The article shows that the upcoming development of the oil industry will be significantly affected by a number of events and trends that originated or developed in 2024. This determined the main framework for forecast estimates of the development of the oil sector for 2025-2026 and a more distant future. It is noted that the leading world analytical centers - the International Energy Agency (IEA), the OPEC Secretariat and the US Energy Information Administration - conduct assessments on a monthly basis. An analysis of these estimates made in January-June 2025 shows that there is currently no clear idea of either the trends in the upcoming development of the oil sector of the global economy or the volumes of demand for oil and other types of liquid fuels. A comparative analysis of the considered forecasts of OPEC, the US EIA and the IEA revealed that they show a tendency to adjust the energy transition concept of the OECD countries, which may lead to a revision of trends, as well as the volumes of global demand for oil and its production in the long term, towards their increase. Based on the analysis conducted, the article concludes that currently in the «Western» world there is a consensus on the long-term point of view of OPEC that the future energy needs of the world should be met in a comprehensive manner - both through the accelerated development of renewable energy sources and energy efficiency technologies, and the use of traditional hydrocarbon fuels.

References

1. Mastepanov A.M., Main results of the development of the oil sector of the global economy in 2024 in the assessments of leading foreign research centers (In Russ.), Energeticheskaya politika, 2025, no. 5(208), pp. 10–33.

2. OPEC. Monthly Oil Market Report, 16 June 2025, URL:https://momr.opec.org/pdf-download/

3. Budris A., Nefti mnogo ne byvaet: pochemu reshenie o roste dobychi v OPEK+ ne privelo k obvalu tsen (There is no such thing as too much oil: why the decision to increase production in OPEC+ did not lead to a collapse in prices), URL: https://www.forbes.ru/biznes/541340-nefti-mnogo-ne-byvaet-pocemu-resenie-o-roste-dobyci-v-opek-ne-pr...

4. OPEC. Monthly Oil Market Report, 15 January 2025, URL: https://www.opec.org/assets/assetdb/momr-january-2025.pdf

5. Short-Term Energy Outlook. STEO. U.S. Energy Information Administration, June 2025, URL: https://www.eia.gov/outlooks/steo/pdf/steo_full.pdf

6. IEA Oil 2025. Analysis and forecast to 2030, URL: https://iea.blob.core.windows.net/assets/018c3361-bc01-4482-a386-a5b2747ae82a/Oil2025.pdf

7. IEA. Oil Market Report, February 2025, URL: https://www.iea.org/reports/oil-market-report-february-2025

8. IEA. Oil Market Report, June 2025, URL: https://www.iea.org/reports/oil-market-report-june-2025

9. 2025 Outlook for Global Energy, 2025, URL: https://www.guinnessgi.com/insights/guinness-global-energy-outlook

10. bp Energy Outlook: 2024 edition, URL: https://www.bp.com/en/global/corporate/energyeconomics/energy-outlook.html

11. World Oil Outlook 2025. Organization of the Petroleum Exporting Countries. OPEC Secretariat, July 2025, URL: https://momr.opec.org/pdf-download/

12. Short-Term Energy Outlook. STEO. U.S. Energy Information Administration, July 2025, URL: https://www.eia.gov/outlooks/steo/pdf/steo_full.pdf

13. IEA. Oil Market Report, April 2025, URL: https://www.iea.org/reports/oil-market-report-april-2025

The article reflects the experience of studying carbonate deposits of the Osinsky productive horizon (O-1, B1 formation) within several areas located in the central part of the Nepa-Peleduy arch of the Nepa-Botuoba anteclise, which are the main resource base of Surgutneftegas PJSC in the territory of the Republic of Sakha (Yakutia). In the course of the research, a large amount of factual material was studied, including exploration and production data, transit drilling, core studies, the results of interpretation of 3D-seismic data, as well as the analysis of the main indicators of the development of hydrocarbon deposits of the O-1 formation. The second part of the article presents the results of a detailed correlation of the Osinsky horizon, as well as the main factors influencing the formation of reservoir rocks with increased filtration and capacitance properties. In the section of O-1 formation, four cyclic sequences were identified. It was established that in the central and northern parts of the studied area, the organogenic buildup of the Osinsky horizon developed in two stages, which led to the formation of two intervals of the reservoir layers separated by a package of low-permeability rocks and acting as independent targets for development. The combined influence of sedimentation heterogeneity of rocks and subsequent epigenetic processes - dolomitization, recrystallization, and selective leaching determines the development of high-capacity pore space in the reservoirs of the Osinsky horizon. The best reservoir properties are found in secondary dolomites of organogenic buildups, in which inherited cavernous-porous void space is formed.

References

1. Milovanova E.V., Postnikova O.V., Kitaeva I.A., Mechanism of formation of increased natural radioactivity of deposits of the Osinskiy horizon in the south of the Siberian platform (In Russ.), Trudy RGU nefti i gaza (NIU) imeni I.M. Gubkina, 2020, no. 2(299), pp. 16-27, DOI: https://doi.org/10.33285/2073-9028-2020-2(299)-16-27

2. Gubina E.A., Vinokurova O.A., Belomestnykh A.A., Quantitative assessment of bitumen content in oil deposits of the Osinsky productive horizon of Eastern Siberia (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2024, no. 1, pp. 42-46, DOI: https://doi.org/10.24887/0028-2448-2024-1-42-4

3. Gurova T.I., Chernova L.S., Potlova M.M. et al., Litologiya i usloviya formirovaniya rezervuarov nefti i gaza Sibirskoy platformy (Mingeo SSSR, SibNPO po geologo-razvedochnym rabotam) (Lithology and conditions of formation of oil and gas reservoirs of the Siberian platform (Mingeo of the USSR, SibNPO for geological exploration)), Moscow: Nedra Publ., 1988, 254 p.

4. Nikulina M.Yu., Nikulin E.V., Luk'yanov V.V. et al., Prospects for searching for oil and gas deposits in the Osinsky pay zone in the territory of Nepa-Botuoba anteclise of Eastern Siberia (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2023, no. 9, pp. 85-89, DOI: http://doi.org/10.24887/0028-2448-2023-9-85-89

5. Kuznetsov V.G., Ilyukhin L.N., Postnikova O.V. et al., Karbonatnye tolshchi Vostochnoy Sibiri i ikh neftegazonosnost' (Carbonate strata of Eastern Siberia and their oil and gas potential), Moscow: Nauchnyy mir Publ., 2000, 104 p.

6. Malkosh R.V., Romashev E.A., Lebedeva M.G., Ageychenko S.Yu., The studying of fracturing of O-1 layer of the Osinsky productive formation deposits of the central part of Nepa arch of Eastern Siberia (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2024, no. 3, pp. 35-40, DOI: https://doi.org/10.24887/0028-2448-2024-3-35-40

This study focuses on exploring the potential application of logging-while-drilling data to estimate permeability, which is essential for calculating the initial production rate and profile of horizontal wells with the intention to optimize well trajectory and improve its economic efficiency in real time. The dataset comprises information from horizontal wells drilled by Rosneft Oil Company between 2022 and 2024, including las-files with logging-while-drilling records and history-matched on actual initial production rates averaged along the well horizontal part absolute permeability values. To tackle this challenge, several machine learning models were developed, employing both classification and regression techniques. History-matched on actual initial production rates average well permeability was selected as the target variable, with number of averaged logging curve features serving as input parameters. The best-performing model demonstrated the ability to predict permeability required for estimating the initial production rate of horizontal wells with a mean error of 63 % and a median error of 24 %. As the result of the study, it is clearly shown that this approach to history-matched eligible for initial production rate calculation permeability estimation while drilling, utilising machine learning tools is promising. Furthermore, even at this stage the developed methodology already shows potential for enhancing technological and economic efficiency of Rosneft’s Oil Company new wells drilling program.

References

1. Nwulu E.O. et al., Machine learning applications in predictive maintenance: Enhancing efficiency across the oil and gas industry, International Journal of Engineering Research Updates, 2023, no. 5(1), pp. 13–27, DOI: https://doi.org/10.53430/ijeru.2023.5.1.0017

2. Lawal A. et al., Machine learning in oil and gas exploration: A review, IEEE Access, 2024, no. 12, pp. 19035–19058, DOI: https://doi.org/10.1109/access.2023.3349216

3. Choubey S., Karmakar G.P., Artificial intelligence techniques and their application in oil and gas industry, Artificial Intelligence Review, 2020, V. 54(04), pp. 1–19,

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4. Elkatatny S., Mahmoud M., Tariq Z., Abdulraheem A., New insights into the prediction of heterogeneous carbonate reservoir permeability from well logs using artificial intelligence network, Neural Comput & Applic., 2017, DOI: https://doi.org/10.1007/s00521-017-2850-x

5. Azbukhanov A.F., Kostrigin I.V., Bondarenko K.A. et al., Selection of wells for hydraulic fracturing based on mathematical modeling using machine learning methods

(In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2019, no. 11, pp. 38–42, DOI: https://doi.org/10.24887/0028-2448-2019-11-38-42

6. Yige Sun et al., Deep learning versus conventional methods for missing data imputation: A review and comparative study, Expert Systems with Applications, 2023,

V. 227, DOI: https://doi.org/10.1016/j.eswa.2023.120201

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9. Kudashov K.V., Antsupov V.E., Akimova D.A., New wells production rate forecast quality improvement due to calculated values achievement for objects with different geological, geophysical and technological parameters (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2023, no. 8, pp. 128–130, DOI: https://doi.org/10.24887/0028-2448-2023-8-128-130

10. Helle H.B., Bhatt A., Ursin B., Porosity and permeability prediction from wireline logs using artificial neural networks: a North Sea case study, Geophysical Prospecting, 2001, no. 49, pp. 431–444, DOI: https://doi.org/10.1046/j.1365-2478.2001.00271.x

11. Shokir E.M., Permeability estimation from well log responses, Journal of Canadian Petroleum Technology, 2006, V. 45(11), pp. 41–46,

DOI: https://doi.org/10.2118/06-11-05

This paper examines the geological, technical, and economic aspects of developing pore-fractured low-permeability reservoirs of the Berezovskaya suite in Western Siberia. The key challenges of such reservoirs are identified, including low productivity, high heterogeneity of filtration properties, and weak hydraulic connectivity within the fracture system. A review of both international and domestic experience in inflow stimulation methods is presented, covering artificial fracturing techniques such as hydraulic fracturing (HF), directional unloading (georipping), gas-dynamic impulse stimulation, and cyclic geomechanical treatments. Based on the analysis of geological conditions and field test results, a development strategy is proposed that combines artificial fracturing techniques with HF (to generate extended «main» fractures). A typical economic evaluation demonstrates that the proposed strategy is the most preferable, as it ensures a faster payback of the associated costs. Particular attention is devoted to a core study program aimed at experimental validation of the methodology which is determination of critical drawdowns, assessment of permeability enhancement, and investigation of fracture formation mechanisms in water-sensitive rocks. The prospects for scaling this approach across the region and the key factors determining its success are discussed. The results of this research may be applied in planning pilot-industrial projects and in developing regulatory and technical frameworks for the development of hard-to-recover gas reserves of the Berezovskaya suite and similar reservoirs.

References

1. Afonin I.V., Onskul’ E.A., Mineralogo-geokhimicheskie osobennosti i usloviya formirovaniya berezovskoy svity na primere Kharampurskogo mestorozhdeniya (Zapadnaya Sibir’) (Mineralogical and geochemical features and conditions of formation of the Berezovskaya suite on the example of the Kharampur deposit (Western Siberia)), Collected papers “Dinamika i vzaimodeystvie geosfer Zemli” (Dynamics and interaction of the Earth’s geospheres), Proceedings of All-Russian conference with international participation dedicated to the 100th anniversary of training specialists in the field of Earth sciences at Tomsk State University, Part 3, Tomsk, 08–12 November 2021, Tomsk: Publ. of Tomsk Center for Scientific and Technical Information, 2021, pp. 150-152.

2. Gordeev A.O., Doroshenko A.A., Osipov S.V., Reviewing the results of testing the Berezovskaya Formation reservoirs in West Siberia (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2024, no. 4, pp. 84-89, DOI: https://doi.org/10.24887/0028-2448-2024-4-84-89

3. Agalakov S.E., Geologiya i gazonosnost’ verkhnemelovykh nadsenomanskikh otlozheniy Zapadnoy Sibiri (Geology and gas potential of the Upper Cretaceous post-Cenomanian deposits of Western Siberia): thesis of doctor of geological and mineralogical science, Tyumen, 2019.

4. Indrupskiy I.M., Ibragimov I.I., Tsagan-Mandzhiev T.N. et al., Laboratory, numerical and field assessment of the effectiveness of cyclic geomechanical treatment on a Tournaisian carbonate reservoir (In Russ.), Zapiski Gornogo instituta, 2023, V. 262, pp. 581–593, DOI: https://doi.org/10.31897/PMI.2023.5

5. Khristianovich S.A., Kovalenko Yu.F., Kulinich Yu.V., Karev V.I., Increasing the productivity of oil wells using the geo-loosening method (In Russ.), Neft’ i gaz Evraziya, 2000, no. 2, pp. 90-94.

6. Karev V.I., Kovalenko Yu.F., Khimulya V.V., Shevtsov N.I., Parameter determination of the method of directional unloading of the reservoir based on physical modelling on a true triaxial loading setup (In Russ.), Zapiski Gornogo instituta, 2022, V. 258, pp. 906–914, DOI: https://doi.org/10.31897/PMI.2022.95

7. Karev V.I., Kovalenko Yu.F., Kulinich Yu.V., Khristianovich S.A., Increasing the productivity of oil wells using the geo-loosening method (In Russ.), Neft’ i gaz Evraziya, 2000, no. 2, pp. 90–94.

8. Barkov S.O., Geomekhanicheskoe modelirovanie mekhanicheskikh i fil’tratsionnykh protsessov v nizkopronitsaemykh neftegazovykh plastakh v usloviyakh slozhnogo nagruzheniya (Geomechanical modeling of mechanical and filtration processes in low-permeability oil and gas reservoirs under complex loading conditions): thesis of candidate of physical and mathematical science, Moscow, 2024.

9. Kruglov Ya.A., Tyukavkina O.V., Development of gas-dynamic fracturing technology (testing at production sites with a terrigenous reservoir type) (In Russ.), Ekspozitsiya Neft’ Gaz, 2024, no. 8. pp. 87–93, DOI: https://doi.org/10.24412/2076-6785-2024-8-87-93

10. Indrupskiy I.M., Ibragimov I.I., Tsagan-Mandzhiev T.N. et al., Kompleksnye issledovaniya mekhanizma i effektivnosti tsiklicheskogo geomekhanicheskogo vozdeystviya na karbonatnyy kollektor turneyskogo yarusa (Comprehensive studies of the mechanism and efficiency of cyclic geomechanical impact on the Tournaisian carbonate reservoir), Collected papers “Fundamental’nyy bazis innovatsionnykh tekhnologiy neftyanoy i gazovoy promyshlennosti” (Fundamental basis of innovative technologies in the oil and gas industry), Proceedings of All-Russian scientific conference with international participation dedicated to the 35th anniversary of the Institute of Oil and Gas Geophysics of the Russian Academy of Sciences, Moscow, 17–19 October, 2022, Moscow: Publ. of Institute of Oil and Gas Problems of the Russian Academy of Sciences, 2022, pp. 4–8.

11. Kalabin A.A., Mitrofanov D.A., Gordeev A.O., An integrated approach to core & logging data interpretation to study the fracturing of Berezovsky reservoirs of West Siberian field (In Russ.), Ekspozitsiya Neft’ Gaz, 2021, no. 6(85), pp. 52-55, DOI: https://doi.org/10.24412/2076-6785-2021-6-52-55

12. Karev V.I., Khimulya V.V., Shevtsov N.I., Experimental studies of the deformation, destruction and filtration in rocks: A review (In Russ.), Izvestiya Rossiyskoy akademii nauk. Mekhanika tverdogo tela = Mechanics of Solids, 2021, no. 5, pp. 3-26, DOI: https://doi.org/10.31857/S0572329921050056

13. Trends in U.S. Oil and Natural Gas Upstream Costs, U.S., Energy Information Administration, March 2016, Washington, DC 20585

14. Patent 2747944 C1 RF, Method for stratification of homogeneous upper crealy silicy thickness, Inventors: Agalakov S.E., Marinov V.A., Kudamanov A.I.,

Novoselova M.Yu.

15. Patent 2742077 C1 RF, Method of localising hydrocarbon reserves in siliceous deposits of the late cretaceous, Inventors: Agalakov S.E., Novoselova M.Yu., Kudamanov A.I., Marinov V.A.

16. Patent 2745640 C1 RF, Method of gas deposit development in low permeable siliceous opokamorphic reservoirs, Inventors: Gordeev A.O., Melikov R.F., Kalabin A.A., Loznyuk O.A., Shaybakov R.A., Korolev A.Yu., Gabuniya G.B.

17. Sukhodolov Ya.A., The eastern gas program implementation and the prospects of East Siberian gas resources development (In Russ), Izvestiya Irkutskoy gosudarstvennoy ekonomicheskoy akademii, 2014, no. 6(98), pp. 63–71, DOI: https://doi.org/10.17150/1993-3541.2014.24(6).63-71

The purpose of the article is to conduct interdisciplinary research within the framework of a new scientific direction related to thrust vector control within a full geometric sphere, when the thrust vector deviation angle can vary in the range from 180о to -180о, in any direction. One of the patented options for energy distribution in a multi-flow jet system is described. The distribution of the working gas energy is considered using an example of a blade machine capable of operating both in the axial fan mode and in the centrifugal fan mode. The area of the critical section of the channel can be adjusted using an analogue of an iris diaphragm. Some prospects for the practical application of the obtained results are shown. To create promising control systems and to train designers, it is proposed to use the Euler's methodology and CFD technologies. Options for complete and partial channel overlapping are considered to change the operating mode with a change in the direction of the thrust vector, the thrust vector module, with a change in coordinates at the initial point of force application. A scientific basis was prepared for the development of multi-flow jet systems based on Euler's methodology. Two main directions for the development of scientific research are considered: energy-saving power engineering and transport systems (on land, at sea, in the air).

References

1. Sazonov Y.A., Mokhov M.A., Bondarenko A.V. et al., Investigation of a multiflow ejector equipped with variable-length links for thrust vector control using Euler’s methodology, Eng, 2024, V. 5, pp. 2999–3022, DOI: https://doi.org/10.3390/eng5040156

2. Sazonov Y.A., Mokhov M.A., Bondarenko A.V. et al., Study of reversible nozzle apparatuses using euler methodology and CFD technologies, Civil Engineering Journal (Iran), 2024, V. 10(11), pp. 3640–3671, DOI: https://doi.org/10.28991/CEJ-2024-010-11-013

3. Zhang T., Strbac G., Novel artificial intelligence applications in energy: A systematic review, Energies, 2025, no. 18, DOI: https://doi.org/10.3390/en18143747

4. Zhang Weiwei, Zhao Shule, Envisioning the blueprint: Aeronautics in large models era, Chinese Journal of Aeronautics, 2025, V. 38, no. 8, DOI: https://doi.org/10.1016/j.cja.2025.103607.

5. Gorokhov V.G., Evolyutsiya inzhenerii: ot prostoty k slozhnosti (The evolution of engineering: from simplicity to complexity), Moscow: Publ. of Institute of Philosophy of the Russian Academy of Sciences, 2015, URL: https://gtmarket.ru/library/basis/7366

6. Ackoff R.L., Magidson J., Addison H.J., Idealized design: How to dissolve tomorrow’s crisis… Today creating an organization’s future, Wharton School PubIishing, 2006.

7. Hasib Sh.A., Gulzar M.M., Oishy S.R. et al., An investigation of innovative strategies in underwater soft robotics, Engineering Science and Technology, an International Journal, 2025, V. 70, DOI: https://doi.org/10.1016/j.jestch.2025.102123

8. US Patent 2446266. Jet propelled helicopter rotor, Inventor: Thomas L., URL: https://www.freepatentsonline.com/2446266.pdf

9. Schäfer Y., Stößel M., Barnique A. et al., Effects of tip injection on a turbofan engine with non-invasive high-speed actuators, Int. J. Turbomach. Propuls., 2025,

V. 10, 9, DOI: https://doi.org/10.3390/ijtpp10020009

10. Luo Y., Wu Z., Li Z. et al., Design of a novel pump cavitation valve and study of its cavitation characteristics, Water, 2025, V. 17,

DOI: https://doi.org/10.3390/w17101503

11. Mena-Arciniega C., Criollo L., Xing S., Topology optimization methods for morphing aircraft design: a review, Aviation, 2024, V. 28(4), pp. 292–305,

DOI: https://doi.org/10.3846/aviation.2024.22596

12. Yun J.-E., Shin J.-Y., Harsito C. et al., Turbine performance of variable geometry turbocharger applied to small gasoline engine considering heat transfer effect, Energies, 2025, V. 18, DOI: https://doi.org/10.3390/en18143775

13. Fang S., Zhang S., Zhou J., Yang W., A high-efficient modeling method for aerodynamic loads of an airfoil with active leading edge based on RFA and CFD, Aerospace, 2025, V. 12, DOI: https://doi.org/10.3390/aerospace12070632

14. Xu T., Meng W., Zhang J., Energy optimal trajectory planning for the morphing solar-powered unmanned aerial vehicle based on hierarchical reinforcement learning, Drones, 2025, V. 9(7), DOI: https://doi.org/10.3390/drones9070498

15. Fazylova A., Alipbayev K., Myrzabekov K. et al., The aerodynamically driven orientation control of a solar panel on an aircraft with numerical simulation, Drones, 2025, V. 9, DOI: https://doi.org/10.3390/drones9070458

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17. Sorokin V.A., Yanovskiy L.S., Kozlov V.A. et al., Raketno-pryamotochnye dvigateli na tverdykh i pastoobraznykh toplivakh (Rocket-ramjet engines on solid and paste fuels), Moscow: Fizmatlit Publ., 2010, 318 p.

18. Shanmugam P., Kanjikovil Mahali P., Raja S., An efficient SDOF sweep wing morphing technology for eVTOL-UAV and experimental realization, Drones, 2025, V. 9, DOI: https://doi.org/10.3390/drones9060435

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22. Patent 2778961 C1 RF, Jet pump unit, Inventors: Sazonov Yu.A., Mokhov M.A., Tumanyan Kh.A., Frankov M.A., Voronova V.V., Balaka N.N.

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The article under consideration provides a comprehensive analysis and covers current achievements of multistage hydraulic fracturing (MSHF) technology development at Zarubezhneft’s JSC assets, including the Kharjaga field in the Russian Federation and offshore projects in Socialist Republic of Vietnam being developed under the Vietsovpetro joint venture. It examines advanced engineering solutions for improving the efficiency of low-permeability reservoir development, with a focus on geomechanical modeling and ball-activated frac-port completion systems. The study highlights the adaptation of these technologies to challenging geological conditions, such as high vertical and lateral heterogeneity of formations and water breakthrough risks. Key pilot projects are discussed in detail, including the first successful MSHF operation in a directional well offshore Vietnam and the implementation of MSHF in a multilateral well at the Artinskian reservoir in the Kharjaga field. The conducted analysis covers technological and infrastructural constraints of offshore operations, such as limited pumping capacity and seasonal weather impacts. The article outlines prospective development directions, such as transitioning to horizontal and semi-horizontal wells with MSHF, deploying high-capacity pumping equipment, and utilizing specialized vessels to scale up operations. The following innovations are aimed to enhance the economic viability of developing complex reservoirs while maintaining operational safety and efficiency.

References

1. Astaf’ev V.N., Mazhirin Yu.A., Abdullin R.F. et al., Development of hydraulic fracturing technologies in modern conditions (based on the materials of the 2nd technological forum “Hydraulic fracturing technologies”; 20.11.2023-21.11.2023, Novosibirsk) (In Russ.), Geologiya i mineral’no-syr’evye resursy Sibiri, 2024, no. 2(58), pp. 100-109, DOI: https://doi.org/10.20403/2078-0575-2024-2-100-109

2. Klevtsov A.S., Grishchenko E.N., Balenko P.S. et al., Features of hydraulic fracturing planning and implementation while developing the low permeable highly dissected Oligocene reservoirs of Vietnam offshore fields (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2020, no. 9, pp. 114–118, DOI: https://doi.org/10.24887/0028-2448-2020-9-114-118

3. Ivanov A.N., Zyong Zan’ Lam, Vasil’ev V.A., Exploration of the Oligocene dense sandstone reservoirs potential of Nam Con Son shelf basin (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2006, no. 4, pp. 112–114

4. Sadovnikov A.A., Klevtsov A.S., Kozyk S.S., Enhanced recovery techniques in the white tiger oilfield: Analysis of the effective use (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2018, no. 11, pp. 88–90, DOI: https://doi.org/10.24887/0028-2448-2018-11-88-90

5. Hoang Long, Phung Dinh Thuc, Nguyen Minh Quy, Study on applied technologies to propose solutions for enhancing hydraulic fracturing efficiency in tight sandstone reservoirs of the Cuu Long basin, Petrovietnam Journal, 2024, no. 06, pp. 22–30, DOI: https://doi.org/10.47800/PVSI.2024.06-03

Development of digital twins to describe multiphase flows in wells, gathering systems, and wellstream processing requires precise mathematical models capable of simulating phase transitions in multicomponent mixtures. Currently, Western software products dominate the market for PVT modeling of hydrocarbon mixtures. However, their commercial licensing, proprietary (closed-source) nature, and lack of adaptability to industry-specific needs limit their applicability. Consequently, the development of domestic software for modeling reservoir fluid phase behavior is a critical priority for the oil and gas industry. This paper presents the results of compositional modeling of multiphase hydrocarbon systems with abnormal properties due to their unique composition, using a proprietary PVT calculator. The authors detail the implementation of a software algorithm for calculating hydrocarbon phase behavior under specified pressure-temperature (PT) conditions based on a cubic equation of state (EOS). The simulation results are compared with those from established commercial software and laboratory experimental data. Simplified approaches to compositional modeling of gas-condensate mixtures are analyzed, particularly those relying on empirical correlations. A comparative study of various computational methods for determining the dew-point pressure of gas-condensate mixtures is conducted using field examples of a field in Russia. The study demonstrates that empirical correlations have significant limitations in applicability across broad pressure and temperature ranges, whereas classical equations of state accurately describe fluid phase behavior under dynamic PT conditions corresponding to all stages of production.

References

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

2. Lubnin A.A., Yudin E.V., Fazlytdinov R.F. et al., A new approach of gas lift wells production optimization on offshore fields (In Russ.), SPE-181903-MS, 2016,

DOI: https://doi.org/10.2118/181903-MS

3. Malyshev V.L., Moiseeva E.F., Kalinovskiy Yu.V., Calculation of compressibility factor of main natural gas components by means of molecular dynamics simulations

(In Russ.), Izvestiya Tomskogo politekhnicheskogo universiteta. Inzhiniring georesursov = Bulletin of the Tomsk Polytechnic University. Geo Assets Engineering, 2019, V. 330, no. 11, pp. 121–129, DOI: https://doi.org/10.18799/24131830/2019/11/2356

4. Yudin E., Khabibullin R., Galyautdinov I. et al., Modeling of a gas-lift well operation with an automated gas-lift gas supply control system available to purchase

(In Russ.), SPE-196816-MS, 2019, DOI: https://doi.org/10.2118/196816-MS

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

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6. Peneloux A.A. Rauzy E., Freze R., Consistent volume correction for Redlich-Kwong-Soave volumes, Fluid Phase Equilibra, 1982, V. 8, pp. 7–23,

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7. 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

8. 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.

9. 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

10. Abasov M.T., Abbasov Z.Ya., Fataliev V.M. et al., New views on the parameter of dew point of the gascondensate system and the new method for it determination

(In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2011, no. 2, pp. 97–99.

11. Nemeth L.K. Kennedy H.T., A correlation of dewpoint pressure with fluid composition and temperature, Society of Petroleum Engineers Journal, 1967, V. 7, no. 2,

pp. 99–104, DOI: https://doi.org/10.2118/1477-PA

12. Humoud A.A., Al-Marhoun M.A., A new correlation for gas condensate dew-point pressure prediction, SPE-68230-MS, 2001,

DOI: https://doi.org/10.2523/68230-MS

13. Marruffo J., Maita J., Him G., Rojas G., Statistical forecast models to determine retrograde dew pressure and C7+ percentage of gas condensates on basis of production test data of eastern Venezuelan reservoirs, SPE-69393-MS, 2002, DOI: http://doi.org/10.2118/69393-MS

14. Ahmadi M.A., Elsharkawy A., Robust correlation to predict dew point pressure of gas condensate reservoirs, Petroleum, 2017, V. 3, no. 3, pp. 340–347,

DOI: https://doi.org/10.1016/j.petlm.2016.05.001

15. Al-Marhoun M.A., Evaluation of empirically derived PVT properties for Middle East crude oils, Journal of Petroleum Science and Engineering, 2004, V. 42, no. 2–4, pp. 209–221, DOI: https://doi.org/10.1016/j.petrol.2003.12.012

16. El-hoshoudy A., Dessouky S., Gomaa S., Prediction of dew point pressure in gas condensate reservoirs based on a combination of gene expression programming (GEP) and multiple regression analysis, Petroleum & Petrochemical Engineering Journal, 2018, V. 2, DOI: https://doi.org/10.23880/PPEJ-16000163

17. Nnadozie O., A new analytical method for predicting dew point pressure for gas condensate reservoirs, SPE-162985-MS, 2012,

DOI: http://doi.org/10.2118/162985-MS

18. Shokir El-M., Dewpoint pressure model for gas condensate reservoirs based on genetic programming, SPE-114454-MS, 2008,

DOI: https://doi.org/10.2118/114454-MS

19. Kamari A., Sattari M., Mohammadi A.H., Ramjugernath D., Rapid method for the estimation of dew point pressures in gas condensate reservoirs, Journal of the Taiwan Institute of Chemical Engineers, 2016, V. 60, pp. 258–266, DOI: https://doi.org/10.1016/j.jtice.2015.10.011

20. Wang H.Y., Liu H., Chang L.J. et al., Comparison and development of predictive models for dew point pressure of gas condensate reservoir fluids, Natural Gas Geoscience, 2013, V. 24(4), pp. 853-858.

The article is devoted to the development of contact deposits of oil fringes, which is often complicated by high heterogeneity of reservoir properties, as well as an unfavorable ratio of fluid mobility of water- and gas-bearing horizons relative to oil. These features of the objects lead to the risks of premature disintegration of the fringe, breakthrough of non-targeted fluids to production wells, reduction of the coefficients of coverage and displacement, and, as a result, low efficiency of the final development of reserves. At the same time, the development of sub-gas deposits requires the search for effective ways to utilize or benefit from significant volumes of associated gas, given the limited markets, transportation infrastructure, and distance of the deposit from major consumers.

This paper provides a review of gas and gas-chemical methods for increasing oil recovery in order to increase the production of liquid hydrocarbons and increase the share of useful use of associated gas. The paper analyzes the applicability of these methods for one of the Gazprom Neft's oil and gas condensate fields (field N), proposes a promising Low Tension Gas (LTG) technology which combines the effects of residual oil mobilization by reducing the interfacial tension and controlling the mobility of the displacement agent by creating stable foam in a porous medium.

References

1. Jhaveri Bh. et al., Review of BP’s global gas injection projects, SPE-171780-MS, 2014, DOI: https://doi.org/10.2118/171780-MS

2. Alvarado V., Manrique E., Enhanced oil recovery: An update review, Energies, 2010, V. 3, pp. 1529–1575, DOI: https://doi.org/10.3390/en3091529

3. Thomas S., Enhanced oil recovery - An overview, Oil and Gas Science and Technology – Institut franais du ptrole, 2007, V. 63, No. 1, pp. 9-19,

DOI: http://doi.org/10.2516/ogst:2007060

4. Shi J.X., Simulation and experimental studies of foam for enhanced oil recovery, Texas: Dissertation, The University of Texas at Austin, 1996.

5. Li R.F., Wei Yan, Shunhua Liu et al., Foam mobility control for surfactant EOR, SPE-113910-MS, 2008, DOI: https://doi.org/10.2118/113910-MS

6. Turta A.T., Singhal A.K., Field foam applications in enhanced oil recovery projects: Screening and design aspects, Journal of Canadian Petroleum Technology, 2002,

V. 41(10), DOI: https://doi.org/10.2118/02-10-14

7. Shan D., Simulation study of gravity override for foam processes, Texas: The University of Texas at Austin, 2001.

8. Rossen W.R., Van Duijn C.J., Gravity segregation in steady-state horizontal flow in homogenous reservoirs, Journal of Petroleum Science and Engineering, 2004,

V. 43, pp. 99–111, DOI: https://doi.org/10.1016/j.petrol.2004.01.004

9. Blaker T., Aarra M.G., Skauge A. et al., Foam for gas mobility control in the Snorre field: The FAWAG project, SPE-78824-PA, 2022,

DOI: http://doi.org/10.2118/78824-PA

10. Martin F.D., Laboratory investigations in the use of polymers in low permeability reservoirs, SPE-5100-MS, 1974, DOI: https://doi.org/10.2118/5100-MS

11. Srivastava M., Foam assisted low interfacial tension enhanced oil recovery process, Texas: The University of Texas at Austin, 2010.

12. Srivastava M., Zhang J., Nguyen Q.P., Pope G.A., A systematic study of alkaline-surfactant-gas injection as an EOR technique, SPE-124752-MS, 2009,

DOI: https://doi.org/10.2118/124752-MS

13. Szlendak S.M., Nguyen N., Nguyen Q.P., Laboratory investigation of low-tension-gas flooding for improved oil recovery in tight formations, SPE-159841-MS, 2013, DOI: https://doi.org/10.2118/159841-MS

14. Wang D., Cheng J., Yang Z. et al., Successful field test of the first ultra-low interfacial tension foam flood, SPE-72147-MS, 2001, DOI: http://doi.org/10.2523/72147-MS

15. Maubert M., Liyanage P.J., Pope G. et al., ASP Experiments in Indiana Limestone using NaOH to Reduce Surfactant Retention, SPE-190187-MS, 2022,

DOI: http://doi.org/10.2118/190187-MS

16. Hirasaki G., Zhang D.L., Surface chemistry of oil recovery from fractured, oil-wet, carbonate formations, SPE-80988-MS, 2004, DOI: https://doi.org/10.2118/80988-MS

Field implementation of projects of CO2 injecting into productive formations for enhanced oil recovery is possible only after scientific research and a feasibility study. The key stage of the research is laboratory studies, during which a qualitative assessment of the effectiveness of CO2 injection in the conditions of a potential facility is performed, key parameters are determined for creating a composite model and further modeling of CO2 injection on the scale of a well/pilot site. The parameters for the design of experimental and industrial works are determined. Laboratory studies are performed in conditions close to the reservoir, using reservoir fluids and rock samples of the studied object. This ensures that the profitability of project implementation is assessed as correctly and accurately as possible. The article presents the results of complex laboratory studies carried out as part of the scientific support of a project to implement the CO2 injection into low-permeability reservoirs. The following was performed for the conditions of one of the deposits in Western Siberia: standard and special complex of PVT studies, assessment of the minimum pressure of miscibility, filtration studies on core material. The main negative factors that may occur during the CO2 injection were studied. Based on the experimental data obtained, a composite hydrodynamic model of the experimental site was created, and it is planned to perform multivariate calculations on the scale of the well/site of the studied object.

References

1. Morozyuk O.A., Zanochuev S.A., Polyakov A.V. et al., Laboratory support of a project on CO2 injection into a low-permeability reservoir (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2024, no. 10, pp.103–109, DOI: https://doi.org/10.24887/0028-2448-2024-10-103-109

2. Kozhin V.N. et al., Estimation of the utilization potential of carbon dioxide at Orenburg region oil fields (In Russ.), Neftepromyslovoe delo, 2021, no. 8, pp. 43–49,

DOI: https://doi.org/10.33285/0207-2351-2021-8(632)-43-49

3. Emel’yanov K., Zotov N., Savings on decarbonization (In Russ.), Energeticheskaya politika, 2021, no. 10, pp. 27–37, DOI: https://doi.org/10.46920/2409-5516_2021_10164_26

4. Balint V., Ban A., Doleshan Sh., Primenenie uglekislogo gaza v dobyche nefti (The use of carbon dioxide in oil production), Moscow: Nedra Publ., 1977, 240 p.

5. Surguchev M.L., Vtorichnye i tretichnye metody uvelicheniya nefteotdachi plastov (Secondary and tertiary methods of enhanced oil recovery), Moscow: Nedra Publ., 1985, 308 p.

6. Surguchev M.L., Gorbunov A.T., Zabrodin D.P. et al., Metody izvlecheniya ostatochnoy nefti (Residual oil recovery methods), Moscow: Nedra Publ., 1991, 347 p.

7. Lozin E.V., Ryazantsev M.V. et al., CO2-vozdeystvie: issledovaniya uchenykh UfNII-BashNIPIneft’ (CO2 impact: research by scientists from UfNII-BashNIPIneft), Ufa: Publ. of OOO «RN-BashNIPIneft’», 2021, 323 p.

8. Morozyuk O.A. et al., Laboratory studies as a key component of gas EOR projects (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2023, no. 10, pp. 76–81,

DOI: https://doi.org/10.24887/0028-2448-2023-10-76-81

9. Afonin D.G., Gracheva S.K., Ruchkin A.A. et al., The key stages of injecting carbon dioxide into oil reservoirs in order to enhance oil recovery and stimulate oil production (In Russ.), Izvestiya vuzov. Neft’ i gaz, 2024, no. 4, pp. 119–135, DOI: https://doi.org/10.31660/0445-0108-2024-4-119-135

10. Afonin D.G., Ruchkin A.A., Galikeev R.M., Factor analysis of estimated efficiency of producing wells treatments with carbon dioxide using Huff and Puff technology

(In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2024, no. 8, pp. 84-88, DOI: https://doi.org/10.24887/0028-2448-2024-8-84-88

11. Afonin D.G., Vydysh I.V., Galikeev R.M. et al., Factor analysis of estimated efficiency of producing wells treatments with carbon dioxide using huff and puff technology (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2025, no. 6, pp. 50–55, DOI: https://doi.org/10.24887/0028-2448-2025-6-50-55

12. GOST 26450.0-85. Rocks. General requirements for sampling and sample preparation for determination of collecting properties.

13. M 01.00241-2013/31-248-2017. Porody gornye. Metodika izmereniy koeffitsientov otkrytoy poristosti, koeffitsientov gazopronitsaemosti i koeffitsienta anizotropii v baricheskikh usloviyakh s ispol’zovaniem analizatora PIK-PP i ego modifikatsiy (Rocks. Methods of measuring open porosity coefficients, gas permeability coefficients and anisotropy coefficient under baric conditions using the PIK-PP analyzer and its modifications).

14. STO 11-21-2014. Porody gornye. Metodika izmereniy koeffitsienta otkrytoy poristosti volyumometricheskim metodom s ispol’zovaniem porozimetra UltroPore™ 300 firmy Core Laboratories Instruments (Rocks. Method of measuring the coefficient of open porosity by the volumetric method using the UltroPore™ 300 porosimeter from Core Laboratories Instruments).

15. M 01.00241-2013/31-327-2018. Metodika izmereniy ostatochnoy neftenasyshchennosti i koeffitsienta vytesneniya nefti gazom vysokogo davleniya v obraztsakh gornykh porod (Methodology for measuring residual oil saturation and the coefficient of oil displacement by high-pressure gas in rock samples).

16. Stepanova G.S., Gazovye i vodogazovye metody vozdeystviya na neftyanye plasty (Gas and water-gas methods of influence in oil reservoirs), Moscow: Gazoil press, 2006, 200 p.

17. Shamaev G.A., Preduprezhdenie oslozhneniy pri zakachke dioksida ugleroda dlya uvelicheniya nefteotdachi plastov pri razrabotke anomal’nykh neftey (Prevention of complications when injecting carbon dioxide to increase oil recovery during the development of anomalous oils): thesis of candidate of technical science, Ufa, 1988.

The paper is devoted to the issue of determining the optimal number of stages in multistage hydraulic fracturing (HF) in the process of developing reservoirs with low filtration-capacitive properties. The objects of the study are terrigenous strata of the field located in the West Siberian oil and gas province. The issue of finding the critical maximum distance between HF ports is considered which enables the efficient involvement of reserves in development. The study methods are statistical analysis of the actual dynamics of production wells and a combination of calculated results on a HF simulator with subsequent hydrodynamic modeling. To increase the reliability of the analysis results, groups were formed consisting of wells located in similar geological conditions, without significant differences in completion methods and without complications in the process of drilling, development and subsequent operation over the analyzed time period. The statistical analysis compared the general approach to the placement of hydraulic fracturing ports with an approximate distance of 125 m between ports with wells completed with a distance between ports of at least 160 m. For many wells, increasing the interport distance did not lead to a deterioration in the indicators relative to the general approach, which enables expanding the potential for optimizing costs during well construction. Similar results were obtained based on the modeling of one of the sections. One of the possible criteria for increasing the distance between ports is the permeability of the formation, which affects the efficiency of well operation within the considered comparison.

References

1. Kolupaev D.Yu., Bikkulov M.M., Solodov S.A. et al., Mass hydraulic fracturing is a key technology of the southern part Priobskoye field development (In Russ.), PROneft’. Professional’no o nefti = PROneft. Professionally about Oil, 2019, no. 1, pp. 39–45, DOI: https://doi.org/10.24887/2587-7399-2019-1-39-45

2. Buzinov S.N., Umrikhin I.D., Issledovanie neftyanykh i gazovykh skvazhin i plastov (The study of oil and gas wells and reservoirs), Moscow: Nedra Publ., 1973, 248 p.

3. Listik A.R., Popov N.G., Sitnikov A.N. et al., Identifying the best technology solutions to improve efficiency of MSHF in horizontal wells at the Priobskoye field

(In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2017, no. 12, pp. 46-48, DOI: https://doi.org/10.24887/0028-2448-2017-12-46-48

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

References

1. 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).

2. Ishmurzin A.A., Yamaliev V.U., Bulyukova F.Z., Designing low-flow electric centrifugal pump of high efficiency coefficient (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2020, no. 5, pp. 84–87, DOI: https://doi.org/10.24887/0028-2448-2020-5-84-87

3. Bakirov R.R., Boltenkov D.D., Sadrutdinov T.R., Application of periodic mode during the operation of oil wells at the late stage of development (In Russ.), Mnogofaznye sistemy = Multiphase Systems, 2024, V. 19, no. 1, pp. 31–34, DOI: https://doi.org/10.21662/mfs2024.1.004

4. 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

5. Kuz’min M.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

6. Ivanov V.A., Verbitskiy V.S., Khabibullin R.A. et al., Analysis of the influence of operational features and operating modes of oil wells on the reliability of ESP (In Russ.), Proceedings of Russian Energy Industry Conference (ROEK) 2024, Moscow, 15–17 October 2024, Moscow: Publ. of Geomodel’ Razvitie, 2024, pp. 294–298.

7. Vidineev A.S., Determination of the optimal mode of a short-time periodic operation of low flow rate wells by means of using electric centrifugal pump (In Russ.), Neftepromyslovoe delo, 2022, no. 3(639), pp. 41–45, DOI: https://doi.org/10.33285/0207-2351-2022-3(639)-41-45

8. Kostilevskiy V.A., Shaydakov V.V., Koroleva D.A., Flow-rate calculation method for short-term well operation (In Russ.), Stroitel’stvo neftyanykh i gazovykh skvazhin na sushe i na more, 2023, no. 4(364), pp. 45–48, DOI: https://doi.org/10.33285/0130-3872-2023-4(364)-45-48

9. 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

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. Yudin E.V., Andrianova A.M., Ganeev T.A. et al., Production monitoring using a virtual flow meter for an unstable operating well stock (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2023, no. 8, pp. 82–87, DOI: https://doi.org/10.24887/0028-2448-2023-8-82-87

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

13. MultiflashTM, Infochem/KBC Process Technology Ltd. User Guide for Multiflash for Windows, Version 7.1; Kbc Advanced Technology Pte Ltd.: Singapore, 2020.

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

15. Gorid’ko K.A., Verbitskiy V.S., 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 = SOCAR Proceedings, 2023, no. S1, pp. 9–20, DOI: https://doi.org/10.5510/OGP2023SI100831

16. Yudin E.V., Habibullin R.A., Smirnov N.A. et al., New approaches to gaslift and ESP well stock production management (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2021, no. 6, pp. 67–73, DOI: https://doi.org/10.24887/0028-2448-2021-6-67-73

17. Yudin E., Piotrovskiy G., 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

One of the challenges complicating the operation of oil production wells and oilfield equipment is the formation of asphalt-resin-paraffin deposits (ARPD). To combat ARPD, oil-producing companies employ both preventive measures and removal of already formed deposits. The primary method for cleaning the internal surface of tubing (tubing strings) from paraffin is mechanical, involving the lowering and lifting of scrapers using manual winches. This operation is performed in each well at regular intervals, determined by the well's production rate, ARPD content, temperature and pressure, and is set by the field's engineering service. The main drawback of such scrapers is their low mechanical reliability. Scrapers often cause emergency situations due to jamming inside the tubing or wire breakage. One possible way to improve the ARPD removal system is to implement a digital twin for diagnostics – a virtual analog of the tubing cleaning device. This enables real-time monitoring of the cleaning system's status and the anticipation of emergency situations, such as a potential winch cable break. This paper proposes a digital twin based on a multilayer perceptron neural network for diagnosing the operation of the well cleaning device. The studies showed that the most accurate model includes two hidden layers with 20 neurons in the first hidden layer and 10 in the second, trained using the Bayesian regularization algorithm. The recognition accuracy of possible emergency situations on the test sample reached no less than 85 %, which is a sufficient level for practical use of the model.

References

1. Krysanov D., II v neftyanoy industrii: kak tekhnologii menyayut geologorazvedku i dobychu (AI in the oil industry: How technology is changing exploration and production), URL: https://trends.rbc.ru/trends/industry/678f9f5f9a79477d9725513e

2. Blyablyas A.N., Application of artificial intelligence approach to the well complication control (In Russ.), Gazovaya promyshlennost', 2018, no. 4(767), pp. 16–21.

3. Belkina S.A., Nagaeva S.N., The education reasons the asfaltapitchesparaffin of deposits in PCP (In Russ.), Vestnik Yugorskogo gosudarstvennogo universiteta, 2016, V. 42, no. 3, pp. 7–11.

4. Korobov G.Yu., Parfenov D.V., Mechanisms of formation of asphaltene-resin-paraffin deposits: research methods (In Russ.), Neftegaz.RU, 2022, no. 8, pp. 22–31.

5. Gryaznova E.S., Main causes & factors affecting formation of asphalt-resin-paraffin deposits (In Russ.), Vestnik nauki, 2022, V. 1, no. 12(57), pp. 359–362.

6. Fedorov S.N., Kolovertnov G.Yu., Krasnov A.N., Prakhova M.Yu., Digital twins in the oil and gas industry: experience and prospects of use, Proceedings of the International Science Conference “Science. Education. Practice”, 2025, March 26, pp. 116–123, DOI: https://doi.org/10.34660/INF.2025.52.92.052

7. Krasnov A.N., Khoroshavina E.A., Prakhova M.Yu., Preventing paraffination of pumping equipment of oil wells, Advances in Engineering Research, 2017, V. 133,

pp. 370–375, DOI: https://doi.org/10.2991/aime-17.2017.60

8. Fedorov S.N., Kolovertnov G.Yu., Krasnov A.N., Prakhova M.Yu., Diagnostic diagram of state of well mechanical cleaning unit (In Russ.), Elektrotekhnicheskie i informatsionnye kompleksy i sistemy, 2025, V. 21, no. 2, pp. 98–110, DOI: http://doi.org/10.17122/1999-5458-2025-21-2-98-110.

9. Fedorov S.N., Kolovertnov G.Yu., Krasnov A.N., Prahova M.Yu., Digital twin of the device for cleaning pump-compressor pipes, HMMOCS, 2025, pp. 404–412,

DOI: https://doi.org/10.1007/978-3-031-95649-2_35

10. Kobzar O., Mosyagin G., Gudilov M. et al., A new approach to creating a digital twin of well for production monitoring in western Siberia fields, SPE-216731-MS, 2023, DOI: https://doi.org/10.2118/216731-MS

11. Andrianova A.M., Yudin E.V., Ganeev T.A. et al., Application of intelligent methods for analysis high-frequency production data for solving oil engineering challenges

(In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2021, no. 9, pp. 70–75, DOI: https://doi.org/10.24887/0028-2448-2021-9-70-75

12. Eremin N.A., Eremin A.N., Digital twin in the oil and gas production (In Russ.), Neft’. Gaz. Novatsii, 2018, no. 12, pp. 14–17.

13. Ilushin P., Vyatkin K., Menshikov A., Development of a methodology and software package for predicting the formation of organic deposits based on the results of laboratory studies, Fluids, 2021, no. 6, pp. 446-450, DOI: https://doi.org/10.3390/fluids6120446

14. Bykova V.N., Kim E., Gadzhialiev M.R. et al., Application of a digital twin in the oil and gas industry (In Russ.), Actual Problems of Oil and Gas, 2020, no. 1(28),

pp. 8–15, DOI: https://doi.org/10.29222/ipng.2078-5712.2020-28.art8

15. Yudin E., Kovaleva M., Shevchenko V. et al., Maintaining ESP operational efficiency through machine learning-based anomaly detection, Geoenergy Science and Engineering, 2025, V. 251, DOI: https://doi.org/10.1016/j.geoen.2025.213864

16. E. Yudin et al., Modelling of a gas-lift well operation with an automated gas-lift gas supply control system, SPE-196816-MS, 2019, DOI: https://doi.org/10.2118/196816-MS

17. Yudin E.V., Andrianova A.M., Ganeev T.A. et al., Production monitoring using a virtual flow meter for an unstable operating well stock (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2023, no. 8, pp. 82–87, DOI: https://doi.org/10.24887/0028-2448-2023-8-82-87

18. Yudin E. et al., Using deep learning algorithms to monitor well performance and restore well rate dynamics, SPE-217526-MS, 2023,

DOI: https://doi.org/10.2118/217526-MS

19. Neyronnaya set’: raskrytie vozmozhnostey iskusstvennogo intellekta (Neural Network: Unlocking the power of artificial intelligence),

URL: https://www.easiio.com/ru/neural-network-hidden-layer/

20. Chornyy A.V., Kozhemyakina I.A., Churanova N.Yu. et al., Analysis of wells interaction based on algorithms of complexing geological and field data (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2019, no. 1, pp. 36–39, DOI: https://doi.org/10.24887/0028-2448-2019-1-36-39

21. Nazhimova N.A., Naumova E.G., Formation of skills for building neural networks in various software environments (In Russ.), Sovremennye problemy nauki i obrazovaniya, 2024, no. 3, pp. 98–105, URL: https://doi.org/10.17513/spno.33522

22. De Luka G., Arkhitektura neyronnoy seti: kriterii vybora kolichestva i razmera skrytykh sloev (Neural network architecture: Criteria for selecting the number and size of hidden layers), URL: https://www.baeldung.com/cs/neural-networks-hidden-layers-criteria

This paper presents a probabilistic electrical submersible pump selection methodology for conditions of high parameter uncertainty following geological and technical operations. The primary challenge is significant variability in productivity index during the post-workover period, which critically affects pump operating regimes. Wells with high gas-oil ratios present particular complexity, where the pump's ability to handle gas-liquid mixtures becomes the dominant factor in operational reliability. The research methodology is based on Monte Carlo simulation combined with hydrodynamic modeling in Unifloc VBA, using Standing correlations for PVT properties, Ansari and Beggs-Brill models for multiphase flow calculations accounting for hydrodynamic and thermal effects, and Marquez correlation for natural gas separation at pump intake. A comprehensive efficiency criterion was developed that integrates pump efficiency, energy performance indicators, mean time between failures, and production shortfall risks through normalized coefficients. Testing of the methodology on a Western Siberian mature oilfield demonstrated that small standard deviations in reservoir pressure and productivity index lead to substantial scatter in predicted flow rates, significantly affecting pump sizing selection. It is shown that reducing uncertainty in input parameters through field measurements such as well testing, production logging, or reservoir sampling substantially impacts equipment selection results, emphasizing the necessity for accurate data collection during design and well monitoring phases.

References

1. Pashali A.A., Kolonskikh A.V., Khalfin R.S. et al., A digital twin of well as a tool of digitalization of bringing the well on to stable production in Bashneft PJSOC (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2021, no. 3, pp. 80–84, https://doi.org/10.24887/0028-2448-2021-3-80-84

2. Baymukhametov M.K., Gulishov D.S., Mikhaylov V.G. et al., Analysis of causes of gas-oil ratio growth at late stages of oil fields exploration (In Russ.), Izvestiya Tomskogo politekhnicheskogo universiteta. Inzhiniring georesursov = Bulletin of the Tomsk Polytechnic University. Geo Assets, 2018, V. 329, no. 8, pp. 104-111.

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

4. Galkin V.I., Koltyrin A.N., Development of a method for forecasting technological indicators of a well operation after application of geological-technical measures

(In Russ.), Neftepromyslovoe delo, 2020, no. 7(619), pp. 18–28, DOI: https://doi.org/10.30713/0207-2351-2020-7(619)-18-28

5. Galkin V.I., Koltyrin A.N., Justification of the predicted value of oil flow rate increase after applying WST with the help of the statistical method (In Russ.), Izvestiya Tomskogo politekhnicheskogo universiteta. Inzhiniring georesursov = Bulletin of the Tomsk Polytechnic University. Geo Assets Engineering, 2023, V. 334, no. 2, pp. 81–86.

6. Altunin A.E., Semukhin M.V., Kuzyakov O.N., Tekhnologicheskie raschety pri upravlenii protsessami neftegazodobychi v usloviyakh neopredelennosti (Technological calculations in the management of oil and gas production in the face of uncertainty), Tyumen: Publ. of TIU, 2015, 187 p.

7. Hajinorouz M., Alavi S.E., A new approach based on VIKOR and Monte-Carlo algorithms for determining the most efficient enhanced oil recovery methods: EOR screening, Journal of Petroleum Exploration and Production Technology, 2024, V. 14, no. 2, pp. 623–643, DOI: https://doi.org/10.1007/s13202-023-01726-y

8. Yudin E.V., Piotrovskiy G.A., Kolyuk O.A., Operational features and methods for determining the optimal operation parameters in fractured reservoirs with a gas cap: Oil rims of Orenburg OGCF case study (In Russ.), PRONEFT’’. Professional’no o nefti, 2020, no. 3, pp. 26–32.

9. Yudin E.V., Habibullin R.A., Smirnov N.A. et al., New approaches to gaslift and ESP well stock production management (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2021, no. 6, pp. 67–73, DOI: https://doi.org/10.24887/0028-2448-2021-6-67-73

10. Krasnov V.A., Sudeev I.V., Yudin E.V. et al., Reservoir parameters evaluation using the production data analysis (In Russ.), Nauchno-tekhnicheskiy Vestnik OAO “NK “Rosneft’”, 2010, no. 1, pp. 30–34.

11. Andrianova A.M., Yudin E.V., Ganeev T.A. et al., Application of intelligent methods for analysis high-frequency production data for solving oil engineering challenges

(In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2021, no. 9, pp. 70–75, DOI: https://doi.org/10.24887/0028-2448-2021-9-70-75

This study investigates the impact of operational wear on the pressure-flow characteristics of electrical submersible pumps (ESP) when pumping coarse-dispersed gas-liquid mixtures. While the degradation of ESP performance due to gas presence is well-documented, this research specifically examines how mechanical wear significantly exacerbates this issue, reducing gas tolerance compared to new equipment. The experimental work was conducted on a specialized test facility at Gubkin University, which enables precise control of parameters. Results demonstrate that worn ESPs experience performance degradation (gas lock) at substantially lower gas volume fractions compared to their original specifications. The critical gas content threshold for worn pumps was found to be significantly reduced, with performance collapsing more abruptly than in new equipment. The research shows that energy efficiency of worn ESPs decreases more rapidly when handling gas-liquid mixtures, necessitating operational adjustments to maintain efficiency. These findings underscore the necessity of developing methodologies to assess pump wear and corresponding correction coefficients for existing performance degradation models obtained through experimental methods. Regular monitoring of downhole equipment condition and timely replacement of worn stages are essential for maintaining efficient operation in high gas-content environments, particularly in late-stage field development where gas-liquid ratios are elevated. The research provides critical insights for optimizing ESP selection, operation, and maintenance strategies.

References

1. Zhang J., Cai S., Li Y. et al., Mechanistic modeling of gas effect on multi-stage electrical submersible pump (ESP) performance with experimental validation, Chemical Engineering Science, 2021, V. 227, DOI: http://doi.org/10.1016/j.ces.2021.117288

2. Barrios L., Prado M., Experimental visualization of two-phase flow inside an electrical submersible pump stage, Journal of Energy Resources Technology, 2011, V. 133(4),

DOI: http://doi.org/10.1115/OMAE2009-79726

3. Zhu J., Zhang H.Q., A review of experiments and modeling of gas-liquid flow in electrical submersible pumps, Energies, 2018, V. 11(1), DOI: https://doi.org/10.3390/en11010180

4. 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

5. Gamboa J., Prado M., Review of electrical-submersible-pump surging correlation and models, SPE-140937-PA, 2011, DOI: https://doi.org/10.2118/140937-PA

6. Zhou D., Sachdeva R., Simple model of electric submersible pump in gassy well, Journal of Petroleum Science and Engineering, 2010, V. 70(3-4), pp. 204–213,

DOI: https://doi.org/10.1016/j.petrol.2009.11.012

7. Duran J., Prado E.M., ESP stages air-water two-phase performance – modeling and experimental data, SPE-87627-MS, 2003.

8. Romero M.I., An evaluation of an electrical submersible pumping system for high GOR wells: Master’s Thesis, University of Tulsa, 1999.

9. Lea J.F., Bearden J.L., Effect of gaseous fluids on submersible pump performance, Journal of Petroleum Technology, 1992, V. 34(12), pp. 2922–2930.

10. Schafer D., Bieberle A., Neumann M. et al., Application of gamma-ray computed tomography for the analysis of gas holdup distributions in centrifugal pumps, Flow Measurement and Instrumentation, 2015, V. 46, pp. 262–267, DOI: https://doi.org/10.1016/j.flowmeasinst.2015.06.001

11. Si Q., Bois G., Jiang Q. et al., Investigation on the handling ability of centrifugal pumps under air–water two-phase inflow: Model and experimental validation, Energies, 2018, V. 11(11), DOI: https://doi.org/10.3390/en11113048

12. 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

13. 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

14. Goridko K.A., The bench for studying gas phase dispersion in gas-liquid mixture flow along the length of electric submersible pump (In Russ.), Ekspozitsiya Neft’ Gaz, 2020,

no. 6(79), pp. 62–66, DOI: https://doi.org/10.24411/2076-6785-2020-10106

15. 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

16. Yudin E. et al., Maintaining ESP operational efficiency through machine learning-based anomaly detection, Geoenergy Science and Engineering, 2025, V. 251,

DOI: https://doi.org/10.1016/j.geoen.2025.213864

This paper presents a comprehensive analysis of Graphics Processing Unit (GPU) acceleration technologies application for modeling filtration processes in oil and gas reservoirs using the boundary element method (BEM). The research addresses the critical need for computational time reduction in complex multi-well models featuring hydraulic fractures and heterogeneous boundaries, which is essential for real-time reservoir development optimization in the modern digitalized petroleum industry. The study provides detailed examination of architectural compatibility between GPU's massively parallel structure and the naturally decomposable nature of BEM computations, which are based on superposition principles of contributions from multiple sources. A comprehensive algorithmic adaptation strategy was developed, incorporating spatial-temporal decomposition, divergence minimization, efficient utilization of GPU's multi-level memory hierarchy, and optimization of data access patterns. The implementation utilizes programming model CUDA with specialized numerical integration techniques adapted for GPU architecture, including Gauss-Kronrod quadrature and exponential integral approximations optimized for parallel execution. Experimental verification on realistic industrial reservoir models demonstrated an average speedup of 77 times with peak performance reaching up to 126 times in individual iterations, while maintaining high computational accuracy (deviation less than 2,1 %). This enables dramatic reduction of simulation time from hours to minutes for complex reservoir systems, opening new possibilities for uncertainty analysis, multi-scenario calculations, and real-time reservoir development optimization.

References

1. 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

2. Yudin E.V., Poroshin I.O., Gruzdev I.E., Markov N.S., New approaches to rapid performance evaluation of wells in heterogeneous reservoirs (In Russ.), Neftyanoe khozyaystvo= Oil Industry, 2023, no. 10, pp. 61-67, DOI: https://doi.org/10.24887/0028-2448-2023-10-61-67

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. Lubnin A.A. et al., System approach to planning the development of multilayer offshore fields, SPE-176690-MS, 2015, DOI: https://doi.org/10.2118/176690-MS

5. GOST 19.101-2024. Unified system for program documentation. Types of programs and program documents.

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7. Kazemzadeh-Parsi M.J., Unsteady flow to a partially penetrating well in an unconfined aquifer using the boundary element method, Engineering Analysis with Boundary Elements, 2015, V. 50, pp. 50–56.

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11. Demidov D.E., Egorov A.G., Nuriev A.N., Solving computational fluid dynamics problems using NVIDIA CUDA technology (In Russ.), Uchenye zapiski Kazanskogo gos. universiteta. Seriya fiziko-matematicheskie nauki, 2010, V. 152, no. 1, pp. 142-154.

The article is devoted to the issues of collection and routing of data at remote oil well pad sites. Many oil fields in the Russian Federation are located in remote and hard to reach areas, including the Arctic zone and offshore shelf. The lack of developed infrastructure limits the use of telemetry systems because of the difficulty of transmitting large streams of raw data to a remote data processing center, and thereby the high costs associated with establishing wired communication channels and powering them. One of the possible solution is to implement a wireless sensor network (WSN) consisting of intelligent sensors and of specialized edge devices, which would enable increased local data processing directly at well pad sites and low power consumption through data transmission algorithms that optimize network performance. In this paper, it is proposed by the authors that when building a WSN at well pad sites, a cluster‐based approach should be used based on some clustering algorithm. To derive practical recommendations, agent‐based simulation of six widely used clustering algorithms was performed. The values of the control metrics obtained in the study showed that the preference for a particular algorithm is determined by the target performance indicator of the WSN.

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. Vlasov D.Yu., Zancharov A.A., Yudin E.V. et al., Automation of the monitoring process and factor analysis of production deviations (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2023, no. 6, pp. 78–82, DOI: https://doi.org/10.24887/0028-2448-2023-6-78-82

3. 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.

4. Wu G., Talwar S., Johnsson K., Himayat N., M2M: from mobile to embedded Internet, IEEE Commun., 2011, Mag. 49, pp. 36–43, DOI: https://doi.org/10.1109/MCOM.2011.5741144

5. Knyazev O.V., Using data analysis to organize production process management (In Russ.), Ekonomika i sotsium, 2013, no. 3(8), pp. 872-878.

6. Gorid'ko K.A., Timashev E.O., Volkov M.G. et al., Review of experience in predicting ESP failures using machine learning methods (In Russ.), Neftegaz.RU, 2025, no. 1, pp. 55-61.

7. Orru P.F., Zoccheddu A., Sassu L. et al., Machine learning approach using MLP and SVM algorithms for the fault prediction of a centrifugal pump in the oil and gas industry, Sustainability, 2020, no. 11, DOI: https://doi.org/10.3390/su12114776 EDN: FHDLPY

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9. Al’-Kadami N.A., The compare of the routing algorithms for the homogeneous and heterogeneous wireless sensor networks (In Russ.), Informatsionnye tekhnologii i telekommunikatsii, 2014, no. 4(8), pp. 40–48.

10. Dao Ch.N., Issledovanie modeley i metodov obsluzhivaniya trafika v besprovodnykh sensornykh setyakh (Research of models and methods of traffic servicing in wireless sensor networks): thesis of candidate of technical science, St. Petersburg, 2019, 153 p.

11. Buzyukov L.B., Okuneva D.V., Paramonov A.I., Research of characteristics of the self-organized wireless network at various ways of placement of knots (In Russ.), Trudy uchebnykh zavedeniy svyazi, 2016, V. 2, no. 1, pp. 28–32.

12. E Yudin. et al., Using deep learning algorithms to monitor well performance and restore well rate dynamics, SPE-217526-MS, 2023, DOI: https://doi.org/10.2118/217526-MS

13. E Yudin. et al., Maintaining ESP operational efficiency through machine learning-based anomaly detection, Geoenergy Science and Engineering, 2025, V. 251,

DOI: https://doi.org/10.1016/j.geoen.2025.213864

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

15. Krasnov A.N., Prakhova M.Yu., Kalashnik Yu.V., Routing algorithm for the wireless sensor network of the drilling site, Proceedings of the International Conference “Scientific research of the SCO countries: synergy and integration”, 2023, February 10, pp. 189–198.

16. Krasnov A.N., Prakhova M.Yu., Khoroshavina E.A., Use of wireless networks for gas fields automation (In Russ.), Elektronnyy nauchnyy zhurnal Neftegazovoe delo, 2016, no. 4, pp. 205–221.

17. 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: 10.24887/0028-2448-2019-12-47-51

18. Yang Yu, Prasanna V.K., Krishnamachari B., Information processing and routing in wireless sensor networks, World Scientific Publishing, 2006, DOI: http://doi.org/10.1142/628

19. Dvornikov A.A., An agent-oriented wireless sensor network and a superimposed network channels compatibility modeling (In Russ.), Kachestvo. Innovatsii. Obrazovanie, 2015,

no. 9, pp. 34–39.

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

21. Lateef O.A. Esther T.O., Taofeek-Ibrahim F.A., Evolution of wireless networks technologies, history and emerging technology of 5G wireless network: a review, Journal of Telecommunications System & Management, 2018, 5 p

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This paper presents the methodology and results of developing a prototype system for the automated extraction of structured information from unstructured textual reports of Production Geophysical Surveys (PGS) of oil wells. The core of the solution is the QwenLarge Language Model (LLM) architecture, enhanced with a Retrieval-Augmented Generation (RAG) mechanism to provide the model with context from external knowledge bases. A comparative analysis of baseline LLM architectures (Qwen2.5-7B-Instruct and ruGPT-3.5-13B) was conducted, revealing that Qwen held a significant advantage in both accuracy and processing speed. The key achievement of this work is the integration of the RAG approach, which substantially increased the accuracy of geological and technical complication classification from 45 % for the baseline Qwen model to 83 % across nine predefined complication classes. The developed software system executes a full processing pipeline: from text preprocessing (tokenization, normalization) and Named Entity Recognition to complication classification and the generation of structured data ready for integration into corporate information systems. The average processing time for a single report was 30 seconds. This proposed solution is designed to automate engineering analysis, support intervention planning, and enhance the operational efficiency of oil field management by transforming unstructured textual data into actionable, structured insights.

References

1. Krasnov V.A., Sudeev I.V., Yudin E.V., Lubnin A.A., Reservoir parameters evaluation using the production data analysis (In Russ.), Nauchno-tekhnicheskiy vestnik

OAO “NK “Rosneft”, 2010, no. 1, pp. 30–34.

2. 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.

3. Andrianova A.M., Yudin E.V., Ganeev T.A. et al., Application of intelligent methods for analysis high-frequency production data for solving oil engineering challenges

(In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2021, no. 9, pp. 70–75, DOI: https://doi.org/10.24887/0028-2448-2021-9-70-75

4. Judin E., Andrianova A., Ganeev T. et al., Intelligent methods for analyzing high-frequency production data to optimize well operation modes, SPE-212118-MS, 2022, DOI: https://doi.org/10.2118/212118-MS

5. Whiteside J., AI-enabled large language model speeds up wells data retrieval but must be used with care, Drilling Contractor, 2023,

URL: https://drillingcontractor.org/ai-enabled-large-language-model-speeds-up-wells-data-retrieval-but-mu...

6. Rachmanto R., Utilizing large language models for information retrieval from reports in the oil and gas industry, Plain English AI, 2023,

URL: https://ai.plainenglish.io/utilizing-large-language-models-for-information-retrieval-from-reports-in...

7. Ghorbanfekr H., Kerstens P.J., Dirix K., Classification of geological borehole descriptions using a domain adapted large language model, arXiv preprint arXiv:2407.10991, 2024, DOI: https://doi.org/10.48550/arXiv.2407.10991

8. Zhiwei Ma, Santos J.E., Lackey G. et al., Information extraction from historical well records using a large language model, Scientific Reports, 2024, V. 14, No 1,

DOI: https://doi.org/10.1038/s41598-024-81846-5

9. Zhouhan Lin, Cheng Deng, Le Zhou et al., GeoGalactica: A large language model for geoscience knowledge retrieval and reasoning, arXiv preprint arXiv:2401.00434, 2024, DOI: https://doi.org/10.48550/arXiv.2401.00434

10. Wayne Xin Zhao, Kun Zhou, Junyi Li et al., A survey of large language models, 10.48550/arXiv.2303.18223, 2023, DOI: https://doi.org/10.48550/arXiv.2303.18223

11. Guu K. et al., Retrieval augmented language model pre-training, International conference on machine learning, PMLR, 2020, pp. 3929–3938.

In this work, the technology of pyrolysis of associated petroleum gas over 90% Ni / 10% Al2O3 catalyst, synthesized by the solution combustion method is investigated. The high-percentage catalyst was synthesized by burning a solution as a result of the combined heat treatment of (NO3)2-Al(NO3)3-C2H5NO 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 68-87 m2. The paper evaluates the catalytic activity of the catalyst in the decomposition reaction of methane and associated petroleum gas at a pressure of 0,1 MPa and temperatures of 550-650°C. The catalysts were tested in a horizontal reactor without preliminary hydrogen reduction. The synthesized catalyst samples, 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 relationship between the average diameter of the nanofiber and the temperature of the catalytic reaction was experimentally established. The highest specific yield of hydrogen and carbon nanofibers was 11,8 mol/Gkat and 71,0 g/Gkat, respectively, at a temperature of 550 °C in the decomposition reaction of associated petroleum gas. The dependence of carbon yield (71,0 g/Gkat > 49,1 g/ Gkat > 31,5 g/ Gkat) and hydrogen (11,8 mol/Gkat > 8,2 mol/Gkat > 5,3 mol/Gkat) from the temperature of the catalytic reaction, which varies in the range 550 °C > 600 °C > 650 °C.

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7. Yao D., Yang H., Chen H., Williams P.T., Co-precipitation, impregnation and so-gel preparation of Ni catalysts for pyrolysis-catalytic steam reforming of waste plastics, Applied Catalysis B: Environmental, 2018, V. 239, pp. 565–577, DOI: https://doi.org/10.1016/j.apcatb.2018.07.075

8. Nersisyan H.H., Lee J.H., Ding J.R. et al., Combustion synthesis of zero-, one-, two- and three-dimensional nanostructures: Current trends and future perspectives, Progress in Energy and Combustion Science, 2017, V. 63, pp. 79–118, DOI: https://doi.org/10.1016/j.pecs.2017.07.002

The article analyzes existing industrial safety systems, explains the conditions for their implementation, and provides a benchmark based on key criteria. The most efficient safety system nowadays is rooted in the 1970s and has been evolving ever since, it however has a very limited diffusion and is employed, albeit with some reservations, primarily at large corporations. However, it mainly relies on the operations management practices, risk assessment, analysis and management techniques, as well as on equipment and technologies developed and tested in the 20th century. A drawback of modern security systems is their use of expert procedures, dependent on human factor for their performance. The next generation of industrial safety systems, which is only taking shape now, may access and use best practices and scientific achievements of the first quarter of the 21st century, including in the information technology sphere. This will enable achieving the goal of preventing severe and fatal injuries to employees and third parties, and also accidents and emergencies at production sites, which aligns with the «zero» goal. Moreover, the new generation of the safety system should have the capability to achieve the «zero» goal with reduced resource consumption, making it implementable not only in major corporations but also across small and medium-sized businesses. Based on the conducted analysis and the experience of implementing activites in industrial and labour safety in Rosneft Oil Company, main tasks and requirements for the new generation of safety system under development were determined.

References

1. Decree of the President of the Russian Federation No. 198 of 06.05.2018 “Ob osnovakh gosudarstvennoy politiki Rossiyskoy Federatsii v oblasti promyshlennoy bezopasnosti na period do 2025 goda i dal’neyshuyu perspektivu” (On the fundamentals of the state policy of the Russian Federation in the field of industrial safety for the period up to 2025 and beyond).

2. GOST R 56020-2020. Berezhlivoe proizvodstvo. Osnovnye polozheniya i slovar’ (Lean production. Fundamentals and vocabulary).

3. Sivokon’ I.S., Anfimov M.V., Andreeva G.V., Rassledovanie proisshestviy na proizvodstve (Investigation of industrial accidents), Moscow – Vologda: Infra-Inzheneriya Publ., 2024, 254 p.

4. Cameron I. et al., Process hazard analysis, hazard identification and scenario definition: Are the conventional tools sufficient, or should and can we do much better, Process Safety and Environmental Protection, 2017, V. 110, pp. 53–70, DOI: https://doi.org/10.1016/j.psep.2017.01.025

5. Lee J., Cameron I., Hassall M., Dynamic simulation for process hazard analysis: Affordances and limitations in the application to complex process systems, Journal of Loss Prevention in the Process Industries, 2022, V. 87, DOI: https://doi.org/10.1016/j.jlp.2023.105232

6. R. Mokhtarname et al., Application of multivariable process monitoring techniques to HAZOP studies of complex processes, Journal of Loss Prevention in the Process Industries, 2022, V. 74, DOI: https://doi.org/10.1016/j.jlp.2021.104674

7. Senatorov M.Yu., Levin S.E., Nagibin S.Ya., Iskusstvennyy intellekt v sistemakh upravleniya (ot teorii k praktike) (Artificial intelligence in control systems (from theory to practice)), Moscow: Ayaks-Press Publ., 2023, 265 p.

8. Chernoplekov A.N., Chemical processes safety risks control and management (In Russ.), Problemy analiza riska = Issues of Risk Analysis, 2024, V. 21, no. 6,

pp. 10–39.

9. Tikhonova G.I., Churanova A.N., Long-term analysis of the features of occupational injury recording and reporting in Russia (In Russ.), Demograficheskoe obozrenie, 2019, V. 6, no. 2, pp. 142–164.

10. Sostoyanie proizvodstvennogo travmatizma. Okhrana truda v tsifrakh (The state of industrial injuries. Occupational safety in figures), Moscow: Publ. of VNII Truda Mintruda Rossii, 2024, URL: https: //s.vcot.info/document/poleznoe/media/5/66d99c1a16c0e568797996.pdf

11. Brad M., Death and oil: The true story of the piper alpha disaster on the North sea, New York, N.Y.: Pantheon Books, 304 p.

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13. The Public Inquiry into the Piper Alpha Disaster. The Hon Lord Cullen. Volume Two, London: HMSO, 1990, pp. 255-488.

14. Nikitina D.A., Petryaev S.N., Sivokon’ I.S., Fomina E.E., Analysis of experience in building operation management systems for the foreign and Russian oil and gas companies (In Russ.), Bezopasnost’ Truda v Promyshlennosti, 2021, no. 2, pp. 69–74, DOI: https://doi.org/10.24000/0409-2961-2021-2-69-74.

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DOI: https://doi.org/10.1201/b18020

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The process of accumulation and distribution of snow deposits on roofs of vertical cylindrical tanks in winter has a very complex physical nature, which must be taken into account in strength calculations. The following article presents the results of mathematical modeling of snow deposits and snow retention processes on the roofs of vertical steel tanks with a pontoon of 20000 m3 capacity (RVSP-20000) with installed stairways, fencing, service platforms and breathing equipment. Mathematical modeling of snow retention processes was carried out in the ANSYS Fluent software package using a model based on comparing the tangential stresses of the flow on the surface with the critical value of snow entrainment/deposition. To account for the effect of the snow cover height above the tank roof on the air flow, a dynamic grid technology was used, implemented with the user-defined software code. The user-defined function is based on a mathematical model of snow deposition developed on the basis of experimental research. The roof of a vertical spherical tank with a pontoon of RVSP-20000 type served as the object of mathematical modeling. Based on the research results, recommendations for optimizing design solutions and placement of equipment installed on spherical roofs of petroleum products tanks were developed.

References

1. Poryvaev I.A., Safiullin M.N., Semenov A.A., Research of wind and snow cover loads on the roofs of the vertical cylindrical tanks (In Russ.), Inzhenerno-stroitel’nyy zhurnal = Magazine of Civil Engineering, 2012, no. 5, pp. 12–22, DOI: https://doi.org/10.5862/MCE.31.2

2. Lebedeva I.V., Maslov A.V., Berezin M.M., Experimental researches for assignment of snow loads design parameters (In Russ.), Vestnik NITs “Stroitel’stvo” = Bulletin of Science and Research Center of Construction, 2020, no. 2(25), pp. 66–78, DOI: https://doi.org/10.37538/2224-9494-2020-2(25)-66-76

3. Tominaga Y., Comutational fluid dynamics simulation of snowdrift around buildings: Past achievemnts and future perspectives, Cold Regions Science and Technology, 2017, V. 150, pp. 2-14, DOI: http://doi.org/10.1016/j.coldregions.2017.05.004

4. Schneiderbauer S., Tschachler T., Fischbacher J. et al., Computational fluid dynamic (CFD) simulation of snowdrift in alpine environments, including a local weather model, for operational avalanche warning, Annals of Glaciology, 2008, V. 48, pp. 150–158, DOI: http://doi.org/10.3189/172756408784700789

5. Belostotskiy A.M., Britikov N.A., Goryachevskiy O.S., Critical review of modern numerical modelling of snow accumulation on roofs with arbitrary geometry (In Russ.), International Journal for Computational Civil and Structural Engineering, 2021, V. 17(4), pp. 40–59, DOI: https://doi.org/10.22337/2587-9618-2021-17-4-40-59

6. TPR-23.020.00-KTN-0481-22. Magistral’nyy truboprovodnyy transport nefti i nefteproduktov. Kryshi sfericheskie statsionarnye dlya rezervuarov vertikal’nykh tsilindricheskikh stal’nykh nominal’nym ob”emom 10000, 20000, 50000 kub. m. Tipovye proektnye i tekhnicheskie resheniya (Main pipeline transport of oil and oil products. Spherical stationary roofs for vertical cylindrical steel tanks with a nominal volume of 10,000, 20,000, 50,000 cubic meters. Typical design and technical solutions).

7. TPR-23.020.00-KTN-086-16. Magistral’nyy truboprovodnyy transport nefti i nefteproduktov. Rezervuar vertikal’nyy stal’noy s pontonom stroitel’nym nominalom 20000 kub. m (526) (Main pipeline transport of oil and oil products. Vertical steel tank with pontoon, construction nominal 20,000 cubic meters (526)).