESP is used as part of pump-ejector systems, the failure of the feed occurs when the ejector nozzle is blocked by junk. During short-term periodic operation of low-flow wells by ESP units, another cause may occur, associated with additional heating of the well product flow from the stopped pump. Intensification of the processes of oil and water separation in wells during short-term periodic operation by ESP units contributes to an increased risk of failure of the feed and abnormal heating. The expediency of further designed experimental studies of temperature distribution along the length of a multistage ESP during pumping of gas-liquid mixtures with varying degrees of bubble coalescence suppression is shown, which shall serve as a basis for developing methods of calculation for heating the flow by a pump in stationary and non-stationary modes.

References

1. Gareev A.A., On the economic efficiency of oil production by electric centrifugal pumps (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2025, no. 1, pp. 60–63,

DOI: https://doi.org/10.24887/0028-2448-2025-1-60-63

2. Utev N.V., Peshcherenko S.N., Ovchinnikov T.A., The phenomenon of anomalous fluid superheating during periodic operation of oil wells (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2025, no. 2, pp. 66–70, DOI: https://doi.org/10.24887/0028-2448-2025-2-66-70

3. Drozdov A.N., Tekhnologiya i tekhnika dobychi nefti pogruzhnymi nasosami v oslozhnennykh usloviyakh (Technology and techniques for oil production using submersible pumps in difficult conditions), Moscow: MAKS press Publ., 2008, 312 p.

4. Lyapkov P.D., The influence of gas on the operation of the submersible centrifugal pump EN-95-800 (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 1958, no. 2, pp. 43–49.

5. Lyapkov P.D., Dunaev V.V., Results of testing the EN-160-800 pump in a well with gas in the produced fluid (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 1960, no. 2, pp. 48–51.

6. Balykin V.I., Drozdov A.N., Igrevskiy V.I. et al., Field testing of an ESP with a gas separator (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 1985, no. 1, pp. 62–65.

7. Minigazimov M.G., Sharipov A.G., Research of the influence of gas on the operation of the submersible centrifugal pump ECN5-80-800 (In Russ.), Neftepromyslovoe delo. – 1968. – № 7. – S. 34–38.

8. Minigazimov M.G., Sharipov A.G., Minkhayrov F.L., Research of the influence of gas on the operation of the submersible centrifugal pump ECN6-160-1100 (In Russ.), Proceedings of TatNII, 1971, V. 15, pp. 157–164.

9. Sharipov A.G., Minigazimov M.G., Study of the operation of the submersible centrifugal electric pump ECN5-130-600 on water-oil-gas mixtures (In Russ.), Proceedings of TatNII, 1971, V. 19, pp. 262–274.

10. Sharipov A.G., Study of the operation of the submersible centrifugal electric pump ECN5-80-800 on water-oil-gas mixtures (In Russ.), Proceedings of TatNIPIneft, 1975, V. 28, pp. 16–27.

11. Drozdov A.N., Drozdov N.A., N.F. Bunkin, Kozlov V.A., Study of suppression of gas bubbles coalescence in the liquid for use in technologies of oil production and associated gas utilization, SPE-187741-MS, 2017, DOI: https://doi.org/10.2118/187741-MS

12. Drozdov A.N., Gorelkina E.I., Operating parameters of the pump-ejector system under SWAG injection at the Samodurovskoye field (In Russ.), SOCAR Proceedings, 2022, Special Issue No. 2, pp. 9–18, DOI: https://doi.org/10.5510/OGP2022SI200734

13. Drozdov A.N., Chernyshov K.I., Kalinnikov V.N. et al., Water-gas mixtures injection into a reservoir by pump-ejector system using fresh and highly mineralized formation water (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2025, no. 2, pp. 54–57, DOI: https://doi.org/10.24887/0028-2448-2025-2-54-57

14. Drozdov A.N., Investigations of the submersible pumps characteristics when gas-liquid mixtures delivering and application of the results for swag technologies development (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2011, no. 9, pp. 108–111.

15. Drozdov A.N., Verbitskiy V.S., Shishulin V.A. et al., Study of the influence of foaming surfactants on the operation of a multistage centrifugal pump when pumping water-gas mixtures created by an ejector (In Russ.), SOCAR Proceedings, 2022, Special Issue No. 2, pp. 37–44, DOI: https://doi.org/10.5510/OGP2022SI200744

16. Lyapkov P.D., On the influence of liquid viscosity on the characteristics of submersible centrifugal pumps (In Russ.), Proceedings of 1964, V. XLI, pp. 71–107.

17. Kuptsov S.M., Teplofizicheskie svoystva plastovykh zhidkostey i gornykh porod neftyanykh mestorozhdeniy (Thermo-physical properties of reservoir fluids and rocks of oil fields), Moscow: Nedra-Biznestsentr Publ., 2008, 205 p.

18. Abakhri S.D., Perel’man M.O., Peshcherenko S.N., Rabinovich A.I., Influence of viscosity on centrifugal pumps’ working characteristics (In Russ.), Burenie i neft’, 2012, no. 3, pp. 22–26.

19. Makeev A.A., Optimizatsiya ekspluatatsii skvazhin v usloviyakh povyshennogo soleobrazovaniya (na primere plasta trias mestorozhdeniy Zapadnoy Sibiri) (Optimization of well operation in conditions of increased salt formation (using the Triassic formation of Western Siberian fields as an example)): thesis of candidate of technical science, Tyumen, 2022, 132 p.

20. Igrevskiy V.I., Drozdov A.N., Well development using a submersible centrifugal electric pump in a highly productive fractured formation (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 1987, no. 5, pp. 52–56.

21. Drozdov A.N., Bakhir S.Yu., Features of the operation of submersible pumping and pump-ejector systems at the Talinskoye field (In Russ.), Neftepromyslovoe delo, 1997, no. 3, pp. 9–16.

22. Patent RU2821934C1, Water intake well operation method, Inventors: Drozdov A.N., Gorelkina E.I.

23. Kuz’michev N.P., Short-term operation of wells for the production of viscous oil using ESP (In Russ.), Neftegaz.RU, 2015, no. 3, pp. 28–34.

This paper presents a comprehensive methodology for optimizing the placement of production and injection wells in hydrocarbon reservoirs using surrogate modeling based on neural operators. Traditional well placement optimization requires running a large number of full-scale reservoir simulations, making the process computationally expensive and time-consuming. To address this challenge, the study introduces a fast surrogate model built upon the Latent Neural Operator (LNO), capable of reproducing two-phase flow dynamics under varying geological conditions and various well configurations. The LNO model is trained on a large synthetic dataset which is generated using the industrial simulator tNavigator, comprising 2048 scenarios with randomized well placements. The architecture leverages the Physics-Cross-Attention mechanism to encode physical fields into a compact latent representation and decode them back to high-resolution spatial predictions. This enables accurate approximation of pressure and saturation distributions while remaining invariant to computational grid resolution. The trained model performs a one-year dynamic prediction in approximately 0,052 seconds, enabling rapid evaluation of thousands of scenarios. For optimization, a genetic algorithm is employed to maximize cumulative oil production given a fixed number of wells. The surrogate-based framework successfully identifies configurations that avoid low-permeability zones and improve overall reservoir performance. The results obtained demonstrate that LNO provides predictions comparable to full-physics simulations, although some inaccuracies remain near wellbore area due to error accumulation during autoregressive forecasting. The study highlights the potential of neural-operator-based surrogates to significantly accelerate field development planning and outlines future directions for improving near-well prediction accuracy and integrating surrogate-driven optimization with high-fidelity numerical validation.

References

1. Salasakar S., Prakash S., Thakur G., Recent trends in proxy model development for well placement optimization employing machine learning techniques, Modelling, 2024, V. 5, no. 4, pp. 1808–1823, DOI: https://doi.org/10.3390/modelling5040094

2. Tang H., Durlofsky L.J., Graph network surrogate model for optimizing the placement of horizontal wells for CO2 storage, 2024,

DOI: https://doi.org/10.2139/ssrn.4967577

3. Yudin E.V., Modelirovanie fil’tratsii zhidkosti v neodnorodnykh sredakh dlya analiza i planirovaniya razrabotki neftyanykh mestorozhdeniy (Modeling of fluid filtration in heterogeneous environments for the analysis and planning of oilfield development): candidate of physical and mathematical sciences, Moscow, 2014.

4. Badawi D., Gildin E., Neural operator-based proxy for reservoir simulations considering varying well settings, locations, and permeability fields, 2024,

DOI: https://doi.org/10.48550/arXiv.2407.09728

5. Tang H., Durlofsky L.J., Graph network surrogate model for subsurface flow optimization, Journal of Computational Physics, 2024, V. 512,

DOI: https://doi.org/10.1016/j.jcp.2024.113132

6. Li Z., Kovachki N., Azizzadenesheli K. et al., Multipole graph neural operator for parametric partial differential equations, Advances in Neural Information Processing Systems (NeurIPS), 2020, V. 33, pp. 6755–6766.

7. Wang T., Wang C., Latent neural operator for solving forward and inverse PDE problems, 2024, DOI: https://doi.org/10.48550/arXiv.2406.03923

8. Li Z. et al., Geometry-informed neural operator for large-scale 3D PDEs, Advances in Neural Information Processing Systems (NeurIPS), 2023,

DOI: https://doi.org/10.48550/arXiv.2309.00583

9. Yudin E.V. et al., Approach to a new wells performance planning in a low-permeability reservoirs (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2012, no. 11, pp. 25-29.

This article is devoted to the analysis of the current state and prospects for the development of automation and robotics on pipe tool sites in the oil and gas industry. The challenges faced by companies operating in this field are examined: a systematic increase in product turnover, increased safety requirements, and a high level of competition in the labor market, leading to increased costs for attracting qualified personnel. In addition, the ability of an oil producing enterprise to ensure minimal costs for the reuse of tubing and pumping rods is of great importance by performing timely accounting, monitoring and maintenance. The solution is to involve automation and robotics technologies in production processes that were not previously considered for implementation. An analysis of the operation of existing pipe tool sites (PTS) shows that most operations with tubing and pumping rods are performed manually, thereby increasing the dependence of production on the human factor and not ensuring the competitiveness of the oilfield service enterprise. To increase the efficiency of work, it is necessary to introduce modern robotic solutions into operations performed on PTS, which shall reduce production costs, reduce dependence on the human factor, and improve the quality of work performed and productivity of PTS. The article describes the existing problems of PTS, discusses solutions in the field of automation and robotization, presents the concept of robotization of technological operations at a PTS, and provides a rationale for the implementation of new solutions in this area.

References

1. Il’in K.O., Gubaydullin A.G., Khalfin R.S., Kraevskiy N.N., Concept and approaches for assessing the prospects of technological processes robotization in “NK “Rosneft” PJSC (In Russ.), Ekspozitsiya Neft’ Gaz, 2022, no. 4, pp. 48–53, DOI: https://doi.org/10.24412/2076-6785-2022-4-48-53

2. Selivanov S.G., Ivanova M.V., Teoreticheskie osnovy rekonstruktsii mashinostroitel’nogo proizvodstva (Theoretical foundations of the reconstruction of mechanical engineering production), Ufa: Gilem Publ., 2001, 312 p.

3. Il’in K.O., Gavrilova O.A., Kraevskiy N.N., Development of the concept of automation and robotization of technological operations for the repair of tubing (In Russ.), Ekspozitsiya Neft’ Gaz, 2022, no. 6, pp. 76–80, DOI: https://doi.org/10.24412/2076-6785-2022-6-76-80

This paper investigates the application of neural operators for accelerated modeling of reservoir fluid dynamics in field development tasks. Two state-of-the-art architectures – the Multipole Graph Kernel Network (MGKN) and the Latent Neural Operator (LNO) – are compared in terms of predictive accuracy and inference speed for forecasting the spatio-temporal evolution of pressure and water saturation of fields. The models were trained on a dataset generated by an industrial reservoir simulator, comprising 2620 well configurations and 37 time steps, and validated on a test set of 360 configurations with analysis over the first 12 time steps. Model performance is evaluated using the relative L1 error, which measures the average normalized deviation of predictions from reference solutions across all spatial nodes, time steps, and scenarios. The results show that both architectures accurately reproduce the spatio-temporal behavior of the reservoir system. The LNO model achieves nearly two times lower error in pressure prediction compared to MGKN and demonstrates a substantially higher computational efficiency, with inference time around 0,05 seconds on GPU. Despite a gradual accumulation of error during autoregressive forecasting, the models maintain acceptable stability over short-term horizons. Overall, LNO provides an advantageous balance between accuracy and computational performance, confirming the potential of neural operators for interactive optimization and large-scale scenario analysis in reservoir engineering.

References

1. Yudin E., Lubnin А., Simulation of multilayer wells operating, SPE-149924-MS, 2011< DOI: https://doi.org/10.2118/149924-MS

2. Yudin E.V., Gubanova A.E., Krasnov V.A., Method for estimating the wells interference using field performance data (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2018, no. 8, pp. 64–69, DOI: https://doi.org/10.24887/0028-2448-2018-8-64-69

3. Gege Wen, Zongyi Li, Azizzadenesheli K. et al., U-FNO: An enhanced Fourier neural operator-based deep-learning model for multiphase flow, Advances in Water Resources, 2022, V. 163, DOI: https://doi.org/10.1016/j.advwatres.2022.104180

4. Azizzadenesheli K., Kovachki N., Zongyi Li et al., Neural operators for PDEs, Advances in Neural Information Processing Systems (NeurIPS), 2020, V. 33, pp. 11562–11573.

5. Zongyi Li, Hongkai Z., Kovachki N. et al., Physics-informed neural operator for learning partial differential equations, ACM/IMS Journal of Data Science, 2021, V. 1,

no. 3, pp. 1–27, DOI: https://doi.org/10.1145/3648506

6. Zongyi Li, Kovachki N., Azizzadenesheli K. et al., Fourier neural operator for parametric partial differential equations, International Conference on Learning Representations (ICLR), 2021, DOI: https://doi.org/10.48550/arXiv.2010.08895

7. Zongyi Li, Kovachki N., Azizzadenesheli K. et al., Neural operator: Graph kernel network for partial differential equations, 2021, URL: https://arxiv.org/abs/2003.03485

8. Lu Lu, Pengzhan Jin, Guofei Pang et al., Learning nonlinear operators via DeepONet based on the universal approximation theorem of operators, Nature Machine Intelligence, 2021, V. 3, no. 3, pp. 218–229, DOI: https://doi.org/10.1038/s42256-021-00302-5

9. Jin Zh.L., Liu Y., Durlofsky L.J., Deep-learning-based surrogate model for reservoir simulation with time-varying well controls, Journal of Petroleum Science and Engineering, 2020, V. 192, DOI: https://doi.org/10.1016/j.petrol.2020.107273

10. Raissi M., Perdikaris P., Karniadakis G.E., Physics-informed neural networks: A deep learning framework for solving forward and inverse problems involving nonlinear partial differential equations, Journal of Computational Physics, 2018, V. 378, pp. 686–707, DOI: https://doi.org/10.1016/j.jcp.2018.10.045

11. Li Z., Kovachki N., Azizzadenesheli K. et al., Multipole graph neural operator for parametric partial differential equations, Advances in Neural Information Processing Systems (NeurIPS), 2020, V. 33, pp. 6755–6766.

12. Wang T., Wang C., Latent neural operator for solving forward and inverse PDE problems, 2024, DOI: https://doi.org/10.48550/arXiv.2406.03923

13. Yudin E.V., Gubanova A.E., Krasnov V.A., The method of express estimation of pore pressure map distribution in reservoirs with faults and wedging zones,

SPE-191582-18RPTC-MS, 2018, DOI: https://doi.org/10.2118/191582-18RPTC-MS

Currently, there is no single universal tool that would comprehensively calculate both flare systems and oil and gas treatment facilities. When designing new flare units or optimizing the operation of existing ones, software developed by various companies is used. It should also be noted that the calculations of flare systems are regulated by regulatory documents and GOSTs of the Russian Federation. Rosneft Oil Сompany developed the technological process modeling simulator RN-SIMTEP, designed to calculate the object parameters for well products gathering, treatment and transportation systems, including flare units, in accordance with the standards of the Russian Federation (certificate of compliance № ROSS RU.04PLK0.OS01.N00035). The tool is designed to solve problems at the stages of field design and operation and enables developing a project in a unified technological environment – from conceptual design to design and exploration work and production. The paper presents the features of various software tools for calculating flare systems. The comparative analysis includes calculation of flare header hydraulics, as well as thermal radiation and pollutant emissions. Unlike foreign and domestic analogues, RN-SIMTEP offers a wide range of methods for calculating flare systems in accordance with regulations of the Russian Federation, as well as the possibility of joint calculation of the flare system with oil and gas treatment. Thus, the tool enables reducing the financial costs of purchasing several software, the labor costs of transferring data from one software to another and minimizing errors caused by manual transfer.

References

1. Order of the Federal Service for Environmental, Technological and Nuclear Supervision No. 450 of 12/22/2021 “Ob utverzhdenii rukovodstva po bezopasnosti fakel’nykh sistem” (On approval of the safety guidelines for flare systems), Teplogazosnabzhenie,

URL: https://gktgs.ru/assets/app/files/prikaz_450%20ot%2022.12.21_rb_fs.pdf

2. Order of the Ministry of Emergency Situations of Russia dated July 10, 2009 No. 404 “Ob utverzhdenii metodiki opredeleniya raschetnykh velichin pozharnogo riska na proizvodstvennykh ob”ektakh” (On approval of the methodology for determining the calculated values of fire risk at industrial facilities),

URL: https://mchs.gov.ru/dokumenty/normativnye-pravovye-akty-mchs-rossii/667

3. Normy tekhnologicheskogo proektirovaniya gorizontal’no-fakel’nykh ustanovok i neytralizatorov promstokov dlya ob”ektov dobychi gaza (Standards for the technological design of horizontal flare units and industrial wastewater neutralizers for gas production facilities), URL: https://www.npp-pes.com/_files/ugd/db4713_d3367a705b8f4f4c881adc3237fc9a55.pdf

4. Metodika rascheta vybrosov vrednykh veshchestv v atmosferu pri szhiganii poputnogo neftyanogo gaza na fakel’nykh ustanovkakh (Methodology for calculating emissions of harmful substances into the atmosphere during the flaring of associated petroleum gas in flare units),

URL: https://meganorm.ru/Data2/1/4294849/4294849187.pdf

5. Metodika rascheta parametrov vybrosov vrednykh veshchestv ot fakel’nykh ustanovok szhiganiya uglevodorodnykh smesey (Methodology for calculating the parameters of emissions of harmful substances from flare units burning hydrocarbon mixtures), URL: http://www.omegametall.ru/Data2/1/4293832/4293832676.pdf

6. Order of Ministry of Natural Resources of Russia No. 273 of June 6, 2017“Ob utverzhdenii metodov raschetov rassevaniya vybrosov vrednykh (zagryaznyayushchikh) veshchestv v atmosfernom vozdukhe” (On approval of methods for calculating the dispersion of emissions of harmful (polluting) substances in the atmospheric air),

URL: https://docs.cntd.ru/document/456074826

7. https://integral.ru/

8. URL: https://digital.slb.ru/products/

9. URL: https://www.aspentech.com/en/products/engineering/aspen-flare-system-analyzer

10. Johnson A.D., Brightwell H., Carsley A.J., A model for predicting the thermal radiation hazards from large-scale horizontally released natural gas jet fires, Trans IChemE 94 Part B, 1994, pp. 157–168, URL: https://www.icheme.org/media/12116/xii-paper-09.pdf

This paper presents the development and industrial validation of a Graphics Processing Unit (GPU) - accelerated reservoir simulation system based on the Boundary Element Method (BEM). Traditional CPU-centric numerical simulators approached their performance limits, motivating the transition to massively parallel computing architectures. The proposed three-layer system integrates a Python-based control layer, a C++ hybrid computational core, and a CUDA subsystem responsible for high-throughput parallel processing. The BEM formulation enables natural task decomposition: the contribution of each well, fracture or boundary segment is computed independently, enabling efficient distribution across thousands of GPU threads and minimizing memory-access overhead. The system was evaluated on four real-field reservoir models ranging from simple homogeneous structures to large, highly heterogeneous assets. Benchmarking demonstrated substantial performance gains: GPU acceleration achieved speed-up factors between 40 and 124 compared with a CPU-only implementation. Double-precision calculations maintained high numerical accuracy, with average deviations below 2–2,5 %. Single-precision mode, while slightly less accurate (3–5 % deviation), provided maximum performance suitable for rapid scenario screening and interactive workflows. The results exhibit nearly linear scalability and high efficiency even when the model size was increased by an order of magnitude. Pressure-field maps and well-pressure dynamics confirm the physical consistency of the model outputs. Overall, the study demonstrates that the proposed GPU-accelerated BEM framework enables near real-time reservoir simulation while preserving engineering-grade accuracy. The architecture is compatible with existing digital workflows and offers a practical pathway for integrating high-performance GPU computing into routine reservoir-engineering decision-making.

References

1. Bayat M., Killough J.E., An experimental study of GPU acceleration for reservoir simulation, SPE-163628-MS, 2013, DOI: https://doi.org/10.2118/163628-MS

2. Zhao L., Li S., Zhang C.S. et al., An improved multistage preconditioner on GPUs for compositional reservoir simulation, CCF Transactions on High Performance Computing, 2023, V. 5, no. 2, pp. 136–151, DOI: https://doi.org/10.1007/s42514-023-00136-0

3. Middya U., Manea A., Alhubail M. et al., A massively parallel reservoir simulator on the GPU architecture, SPE-203918-MS, 2021, DOI: https://doi.org/10.2118/203918-MS

4. Dogru A.H., Fung L.S.K., Al-Shaalan T.M. et al., From mega-cell to giga-cell reservoir simulation, SPE-116675-MS, 2008, DOI: https://doi.org/10.2118/116675-MS

5. Dogru A.H., Fung L.S.K., Middya U. et al., A next-generation parallel reservoir simulator for gi-ant reservoirs, SPE-119272-MS, 2009,

DOI: https://doi.org/10.2118/119272-MS

6. Cao H., Zaydullin R., Liao T. et al., Adding GPU acceleration to an industrial CPU-based simulator, development strategy and results, SPE-203936-MS, 2021,

DOI: https://doi.org/10.2118/203936-MS

7. Esler K., Gandham R., Patacchini L. et al., A GPU-based, industrial grade compositional reservoir simulator, SPE-203929-MS, 2021,

DOI: https://doi.org/10.2118/203929-MS

8. Khrapov S.S., Khoperskov A.V., Smoothed-particle hydrodynamics models: implementation features on GPUs, Communications in Computer and Information Science, 2018, V. 793, pp. 266–277, DOI: https://doi.org/10.1007/978-3-319-71255-0_21

9. Illarionov E., Temirchev P., Voloskov D. et al., End-to-end neural network approach to 3D reservoir simulation and adaptation, Journal of Petroleum Science and Engineering, 2022, V. 208, DOI: https://doi.org/10.1016/j.petrol.2021.109332

10. Temirchev P., Gubanova A., Kostoev R. et al., Reduced order reservoir simulation with neural-network based hybrid model, SPE-196864-MS, 2019,

DOI: https://doi.org/10.2118/196864-MS

11. Petrosyants M., Illarionov E., Koroteev D., Speeding up the reservoir simulation by real time prediction of the initial guess for the Newton-Raphson’s iterations, Computational Geosciences, 2024, V. 28, pp. 477–493, DOI: https://doi.org/10.1007/s10596-024-10284-z

12. Crespo A.C., Dominguez J.M., Barreiro A. et al., GPUs, a new tool of acceleration in CFD: efficiency and reliability on smoothed particle hydrodynamics methods, PLoS ONE, 2011, V. 6, no. 6, DOI: https://doi.org/10.1371/journal.pone.0020685

13. Feng C., Shen S., Liu H. et al., Toward cost-effective reservoir simulation solvers on GPUs, Advances in Applied Mathematics and Mechanics, 2016, V. 8, no. 6,

pp. 971–991, DOI: https://doi.org/10.4208/aamm.2014.m842

14. Temirchev P., Simonov M., Kostoev R. et al., Deep neural networks predicting oil movement in a development unit, Journal of Petroleum Science and Engineering, 2019, V. 180, pp. 1019–1029, DOI: https://doi.org/10.1016/j.petrol.2019.06.016

15. Takahashi T., Hamada T., GPU-accelerated boundary element method for Helmholtz’ equation in three dimensions, International Journal for Numerical Methods in Engineering, 2011, V. 80, no. 10, pp. 1295–1321, DOI: https://doi.org/10.1002/nme.2661

16. Yudin E.V., Gubanova A.E., Krasnov V.A., The method of express estimation of pore pressure map distribution in reservoirs with faults and wedging zones,

SPE-191582-18RPTC-MS, 2018, DOI: https://doi.org/10.2118/191582-18RPTC-MS

17. Yudin E.V., Modelirovanie fil’tratsii zhidkosti v neodnorodnykh sredakh dlya analiza i planirovaniya razrabotki neftyanykh mestorozhdeniy (Modeling of fluid filtration in heterogeneous environments for the analysis and planning of oilfield development): candidate of physical and mathematical sciences, Moscow, 2014.

18. Yudin E. V., Gubanova A.E., Krasnov V.A., Method for estimating the wells interference using field performance data (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2018, no. 8, pp. 64–69, DOI: https://doi.org/10.24887/0028-2448-2018-8-64-69

The article covers the issue of implementing adaptive delta compression algorithm with a double edge for electric submersible pumps (ESP) monitoring systems. Nowadays in the upstream oil and gas sector, as a consequence of rapid digitalization, there is a sharp increase in the volume of data transmitted both at production sites and between fields and higher-level systems. Since any communications link both wired and wireless has inherent limits on data rate and throughput, various data-compression algorithms are used to optimize traffic. The design of such algorithms is determined by many factors, in particular the physical nature and process criticality of the transmitted parameters. This paper proposes an adaptive dual-threshold delta-compression algorithm for ESP monitoring systems that partitions the incoming data stream into values that do and do not require transmission, depending on the magnitude of change relative to the previous value. The thresholds themselves are defined by the metrological characteristics of the sensors and the specifics of the technological process. As a result of the study it is shown that data transmission can be approximately 80 % more efficient than with the use of other algorithms. Furthermore, the proposed algorithm demonstrates high fault tolerance to data loss in the communication channel.

References

1. Polyanskiy S., Yudin E., Slabetsky A. et al., Oil and gas production management: New challenges and solutions, SPE-212086-MS, 2022,

DOI: https://doi.org/10.2118/212086-MS

2. Zebzeev A.G., Method of block sporadic data transmission with dynamic setting of telemetry apertures in telemetry systems (In Russ.), Avtomatika i programmnaya inzheneriya, 2015, no. 1(11), pp. 37–44

3. Yudin E., Khabibullin R., Smirnov N. et al., New applications of transient multiphase flow models in wells and pipelines for production management, SPE-201884-MS, 2020, DOI: https://doi.org/10.2118/201884-MS

4. Yudin E., Khabibullin R., Smirnov N. et al., Modeling and optimization of ESP Wells operating in intermittent mode, SPE-212116-MS, 2022, DOI: https://doi.org/10.2118/212116-MS

5. GOST R MEK 870-6-1-98. Telecontrol equipment and systems. Part 6. Telecontrol protocols compatible with ISO standards and ITU-T recommendations. Section 1. Application context and organization of standards.

6. Krasnov A.N., Prakhova M.Yu., Kalashnik Yu.V. et al., Collection and routing of data at remote oil well pad sites (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2025, no. 8, pp. 101–107, DOI: https://doi.org/10.24887/0028-2448-2025-9-101-107

7. Krasnov A.N., Prakhova M.Yu., Novikova Yu.V., Mathematical simulating qualitative parameters of routing and clustering protocols in wireless data gathering networks, Proceedings of FarEastCon 2020: International Multi-Conference on Industrial Engineering and Modern Technologies, 6–9 October 2020, Vladivostok, Russia, 2020, DOI: https://doi.org/10.1109/FarEastCon50210.2020.9271165

8. Krasnov A.N., Kolovertnov G.Yu., Prakhova M.Yu., Khoroshavina E.A., Improving data transfer efficiency in a gas field wireless telemetry system, Arctic Environmental Research, 2018, V. 18, no. 1, pp. 14–20, DOI: https://doi.org/10.17238/issn2541-8416.2018.18.1.14

9. Zmeev D.O., Nazarov A.A., Ogranichenie nagruzki v telekommunikatsionnykh sistemakh (Load limiting in telecommunication systems), Collected papers “Informatsionno-telekommunikatsionnye tekhnologii i matematicheskoe modelirovanie vysokotekhnologichnykh sistem” (Information and telecommunication technologies and mathematical modeling of high-tech systems), Proceedings of All-Russian conference with international participation, 22–25 April 2014, Moscow: Publ, of RUDN University, 2014, pp. 91–93.

10. Lapshin V.Yu., Koval’kov D.A., Optimization of traffic service duration in a multiservice radio network with dynamic channel allocation on demand (In Russ.), Izvestiya instituta inzhenernoy fiziki, 2012, no. 3, pp. 49–53.

11. Chen N.N., Tsai Y.Y.S., Chang W., Uplink synchronization control technique and its environment-dependent performance analysis, Electronics Letters, 2003, V. 33,

pp. 1555–1757, DOI: https://doi.org/10.1049/el:20031091

12. Yudin E.V., Piotrovskiy G.A., Smirnov N.A. et al., Methods and algorithms for modeling and optimizing periodic operation modes of wells equipped with electric submersible pumps (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2023, no. 5, pp. 116-122, DOI: https://doi.org/10.24887/0028-2448-2023-5-116-122.

13. Yudin E.V., Piotrovskiy G.A., Smirnov N.A et al., Group optimization and modeling of mechanized wells operating in intermittent mode, SPE-222942-MS, 2024,

DOI: https://doi.org/10.2118/222942-MS

Within this study, catalysts of 80 % Fe-10 % Co/10 % Al2O3 were obtained via combustion synthesis of solutions. The high-percentage catalyst was synthesized by burning a solution as a result of the combined heat treatment of Fe(NO3)3-Al(NO3)3-C2H5NO2 components in a muffle furnace at 450 °C at a rate of 1 °C/min. The resulting catalyst was a powder with a specific surface area of 61 m2. The catalysts were tested in a horizontal reactor in the decomposition reaction of associated petroleum gas at 850 °C and 0,1 MPa for 6 hours. The synthesized catalyst sample, as well as the carbon nanomaterial obtained on it, were studied using scanning electron microscopy, transmission electron microscopy, energy-dispersive X-ray spectroscopy, low-temperature nitrogen adsorption and X-ray diffraction. The specific carbon yield ranged from 10 to 33 g/g of catalyst. The dependence of carbon yield (and hydrogen) from the temperature of the catalytic reaction was identified, which varies in the range 750°С < 800°C < 950°C < 850°C. The catalytic decomposition of methane on Fe-Co/Al2O3 led to the formation of a mixture of multilayer carbon nanotubes and pyrocarbon (the deposition of the latter intensifies starting from 800°C). A comparison of the obtained data with the activity of the 80 % Fe-10 %Mo/10 % Al2O3 system was carried out. It is noted that, along with the high catalytic activity of the Fe-Co/Al2O3 system, catalysts based on Fe-Mo/Al2O3 may be a good alternative for the implementation of the process of catalytic decomposition of methane and associated petroleum gas.

References

1. Yanqing Wang, Can Pan,Wei Chu et al., Environmental remediation applications of carbon nanotubes and graphene oxide: Adsorption and catalysis, Nanomaterials, 2019, V. 9, no. 3, pp. 439, DOI: https://doi.org/10.3390/nano9030439

2. Ciecierska E., Boczkowska A., Kurzydlowski K.J. et al., The effect of carbon nanotubes on epoxy matrix nanocomposites, Journal of Thermal Analysis and Calorimetry, 2012, V. 111, pp. 1019–1024, DOI: https://doi.org/10.1007/s10973-012-2506-0

3. Su D.S., Centi G., A perspective on carbon materials for future energy application, Journal of Energy Chemistry, 2013, V. 22, no. 2, pp. 151–173,

DOI: https://doi.org/10.1016/S2095-4956(13)60022-4

4. Kurmashov P.B., Ukhina A.V., Manakhov A. et al., Solution combustion synthesis of Ni/Al2O3 catalyst for methane decomposition: Effect of fuel, Appl. Sci., 2023,

V. 13, no. 6, p. 3962, DOI: https://doi.org/10.3390/app13063962

5. Kurmashov P.B., Popov M.V., Brester A.E. et al., Estimation of the efficiency of oxalic acid in the solution combustion synthesis of a catalyst for production of hydrogen and carbon from methane, Dokl. Chem., 2023, V. 511, pp. 209–216, DOI: https://doi.org/10.1134/S0012500823600426

6. Chamyani S., Salehirad A., Oroujzadeh N., Fateh D.S. Effect of fuel type on structural and physicochemical properties of solution combustion synthesized CoCr2O4

ceramic pigment nanoparticles, Ceramics International, 2018, V. 44, no. 7, pp. 7754–7760, DOI: https://doi.org/10.1016/j.ceramint.2018.01.205

7. Kaplan S.S., Sonmez M.S., Single step solution combustion synthesis of hexagonal WO3 powders as visible light photocatalysts, Materials Chemistry and Physics, 2020, V. 240, p. 122152, DOI: https://doi.org/10.1016/j.matchemphys.2019.122152

8. Shri K.M., Balamurugan S., Ashika S.A. et al., Oxalic acid-derived combustion synthesis of multifunctional nanostructured copper oxide materials, Emergent Mater., 2021, V. 4, pp. 1387–1398, DOI: https://doi.org/10.1007/s42247-021-00269-4

9. Torres D., Pinilla J.L., Suelves L., Cobalt doping of α-Fe/Al2O3 catalysts for the production of hydrogen and high-quality carbon nanotubes by thermal decomposition of methane, International Journal of Hydrogen Energy, 2020, V. 45, no. 38, pp. 19313–19323, DOI: https://doi.org/10.1016/j.ijhydene.2020.05.104

10. Karaismailoğlu M., Figen H.E., Baykara S.Z., Methane decomposition over Fe-based catalysts, International Journal of Hydrogen Energy, 2020, V. 45, no. 60,

pp. 34773–34782, DOI: https://doi.org/10.1016/j.ijhydene.2020.07.219

11. Chesnokov V.V., Zaikovskii V.I., Chichkan A.S., Buyanov R.A., The role of molybdenum in Fe–Mo–Al2O3 catalyst for synthesis of multiwalled carbon nanotubes from butadiene-1,3, Applied Catalysis A: General, 2009, V. 363, no. 1–2, pp. 86–92, DOI: https://doi.org/10.1016/j.apcata.2009.04.048. – EDN: LLSLUD

12. Palani V., Narayanan S.G., Pradeep Kumar A.R., Catalytic hydrogenation of agricultural residues to green diesel: Process optimization with FeMo/Al2O3 catalyst,

International Journal of Green Energy, 2025, V. 22, no. 13, pp. 2859–2876.

The bending radius of a pipe spool is one of the main parameters characterizing the stress-strain state of a pipeline. Diagnostic examination with inline inspection tools ensures the detection of spools with non-standardized bending radius. The paper describes a method for determining pipeline axis bending radius using ground laser scanning (GLS). This approach not only ensures high precision of determining the value of pipeline axis bending radius, but also enables determining the pipeline axis bending plane. Automation of measurement result processing ensures timely processing of GLS data and clarification of technical solutions to bring a pipe spool into a standardized state during actual work execution, when opening a pipe spool. The method described enables measuring the actual radius within the ranges of 50 m to 2500 m and more, the bending directions of opened pipe spools from 0 to 360° with an accuracy of at least 1%. Apart from determining pipeline axis bending parameters, GLS data is used to determine the dimensions of geometry defects, such as corrugations, dents, and skewed joints. When cutting out a spool on a pipeline, the use of GLS enables assessing the stress-strain state of the pipeline before cutting, and measuring the coaxiality of pipe spools after spool cutting. The GLS technology enables replacing the classical geodesic measurement methods during work execution, as-built surveying and, at the same time, ensuring the acquisition of high-precision pipe spool geometry data providing timely identification of pipeline deformations.

References

1. Dolgopolov D.V., Teoreticheskoe obosnovanie razrabotki tekhnologiy aerokosmicheskikh issledovaniy dlya sozdaniya geoprostranstvennykh modeley sistem truboprovodnogo transporta (Theoretical justification for the development of aerospace research technologies for the creation of geospatial models of pipeline transport systems): thesis of doctor of technical science, Novosibirsk, 2024, 233 p.

2. Kuznetsov T.I., Dolgopolov D.V., Baryshev A.I., Monitoring of main pipeline routes using airborne laser scanning and the GNSS differential subsystem (In Russ.),

Interekspo Geo-Sibir’, 2025, V. 4, pp. 189–196, DOI: https://doi.org/10.33764/2618-981X-2025-4-189-196

3. Azarov B.F., Modern methods of geodetic observations of deformations of engineering structures (In Russ.), Polzunovskiy vestnik, 2011, no. 1, pp. 19–29.

4. Patent RU2739869C1. Method of determining actual bending stresses of a pipeline, Inventors: Zakharov A.A., Kuznetsov T.I., Baryshev A.I., Fedotov A.L., Pokrovskaya E.A.

5. Certificate of state registration of a computer program RU2024615023. Programmnyy modul’ avtomatizirovannogo opredeleniya radiusov uprugogo izgiba sektsiy MT po dannym NLS (A software module for automated determination of elastic bending radii of main pipeline sections based on external laser scanning data), Authors: Kuznetsov T.I., Baryshev A.I., Pokrovskaya E.A., Fedotov A.L., Kaptur A.A., Grigor’ev L.V.

6. Dolgopolov D.V., Kuznetsov T.I., Akhundov A.G. et al., Three-dimensional geoinformation modeling of main pipeline facilities by laser scanning data to form the boundary of the allotment of land (In Russ.), Vestnik SGUGiT, 2025, V. 30, no. 4, pp. 117–130, DOI: https://doi.org/10.33764/2411-1759-2025-30-4-117-130

The article presents the experience in mitigation of biocorrosion on oil fields. Corrosion of equipment and pipelines on late-stage fields is an operational problem in the oil industry. Although it is often difficult to identify the leading mechanism of degradation, however, based on statistics from investigations of the failures causes, it can be stated that failures due to bacterial corrosion and corrosion under deposits account up to 34 % of the total number of failures occurring due to corrosion. Corrosion tests were conducted under statistical conditions on a model of formation water contaminated with sulfate-reducing bacteria (SRB) and a model of formation water without SRB. The results of tests showed that in the presence of the SRB cumulative culture, the general rate of the corrosion process increases by 2 times compared to a similar model of formation water that does not contain SRB. The most traditional method of combating bacterial contamination of deposits is the use of bactericides. However, often for conditions of fields in the late stages of development the use of bactericides is not an economically viable way to mitigate bacterial corrosion. A technical and economic assessment of measures aimed at mitigation of biocorrosion using impact treatment technology with technological equipment settling has been carried out. The technical and economic assessment showed that bactericidal treatments at fields in the late stage of development are unprofitable. Bactericide injection is most effective in combination with equipment cleaning from deposits for fields where bactericidal treatments have historically been used since commissioning.

References

1. Glushchenko V.N., Zelenaya S.A., Zelenyy M.Ts., Ptashko O.A., Biozarazhennost’ neftyanykh mestorozhdeniy (Automated processing of data from geophysical and geological-technological studies of oil and gas exploration wells and calculation of oil and gas reserves using computers), Ufa: Belaya reka Publ., 2012, 680 p.

2. Karachevskiy D.Yu., Valekzhanin I.V., Gilaev R.G. et al., The effect of deposits of mineral salts and corrosion products on the metal surface on the effectiveness of inhibitory protection (In Russ.), Problemy sbora, podgotovki i transporta nefti i nefteproduktov, 2025, no. 3(155), pp. 89-108, DOI: http://doi.10.17122/ntj-oil-2025-3-89-108

3. Nizamov K.R., Povyshenie ekspluatatsionnoy nadezhnosti neftepromyslovykh truboprovodov (Improving the operational reliability of oil field pipelines): thesis of doctor of technical science, Ufa, 2001.

4. Moon K.-M., Cho H.-R., Lee M.-H. et al., Electrochemical analysis of the microbiologically influenced corrosion of steels by sulfate-reducing bacteria, Metals and Materials International, 2007, V. 13, no. 3, pp. 211–216, DOI: https://doi.org/10.1007/BF03027807

5. Zav’yalov V.V., Problemy ekspluatatsionnoy nadezhnosti truboprovodov na pozdney stadia razrabotki mestorozhdeniy (Pipelines operating reliability problems in the late stages of field development), Moscow: Publ. of VNIIOENG, 2005, 332 p.

6. RD 39-0147103-350-89. Otsenka bakteritsidnoy effektivnosti reagentov otnositel’no adgezirovannykh kletok sul’fatvosstanavlivayushchikh bakteriy pri laboratornykh ispytaniyakh (Evaluation of the bactericidal efficiency of reagents against adherent cells of sulfate-reducing bacteria in laboratory tests), Moscow: Publ. of Ministry of Oil Industry, 1989, 14 p