The article is devoted to the topic of loyalty. But not in the sphere of personal re-lationships, the authors will speak about loyalty to values, principles, and the once-chosen path of university development, which activities are embedded or closely intertwined with the activities of the main economic entities of the oil and gas complex such as Gazprom, Rosneft, Lukoil, Surgutneftegaz, Transneft and further down the long list. This refers to Gubkin University. Reflecting on its 95-year history, the authors state and prove that over the years, the university has never betrayed the founder of the refers to the great Russian geologist Ivan Mi-khailovich Gubkin, his precepts, and this is precisely what the university, one of the leading engineering universities in Russia, owes to its achievements and sus-tainable development. Created in the wake of the country's industrialization, Gub-kin University has been and remains primarily a branch university for all the years of its existence, although individual areas of training and research by university scientists cover a wide range of industries. The authors show the university's prin-cipled position on engineering education, which is that it does not end with a uni-versity degree, but should be based on the fundamental principle of continuing professional education.

References

1. Volkov A.E., Universitety RF. Logika transformatsiy. Lektsiya v Tomskom politekhnicheskom universitete 16.11.2021 (Universities of the Russian Federation. Logic of Transformations. Lecture at Tomsk Polytechnic University 11/16/2021), URL: https://rutube.ru/video/3409704c76448d4d1bb53dc9d6962b25/

2. Vladimirov A.I., Sheynbaum V.S., The state and development of oil and gas education (In Russ.), Neftyanoe khozyaystvo = Oil Indsutry, 1996, no. 3, pp. 17–20.

3. Vladimirov A.I., Academician I.M. Gubkin is an outstanding scientist and organizer of higher oil and gas education in Russia (In Russ.), Neftyanoe khozyaystvo = Oil Indsutry, 1996, no. 9, pp. 6–12.

4. URL: https://vuzopedia.ru/spec/81

5. Salganskiy E.A., Tsvetkov M.V., Kadiev Kh.M. et al., Rare and valuable metals in oils and coals of the russian federation: content and methods of extraction (In Russ.), Zhurnal prikladnoy khimii, 2019, V. 92, no. 12, pp. 1514–1533, DOI: http://doi.org/10.1134/S0044461819120028

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7. Borovkov A.I., Maruseva V.M., Ryabov Yu.A., Shcherbina L.A., Global trends in engineering education (In Russ.), Nauchno-tekhnicheskie vedomosti SPbGPU. Gumanitarnye i obshchestvennye nauki, 2018, V. 9, no. 2, pp. 58–75.

8. Budzinskaya O.V., Sheynbaum V.S., Institutional support of continuing engineering education (In Russ.), Vysshee obrazovanie v Rossii, 2018, V. 27, no. 10, pp. 30–46. – DOI: http://doi.org/10.31992/0869-3617-2018-27-10-30-46

9. Martynov V.G., Sheynbaum V.S., Inzhenernaya pedagogika v kontekste inzhenernoy deyatel'nosti (In Russ.), Vysshee obrazovanie v Rossii, 2022, V. 31, no. 6, pp. 152–168, DOI: http://doi.org/10.31992/0869-3617-2022-31-6-152-168.

10. Martynov V.G., Bessel' V.V., Lopatin A.S., Mingaleeva R.D., Global energy consumption forecasting for the medium and long term perspective (In Russ.), Neftyanoe khozyaystvo = Oil Indsutry, 2022, no. 8, pp. 30-34, DOI: http://doi.org/10.24887/0028-2448-2022-8-30-34.

11. Martynov V.G., Bessel' V.V., Lopatin A.S., Low-carbon energy in Russia as the basis of its carbon neutrality (In Russ.), Neftyanoe khozyaystvo = Oil Indsutry, 2023, no. 3, pp. 8-12, DOI: http://doi.org/10.24887/0028-2448-2023-3-8-12

Organic fuels are currently the main source of energy and, as numerous studies show, given the annual growth in global energy consumption, they will remain so in the medium term. Despite the fact that oil will gradually lose its dominant position in the energy sector, being replaced by more environmentally friendly and efficient energy sources, the need for it, given its widespread use in the energy sector and in a number of other industries, will remain quite high. In this regard, the concerns of many scientists and specialists are caused by the exhaustion of oil resources both in Russia and on our planet as a whole. The article presents the results of the authors' analysis of oil production, consumption and reserves in the world, in various regions and in leading countries in terms of reserves and production. It is shown that the situation with the replenishment of oil resources to maintain the level of production required by the world economy is not acceptable for developing a long-term strategy for the oil industry development, even taking into account the abiogenic theory of oil origin, which proves its renewability, and which has been proven in recent years by many factual data and experimental results, including those obtained by Gubkin University.

References

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2. Bessel’ V.V., Lopatin A.S., Martynov V.G., Mingaleeva R.D., The role of oil and gas in the transformation of global energy at the present stage (In Russ.), Neftegazovaya vertikal’, 2024, no. 10, pp. 52–64.

3. Martynov V.G., Bessel’ V.V., Lopatin A.S., Mingaleeva R.D., Global energy consumption forecasting for the medium and long term perspective (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2022, no. 8, pp. 30–34, DOI: https://doi.org/10.24887/0028-2448-2022-8-30-34

4. Bessel’ V.V., Lopatin A.S., Martynov V.G., Mingaleeva R.D., Forecast of the Russian economy energy supply in the medium term (In Russ.), Problemy ekonomiki i upravleniya neftegazovym kompleksom, 2022, no. 8(212), pp. 5–14, DOI: https://doi.org/10.33285/1999-6942-2022-8(212)-5-14

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6. Aksyutin O.E., Ishkov A.G., Romanov K.V. et al., Ecological efficiency of production and application of natural gas on the basis of its full life cycle estimation (In Russ.), Vesti gazovoy nauki, 2017, no. 5(33), pp. 3–11.

7. Bessel’ V.V., Lopatin A.S., Martynov V.G., On the state of the hydrocarbon resource base (In Russ.), Geologiya, geofizika i razrabotka neftyanykh i gazovykh mestorozhdeniy, 2024, no. 12(396), pp. 5–16.

8. Bessel’ V.V., Lopatin A.S., Martynov V.G., Mingaleeva R.D., Revisiting the issue of estimating global national hydrocarbon reserves (In Russ.), Trudy RGU nefti i gaza imeni I.M. Gubkina, 2024, no. 4(317), pp. 5–16.

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10. Osnovnye tendentsii razvitiya neftetreydinga v Rossii v usloviyakh fragmentatsii mirovogo tovarnogo rynka energoresursov: monografiya (Main trends in the development of oil trading in Russia in the context of fragmentation of the global energy commodity market: monograph): edited by Telegina E.A., Moscow: Rusayns Publ., 2024, 168 p.

11. Mingaleeva R. D., Bessel’ V.V., The world’s major economies sustainable development requires more energy (In Russ.), Problemy ekonomiki i upravleniya neftegazovym kompleksom, 2022, no. 3(207), pp. 57–63, DOI: https://doi.org/10.33285/1999-6942-2022-3(207)-57-63

12. Kondrat’eva T.I., Roginskiy V.V., Grenlandiya. Bol’shaya rossiyskaya entsiklopediya 2004-2017 (Greenland. The Great Russian Encyclopedia 2004-2017), URL: https://old.bigenc.ru/geography/text/2377858

13. Arkticheskie ambitsii Trampa: neft’ i gaz est’, no dobychi net (Trump’s arctic ambitions: There’s oil and gas, but no production), URL: https://oilcapital.ru/news/2025-01-13/arkticheskie-ambitsii-trampa-neft-i-gaz-est-no-dobychi-net-529...

14. Kucherov V.G., Bessel’ V.V., Oil global geological resources and reserves assessment: myth and reality (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2021, no. 10, pp. 14–18, DOI: https://doi.org/10.24887/0028-2448-2021-10-14-18

15. Kutcherov V., Krayushkin V., The deep-seated abiogenic origin of petroleum: from geological assessment to physical theory, Review of Geophysics, 2010, V. 48, RG1001, DOI: https://doi.org/10.1029/2008RG000270

The article presents the results of modeling the operation of a functioning horizontal oil well with a performed ball multistage hydraulic fracturing in conditions of a low-productivity formation. The main objective of the study was to assess the effect of seats on well productivity during flowing mode and subsequent transfer to a mechanized operation mode using an electric centrifugal pump in a periodic mode. To achieve the set goal, two computer models were created using the OLGA software package based on the actual well operation parameters during flowing and mechanized operation modes. A series of calculations were performed for various horizon configurations such as: without seats, with seats of the original diameter and with «contaminated» seats (reduced flow area). In addition, the following work presents an economic assessment of the efficiency of drilling out seats due to an increase in the average daily oil flow rate of the well, as well as due to a decrease in the effect of local resistances on well productivity. The results of this study are an important step in determining the efficiency of using the considered technology for well completion with ball multistage hydraulic fracturing in the development of unconventional low-permeability oil and gas reservoirs.

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. Gong D. et al., Factors influencing fracture propagation in collaborative fracturing of multiple horizontal wells, Energy Engineering, 2024, V. 121, no. 2, pp. 425-437,

DOI: http://doi.org/10.32604/ee.2023.030196

3. Zhongwei Wu et al., Advances and challenges in hydraulic fracturing of tight reservoirs: A critical review, Energy Geoscience, 2022, V. 3, no. 4, pp. 427–435,

DOI: http://doi.org/10.1016/j.engeos.2021.08.002

4. Economides M., Oligney R., Valko P., Unified fracture design. Bridging the gap between theory and practice, Orsa Press, Alvin, Texas, 2002, 262 p.

5. Mingazov A.F., Ibragimov K.R., Samoilov I.S., Perspectives for re-stimulation of horizontal wells with multistage hydraulic fracturing with ball arrangements, SPE-172933-MS, 2020, DOI: http://doi.org/10.2118/172933-MS

6. Yushchenko T.S. et al., Operation features of wells with an extended horizontal wellbore and multistage hydraulic fracturing operation in Bazhenov formation (In Russ.), PRONEFT''. Professional'no o nefti = PRONEFT. Professionally about oil, 2022, V. 7, no. 1, pp. 72–88, DOI: https://doi.org/10.51890/2587-7399-2022-7-1-72-88

7. Putri K. et al., Flowback in shale wells: Proppant transport and distribution in the wellbore, Proceedings of the 6th Unconventional Resources Technology Conference, DOI: http://doi.org/10.15530/urtec-2018-2887450

8. Lu H., Anifowosh O., Xu L., Understanding the impact of production slugging behavior on near-wellbore hydraulic fracture and formation integrity, SPE-189488-MS, 2018, DOI: http://doi.org/10.2118/189488-MS

9. User Guide for Multiflash for Windows, Version 7.1, KBC Advanced Technology Pte Ltd.: Singapore, 2022, URL: https://doku.pub/documents/multiflash-manual-nl2p9e386808

10. The PIPESIM 2017 User Manual, Version 2017, Schlumberger.

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

12. Dengaev A. et al., Mechanical impurities carry-over from horizontal heavy oil production well, Processes, 2023, V. 11, no. 10, DOI: http://doi.org/10.3390/pr11102932

This paper introduces an innovative algorithm for optimizing radial placement of horizontal wells based on a 3D geological model of oil fields using radial well distribution. The authors present an analytical approach that substantially reduces computational time and resources compared to conventional methods such as multivariate hydrodynamic simulations or artificial intelligence algorithms. The methodology is based on an objective function that evaluates hydrocarbon mobility, volume of reserves as well as geological parameters including permeability, formation thickness, and relative phase permeability. The algorithm was rigorously tested on three synthetic reservoir models featuring diverse geological-physical properties and varying conditions for radial placement of horizontal wells. Computational results demonstrate that the proposed method delivers comparable efficiency to optimization algorithms (with only 1,1-3,5 % variance in oil recovery), while it requires 78 times less computational time. This exceptional performance makes the algorithm particularly valuable during the early-stage of field development planning when rapid decision-making under conditions of significant data uncertainty is critical. Due to the fact that nowadays in Russia there is a tendency towards an increase in the volume of production engineering works for new offshore hydrocarbon deposits the paper emphasizes the practical significance of the algorithm for offshore fields, where a limited number of wells and high drilling costs require accurate planning.

References

1. Dezhina I.G., Aktual'nye tekhnologicheskie napravleniya v razrabotke i dobyche nefti i gaza (Current technological trends in the development and production of oil and gas), Moscow: BiTuBi Publ., 2017, 220 p.

2. Tveiterå L.K., Fismen M.B., Asgeir Ch.A., Ivar F.O., Overcoming subsurface challenges to develop a thin oil column – A case study from the five decade Old Gekko discovery in the Alvheim area, SPE-209543-MS, 2022, DOI: https://doi.org/10.2118/209543-MS

3. Suleymanov A.B., Kuliev R.P., Sarkisov E.I., Karapetov K.A., Ekspluatatsiya morskikh neftegazovykh mestorozhdeniy (Exploitation of offshore oil and gas fields), Moscow: Nedra Publ., 1986, 285 p.

4. Magizov B., Topalova T., Loznyuk O. et al., Automated identification of the optimal sidetrack location by multivariant analysis and numerical modeling. A real case study on a gas field, SPE-196922-MS, 2019, DOI: https://doi.org/10.2118/196922-MS

5. Islam J., Vasant P.M., Negash B.M. et al., A holistic review on artificial intelligence techniques for well placement optimization problem, Advances in Engineering Software, 2020, V. 141, DOI: https://doi.org/10.1016/j.advengsoft.2019.102767

6. Sayfullin A.A., Analytical tool development for deremining the optimal well trajectory (In Russ.), Nauka. Innovatsii. Tekhnologii, 2022, no. 3, pp. 47-74,

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7. Zou Caineng, Ding Yunhong, Lu Yongjun et al., Concept, technology and practice of “man-made reservoirs” development, Petroleum Exploration and Development, 2017, V. 44, pp. 146–158, DOI: https://doi.org/10.1016/S1876-3804(17)30019-8

8. Lukawski M.Z., Anderson B.J., Augustine Ch. et al., Cost analysis of oil, gas, and geothermal well drilling, Journal of Petroleum Science and Engineering, 2014, V. 118,

pp. 1–14, DOI: https://doi.org/10.1016/j.petrol.2014.03.012

9. Mohamed A.W., A novel differential evolution algorithm for solving constrained engineering optimization problems, Journal of Intelligent Manufacturing, 2018, V. 29,

pp. 659–692, DOI: https://doi.org/10.1007/s10845-017-1294-6

10. Yushkov I.R., Khizhnyak G.P., Ilyushin P.Yu., Razrabotka i ekspluatatsiya neftyanykh i gazovykh mestorozhdeniy (Development and operation of oil and gas fields), Perm: Publ. of PSTU, 2013, 177 p. 2

The hydroisomerization of linear alkanes represents a cornerstone process in modern petroleum refining, particularly in the catalytic isodewaxing of middle distillate fractions. This transformation is industrially vital for producing premium low-pour-point diesel fuels and high-performance lubricants, where improved cold-flow properties are achieved through selective branching of hydrocarbon chains. In this work, zeolite ZSM-23, silicoaluminophosphates SAPO-11 and SAPO-31 were synthesized, and commercial zeolite ZSM-5 was used. Based on these molecular sieves, supports were prepared (using boehmite as a binder in an amount of 30 wt.%) and platinum catalysts on their basis (Pt content – 0,5 wt.%). At each step of synthesis, the materials, supports, and catalysts were characterized by X-ray diffraction, temperature-programmed desorption of ammonia (NH₃-TPD), low-temperature nitrogen adsorption, transmission and scanning. The catalytic activity was evaluated using a laboratory flow-type unit with a fixed catalyst bed reactor in the isomerization of n-hexadecane under the following conditions: hydrogen pressure of 3,5 MPa, feedstock liquid hourly space velocity of 4 h-1, temperature range of 230–400 °C, and a hydrogen-to-oil ratio of 600 Nm3/m3. The conversion of n-hexadecane and the selectivity toward cracking and isomerization reactions were compared for the synthesized catalysts. It was found that the SAPO-11-based catalyst provided the highest feedstock conversion and the maximum selectivity toward multi-branched isomers.

References

1. Makhmudova L.Sh., Akhmadova Kh.Kh., Khadisova Zh.T. et al., Production of waxy diesel fuels at refineries in Russia: Status and prospects (In Russ.), Rossiyskiy khimicheskiy zhurnal, 2017, no. 2, pp. 75–97.

2. Zinnatullina G.M., Baulin O.A., Spashchenko A.Yu. et al., Improvement of diesel fuel low-temperature properties (In Russ.), Proceedings of NIPI Neftegaz GNKAR, 2018, no. 2, pp. 77–81, DOI: https://doi.org/10.5510/OGP20180200354

3. Ermak A.A., Buraya I.V., Spiridonov A.V. et al., Methods of regulating the cloud point of diesel fuels (In Russ.), Vestnik Polotskogo gosudarstvennogo universiteta. Seriya B. Promyshlennost'. Prikladnye nauki, 2018, no. 11, pp. 112–117.

4. Bogdanov I., Morozova Y., Altynov A. et al., Ways to improve the effectiveness of depressant additives for the production of winter and arctic diesel fuels, Resources, 2024, V. 13, no. 2, pp. 1–19, DOI: http://doi.org/10.3390/resources13020027

5. Aljajan Y., Stytsenko V., Rubtsova M., Glotov A., Hydroisomerization catalysts for high-quality diesel fuel production, Catalysts, 2023, V. 13, no. 10,

DOI: http://doi.org/10.3390/catal13101363

6. Park K., Ihm S., Comparison of Pt/zeolite catalysts for n-hexadecane hydroisomerization, Applied Catalysis A: General, 2000, V. 203, pp. 201–209,

DOI: http://doi.org/10.1016/S0926-860X(00)00490-7

7. Kosareva O.A., Gerasimov D.N., Maslov I.A. et al., Effect of the zeolite type on catalytic performance in dewaxing of the diesel fraction under sour conditions, Energy & Fuels, 2021, V. 35, no. 19, pp. 16020–16034, DOI: http://doi.org/10.1021/acs.energyfuels.1c01484

8. Yakovenko R.E., Agliullin M.R., Zubkov I.N. et al., Diesel fraction isodewaxing in the presence of granular platinum-containing SAPO-11 and SAPO-41 molecular sieves, Catalysis in Industry, 2024, V. 16, no. 2, pp. 178–186, DOI: https://doi.org/10.1134/S2070050424700089

9. Kondrashev D.O., Kleymenov A.V., Gulyaeva L.A. et al., Studies of the efficiency of diesel isodeparaffinization over a zeolite-containing nickel-molybdenum catalyst (In Russ.), Kataliz v promyshlennosti, 2016, no. 6, pp. 14–22, DOI: https://doi.org/10.18412/1816-0387-2016-6-14-22

10. Bogomolova T.S., Smirnova M.Y., Klimov O.V., Noskov A.S., Studying the hydroisomerization of diesel fractions with different concentrations of nitrogen-containing compounds on bifunctional catalysts based on ZSM-23 and non-noble metals, Catalysis in Industry, 2023, V. 15, no. 2, pp. 182–189,

DOI: http://doi.org/10.1134/S2070050423020034

11. Lan K., Zhou X., Zhang M. et al., Synergistic catalytic performance of Pt-Au bimetallic catalysts on high-crystallinity ZSM-23 zeolite for hexadecane hydroisomerization: metal-acid balance and enhanced isomerization selectivity, Inorganic Chemistry, 2024, V. 63, no. 20, pp. 9315–9325,

DOI: https://doi.org/10.1021/acs.inorgchem.4c01212

12. Bensafi B., Chouat N., Djafri F., The universal zeolite ZSM-5: Structure and synthesis strategies. A review, Coordination Chemistry Reviews, 2023, V. 496,

DOI: http://doi.org/10.1016/j.ccr.2023.215397

13. Sivasanker S., Design of catalysts for pour-point reduction of lube oil fractions, Bulletin of the Catalysis Society of India, 2003, V. 2, pp. 100–106.

14. Zhang M., Chen Y., Wang L. et al., Shape selectivity in hydroisomerization of hexadecane over Pt supported on 10-ring zeolites: ZSM-22, ZSM-23, ZSM-35, and ZSM-48, Industrial and Engineering Chemistry Research, 2016, V. 55, no. 21, pp. 6069–6078, DOI: http://doi.org/10.1021/acs.iecr.6b01163

15. Möller K., Bein T., Crystallization and porosity of ZSM-23, Microporous and mesoporous materials, 2011, V. 143, no. 2–3, pp. 253–262,

DOI: http://doi.org/10.1016/j.micromeso.2010.12.019

16. Lin H., Xu C., Wang W., Wu W., In situ synthesis of nanosized ZSM-12 zeolite isomorphously substituted by gallium for the n-hexadecane hydroisomerization, Chemical Synthesis, 2024, V. 4, no. 3, DOI: http://doi.org/10.20517/cs.2024.40

17. Li H., Sun K., Xiong S. et al., Highly effective Pt-Pd/ZSM-22 catalysts prepared by the room temperature electron reduction method for the n-hexadecane hydroisomerization, Fuel Processing Technology, 2024, V. 262, DOI: http://doi.org/10.1016/j.fuproc.2024.108117

18. Shen Y., Qiao L., Zhang Z. et al., Synthesis, structure, and acidity regulation of ZSM-12 zeolite in alkane isomerization, Fuel, 2025, V. 380,

DOI: http://doi.org/10.1016/j.fuel.2024.133221

19. De Sousa L.V. Júnior, Silva A.O.S., Silva B.J.B., Alencar S.L., Synthesis of ZSM-22 in static and dynamic system using seeds, Modern Research in Catalysis, 2014,

V. 3, no. 2, pp. 49–56, DOI: http://doi.org/10.4236/mrc.2014.32007

20. Wu Q., Yuan J., Guo C. et al., The hydroisomerization of n-hexadecane over Pd/SAPOs bifunctional catalysts with different opening size: Features of the diffusion properties in pore channels and the metal-acid synergistic catalysis, Fuel Processing Technology, 2023, V. 244, DOI: http://doi.org/10.1016/j.fuproc.2023.107692

21. Zhang S., Chen S.L., Dong P. et al., Characterization and hydroisomerization performance of SAPO-11 molecular sieves synthesized in different media, Applied Catalysis A: General, 2007, V. 332, no. 1, pp. 46–55, DOI: http://doi.org/10.1016/j.apcata.2007.07.047

22. Shi J., Wang Y., W. Yang et al., Recent advances of pore system construction in zeolite-catalyzed chemical industry processes, Chemical Society Reviews. Royal Society of Chemistry, 2015, V. 44, no. 24, pp. 8877–8903, DOI: http://doi.org/10.1039/c5cs00626k

23. Zhang Y., Guo C., Wang W. et al., Effect of diffusion and metal-acid synergy on catalytic behavior of the Pd/Hierarchical SAPO-31 nanoparticles for hydroisomerization of n-hexadecane, Fuel Processing Technology, 2024, V. 256, DOI: http://doi.org/10.1016/j.fuproc.2024.108076

24. Pirutko L.V., Parfenov M.V., Lysikov A.I. et al., Synthesis of micro-mesoporous ZSM-23 zeolite, Petroleum Chemistry, 2021, V. 61, pp. 276–283,

DOI: http://doi.org/10.1134/S0965544121020080

25. Souverijns W., Martens J.A., Froment G.F., Jacobs P.A., Hydrocracking of isoheptadecanes on Pt/H-ZSM-22: An example of pore mouth catalysis, Journal of Catalysis, 1998, V. 174, no. 2, pp. 177–184, DOI: http://doi.org/10.1006/jcat.1998.1959

The article is devoted to solving the problem of increasing the accuracy of structural imaging and the possibility of more detailed tracing of tectonic dislocation by using prestack depth migration processing (PSDM) on the example of the seismic data of Rosneft Oil Company. Unfortunately, the tools for the conventional time processing sequence do not always enable to compensate existing deep velocity anomalies (specific features of Western Siberia such as zones gas deposits, abnormally high pressure formation zones, various local anomalies), which negatively affect the results of structural interpretation. On the contrary, the technology of prestack depth migration enables to obtain image of geological structure with less error, to take into account the influence of velocity anomalies on the wave field, and to improve faults imaging. The article presents the results of PSDM, using the examples of two deposits developed by Rosneft oil company in the north of Western Siberia. During both surveys the processing was performed using domestic software Prime, which is fully functional software for interactive interpretive processing of seismic data, developed in accordance with the modern concepts of depth processing. The examples, despite the different nature of the velocity depth anomalies, in both cases illustrate the successful experience of using PSDM. The materials presented in the article prove that the synergy in the working of related specialists (processing, interpretation and geology) and the continuity of the stages of studying the deposit lead to the best results.

References

1. Voskresenskiy Yu.N., Postroenie seysmicheskikh izobrazheniy (Seismic imaging), Moscow: Publ. of Gubkin University, 2006, 116 p.

2. Anisimov R.G., Davletkhanov R.T., Some technological methods used for layer-based velocity-depth model building (In Russ.), Geofizika, 2007, no. 1, pp. 2–7.

3. Glogovskiy V.M., Meshbey V.I., Tseytlin M.I., Langman S.L., Kinematiko-dinamicheskoe preobrazovanie seysmicheskoy zapisi dlya opredeleniya skorostnogo i glubinnogo stroeniya sredy (Kinematic-dynamic transformation of a seismic record to determine the velocity and depth structure of the medium), Proceedings of the 2nd scientific seminar of the CMEA member countries on petroleum geophysics, Part 1. Seysmorazvedka (Seismic exploration), Moscow: Publ. of CMEA, 1982, pp. 327–331.

In connection with the recent geological modeling studies, an updated geological model of the Kolgan terrigenous strata of the Upper Devonian in the south of the Orenburg region is presented. The depth-velocity geologic model reveals a number of features of its structure. For the first time it was shown that the boundaries of the Kolgan formation spreading were delineated based on the results of interpretation of the common depth point method (CDPM)-3D seismic depth cube. The presence of the Kolgansko-Borisovsky paleo-trough was clarified and proved. It is noted that all deposits of the Kolgan formation are mainly located in the areas of tectonic faults and have structural-tectonic and lithological-sedimentary nature. The main productive reservoirs are made of terrigenous sandy sediments and have nomination Dkt1 - Dkt3, possibly in some wells there are Dkt4, Dkt5 reservoirs. At present 41 deposits have been discovered at 16 fields. As a result of this work, the zone of Kolgan deposits development within this paleo-fall was established, which is an additional tool for searching for hydrocarbon deposits in Dkt group formations. The boundaries of the Kolgan formation distribution can be clarified not only on the basis of well logging data, but also on the basis of seismic data. Based on the complex of data, the Kolgan strata thicknesses increase in the north and northeast directions from the territory of Zemlyansky license area, therefore, when planning further exploration in the region, attention should be paid to this fact when studying neighboring territories.

References

1. Pavlinova N.V., Usova V.M., Some features of composition and genesis of terrigenous rocks of kolganskaya strata (In Russ.), Vestnik Rossiyskogo universiteta druzhby narodov. Seriya: Inzhenernye issledovaniya = RUDN Journal of Engineering Research, 2012, no. 3, pp. 11–16.

2. Afanas’eva M.A., Kolgan thickness as perspective object for hydrocarbon prospecting in the limits of Buzuluk depression (In Russ.), Geologiya, geofizika i razrabotka neftyanykh i gazovykh mestorozhdeniy, 2011, no. 1, pp. 33–37.

3. Shibina T.D., Gmid L.P., Tatinskaya N.V., Nikitin Yu.I., Lithology and forecast of reservoirs in the Kolgan formation of the Vakhitovsky field of the Kichkasskaya area in the south of the Orenburg region (In Russ.), Neftegazovaya geologiya. Teoriya i praktika, 2007, V. 2.

4. Nikitin Yu.I., Rikhter O.V., Vilesov A.P., Makhmudova R.Kh., Structure and formation conditions of the Kolganian suite on the south of the Orenburg region (In Russ.), Neftegazovaya geologiya. Teoriya i praktika, 2014, no. 2, URL: http://www.ngtp.ru/rub/4/21_2014.pdf

5. Baranov V.K., Galimov A.G., Lithological criteria of oil-bearing capacity of Upper Devonian deposits in the south of the Orenburg region (In Russ.), Otechestvennaya geologiya, 1996, no. 7, pp. 5–17.

6. Poberezhnyy S.M., Afanas’eva M.A., Polyakova M.A., Yaroshenko A.V., Sedimentation models of the formation of the Kolgan strata of the East Orenburg ridge-like uplift (In Russ.), Geologiya, geografiya i global’naya energiya, 2010, no. 3, pp. 22–36.

7. Kosmynin V.A., Kuz’min D.A., Lithofacies analysis and assessment of oil and gas potential of Kolgan strata deposits in the south of the Orenburg region (In Russ.), Regional’naya geologiya i metallogeniya, 2013, no. 56, pp. 31–39.

8. Fomina G.V., Kaydalov V.I., Borisova E.V. et al., Search for non-anticlinal traps in terrigenous deposits of the Orenburg region (In Russ.), Geologiya nefti i gaza, 1988, no. 10, pp. 14–16.

9. Postoenko P.I., Cherepanov A.G., Prospects of oil bearing Frasnian - Lower Famennian deposits in the south-east of the Volga-Kama anteclise (In Russ.) Geologiya nefti i gaza, 1992, no. 2., pp. 10–14.

10. Yakhimovich G.D., Kolganskiy neftegazonosnyy basseyn i rol’ tektoniki v ego formirovanii (Kolgansky oil and gas basin and the role of tectonics in its formation), Collected papers “Geologiya i razrabotka neftyanykh i gazovykh mestorozhdeniy Orenburgskoy oblasti” (Geology and development of oil and gas fields in the Orenburg region), Orenburg: Orenburgskoe knizhnoe izdatel’stvo Publ., 1998, pp. 72-76.

11. Korotkov B.S., Medvedev N.F., Serebryakova E.S., Kolganskaya tolshcha – osobennosti rasprostraneniya i perspektivy neftegazonosnosti (Kolganskaya strata – features of distribution and oil and gas potential), In: Problemy geologii prirodnogo gaza Rossii i sopredel’nykh stran (Problems of natural gas geology in Russia and neighboring countries), Moscow: Publ. of VNIIGAZ, 2005, pp. 142–149.

In domestic practice of calculating and recalculating reserves, the assessment of water saturation of rocks is carried out using the Dakhnov – Archie model. Its parameters can be adjusted only for one constant value of mineralization. This model works well in pure non-clayey sandstones, but for clayey sandstone, it is necessary to use complex models of electrical conductivity based on measuring electrical conductivity at different mineralization, taking into account the effect of additional conductivity arising at the boundary of the liquid and solid phase. Using experimental data on the electrical conductivity of core samples at different mineralizations in the full and partial water saturation mode, three models of electrical conductivity were considered: B.Yu. Wendelshtein, Waksman – Smits,, Double Water. A number of assumptions, including the effect of double electric layer (DEL) on the saturation parameter and the need to normalize additional electrical conductivity to the current water saturation to account for the increase in the effect of the DEL with a decrease in water saturation, required verification on core samples. The influence of mineralization on the cementation coefficient was confirmed; the influence of the saturation parameter on the rock remains the same regardless of mineralization. New data do not confirm the need to take into account the influence of the DEL on the saturation coefficient and normalize the additional electrical conductivity to the current water saturation with a decrease in the total water saturation. The modification of the models was performed, which resulted in simplification and improvement of the convergence of the calculated electrical conductivities with experimental data.

References

1. Archie G.E., The electrical resistivity log as an aid in determining some reservoir characteristics, Transactions of the AIME, 1942, V. 146, pp. 54-62,

DOI: http://doi.org/10.2118/942054-G

2. Dakhnov V.N., Interpretatsiya karotazhnykh diagramm (Interpretation of well logs), Moscow-Leningrad: Gostoptekhizdat, 1941, 496 p.

3. Dakhnov V.N., Geofizicheskie metody opredeleniya kollektorskikh svoystv i neftegazonasyshcheniya gornykh porod (Geophysical methods for the determination of reservoir properties and oil and gas saturation of rocks), Moscow: Nedra Publ., 1985, 310 p.

4. Ellanskiy M.M., Petrofizicheskie svyazi i kompleksnaya interpretatsiya dannykh promyslovoy geofiziki (Petrophysical relationships and complex interpretation of production geophysics data), Moscow: Nedra, 1978, 215 p.

5. Ellanskiy M.M., Ispol'zovanie sovremennykh dostizheniy petrofiziki i fiziki plasta pri reshenii zadach neftegazovoy geologii po skvazhinnym dannym (Using modern achievements of petrophysics and reservoir physics in solving problems of oil and gas geology based on well data), Moscow: Publ. of Gubkin University, 1999, 111 p.

6. Vendel'shteyn B.Yu., On the relationship between the porosity parameter, surface conductivity coefficient, diffusion-adsorption activity and adsorption causes of terrigenous rocks (In Russ.), Proceedings of MINKhiGP, 1960, V. 31, pp. 16–30.

7. Clavier C, Coates G, Dumanoir J., Theoretical and experimental bases for the Dual-Water model for interpretation of ShalySands, SPE-6859-PA, 1984,

DOI: http://doi.org/10.2118/6859-PA

8. Waxman M.H., M. Smits L.J., Electrical conductivities in oil-bearing shaly sands, Society of Petroleum Engineers Journal, 1968, DOI: https://doi.org/10.2118/1863-A

9. Simandoux P., Dielectric measurements in porous media and application to shaly formation, Revue del’Institut Francais du Petrole, 1963, pp. 193–215 (Translated text in SPWLA Reprint Volume Shaly Sand, July 1982).

10. Poupon A., Leveaux J., Evaluation of water saturation in shaly formations, Trans. SPWLA 12th Annual Logging Symposium, 1971, pp. 1–2.

11. Dakhnov V.N., Promyslovaya geofizika (Industrial geophysics), Moscow: Gostoptekhizdat Publ., 1959, 423 p.

The presence of tectonic fractures in rocks can have a significant impact on the absorption of drilling mud during well drilling. Prediction of mud losses in zones of natural fracturing formed by tectonic activity is based on careful study of geophmorphology and tectonogenesis of fracturing, lithology, pore pressure, rock strength and many other geological features of the fields. The information obtained is used in the design of drilling technology, well casing design, selection of fillers, characteristics and formulation of drilling mud necessary for the successful drilling. The most difficult conditions for drilling are fractured rocks in the zone of stretching of tectonic blocks of the sedimentary cover. The mud losses under these conditions are often disastrous, accompanied by decrease in the level of mud in the well. The well normalization works have a protracted nature, which sharply reduces the efficiency of well construction and incurs financial costs. The risk of mud loss while drilling into fault zones in other cases is manageable. To prevent mud loss during drilling a careful geological analysis, a corresponding drilling technology and provision of loss circulation materials are required. The integrated application of these measures helps to identify faults, prevent mud losses and even exclude them fully, as well as minimize the consequences of their occurrence. An approach is proposed to assess the degree of influence of rock fracture zones on well drilling to minimize the risks of complications using generalization of experience of drilling wells at the fields of the Vietsovpetro JV.

References

1. Basargin Yu.M., Bulatov A.I., Proselkov Yu.M., Oslozhneniya i avarii pri burenii neftyanykh i gazovykh skvazhin (Current issues and innovative solutions in the oil and gas industry), Moscow: Nedra Publ., 2002, 680 p.

2. Hossain M.E., Islam M.R., Drilling engineering, problems and solutions. A field guide for engineers and students, John Wiley & Sons, 2018, 642 p.

3. Pustovoytenko I.P., Preduprezhdenie i metody likvidatsii avariy i oslozhneniy v burenii (Prevention and methods of eliminating accidents and complications in drilling), Moscow: Nedra Publ., 1987, 237 p.

4. Dourado M.M. et al., Particulate wellbore fluid strengthening methodology. Design and application in an offshore Vietnam severely depleted sand reservoir, Proceedings of International Petroleum Technology Conference, Bangkok, Thailand, 1-3 March 2023, DOI: http://doi.org/10.2523/IPTC-22786-MS

5. Nasiri A., Ghaffarkhah A. et al., Experimental and field test analysis of different loss control materials for combating lost circulation in bentonite mud, Journal of Natural Gas Science and Engineering, 2017, V. 44, pp. 1–8, DOI: http://doi.org/10.1016/j.jngse.2017.04.004

Based on the processing of field data, it was found that the Joule-Thomson effect occurs in the well - formation system, which can be used to prevent certain types of complications. The essence of the application of the Joule-Thomson effect in well drilling to control some processes is to compensate the pressure drop by backpressure due to the temperature difference between the well - formation system. At the same time, accidents caused by pressure drops in wells drilled from semi-submersible drilling rigs are also prevented. Development of optimal hydrodynamic and thermodynamic calculation methods, creation of thermohydrodynamic methods, hydrodynamic complexes can become one of the main directions of development of oil industry. The process of pressure drop compensation by back pressure can be implemented in various ways. Nevertheless, the best method, according to the author, is the method based on regulation of wellhead temperature of drilling mud. Regulation of the temperature of the drilling fluid is one of the effective methods of controlling technological processes during well drilling. Thus, the article shows that at a known temperature of the fluid leaving the well, the temperature of the fluid entering the well provides a thermodynamically normal drilling process. Based on data on temperature changes at the wellhead, it is possible to control the pressure drop in the well - reservoir system.

References

1. Movsumov A.A., Gidrodinamicheskie prichiny oslozhneniy pri provodke neftyanykh i gazovykh skvazhin (Hydrodynamic causes of complications during drilling of oil and gas wells), Baku: Azerneshr Publ., 1965, 230 p.

2. Səfərov Y.İ., Selection of technology for cleaning wells with holes before lowering the protective belts (In Azerb.), Azərbaycan Neft Təssərüfatı, 2007, no. 8, pp. 9–12.

3. Seid-Rza M.K., Tekhnologiya bureniya glubokikh skvazhin v oslozhnennykh usloviyakh (Technology for deep well drilling in difficult conditions), Baku: Azerneftneshr Publ., 1963, 208 p.

4. Proselkov Yu.M., Teploperedacha v skvazhinakh (Heat transfer in wells), Moscow: Nedra Publ., 1975, 223 p.

5. Shevtsov V.D., Preduprezhdenie gazoproyavleniy i vybrosov pri burenii glubokikh skvazhin (Prevention of gas manifestations and emissions during deep well drilling), Moscow: Nedra Publ., 1988, 198 p.

6. Alkhasov A.B., Teplofizika i teploperedacha v sistemakh geotermal'noy energetiki (Thermal physics and heat transfer in geothermal energy systems): thesis of doctor of technical science, Makhachkala, 2002, 276 p.

7. Baydyuk B.V., Mekhanicheskie svoystva gornykh porod pri vysokikh davleniyakh i temperaturakh (Mechanical properties of rocks at high pressures and temperatures), Moscow: Gostoptekhizdat Publ., 1963, 102 p.

8. Bulatov A.I., Ryabchenko V.I., Sibirko I.A., Sidorov N.A., Gazoproyavleniya v skvazhinakh i bor'ba s nimi (Gas manifestations in wells and their control), Moscow: Nedra Publ., 1969, 278 p.

9. Amirkhanov Kh.I., Suetnoy V.V., Levkovich R.A., Gairbekov Kh.A., Teplovoy rezhim osadochnykh tolshch (Thermal regime of sedimentary strata), Makhachkala: Dagestanskoe knizhnoe izdatel'stvo Publ., 1972, 230 p.

10. Aronov V.I., Three-dimensional approximation as a problem of processing, modeling and interpretation of geophysical and geological data (In Russ.), Geofizika, 2000, no. 4, pp, 21–25.

11. Aliev M.G., Baymurzaev A.L., Magomedov A.D., Evaluation of thermoelastic stresses of rocks in the walls of an uncased borehole (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 1966, no. 10, pp. 11–15.

12. Afanas'ev A.A., Zavisimost' temperatury tsirkulyatsionnogo potoka ot glubiny buryashcheysya skvazhiny (Dependence of the temperature of the circulation flow on the depth of the drilled well), Proceedings of MINKhiGP named after I.M. Gubkin, 1965, V. 53, pp. 73–83.

13. Gadzhiev F.M., Gidrogeologicheskie usloviya formirovaniya mestorozhdeniya nefti i gaza Yuzhno-Kaspiyskoy megavpadiny (Hydrogeological conditions of formation of oil and gas fields of the South Caspian megadepression), Moscow: Nedra Publ., 1998, 380 p.

14. Krylov V.I., Change in hydrodynamic pressure in a well depending on the speed of the drill string (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 1976, no. 1, pp. 13–16.

15. Dadashev I.A., Konvektivnyy teploobmen pri turbulentnom techenii burovykh rastvorov (Convective heat transfer in turbulent flow of drilling fluids), Krasnodar: Publ. of VNIIKRneft', 1976, pp. 157–162.

16. Es'man B.I., Termogidravlika pri burenii skvazhin (Thermal hydraulics in well drilling), Moscow: Nedra Publ., 1982, 247 p.

17. Es'man B.I., Dedusenko G.Ya., Yaishnikova E.A., Vliyanie temperatury na protsess bureniya glubokikh skvazhin (The influence of temperature on the process of deep well drilling), Moscow: Gostoptekhizdat Publ., 1962, 185 p.

18. Loytsyanskiy L.G., Mekhanika zhidkosti i gaza (Mechanics of liquid and gas), Moscow: Nauka Publ., 1973, 848 p.

19. Mekhtiev Sh.F., Mirzadzhanzade A.Kh., Aliev S.A., Teplovoy rezhim neftyanykh i gazovykh mestorozhdeniy (Thermal regime of oil and gas fields), Baku: Aznefteizdat Publ., 1960, 384 p.

20. Səfərov Y.İ., İsmayılov Ş.İ., Mürəkkəb şəraitdə neft və qaz quyularının qazıma texnologiyasının təkmilləşdirilməsi (Improving oil and gas well drilling technology in difficult conditions), Bakı: SADA, 2001, 182 p.

21. Səfərov Y.İ., Abışev C.H., Some problems in the hook and their prevention (In Azerb.), DNŞ-nin “Elmi Əsərlər” toplusu, 2004, no. 1.

22. Shatsov R.A., Shishenko R.I., Glikman L.S., Balitskiy P.V., Burenie neftyanykh i gazovykh skvazhin (Oil and gas well drilling), Mosocw: Gostoptekhizdat Publ., 1980, 219 p.

The purpose of selecting wells for geological and technical activities (GTA) is relevant for most fields that have been in development for a long time and characterized by a high degree of water content. Engineering approaches and various elements of geological and field analysis are used to address these issues. The analysis of areas and the selection of wells for planning activities are conducted based on full-scale 3D geological and hydrodynamic modeling. This approach is considered to be the most progressive and reliable. There are several complications related to the inability to quickly identify promising areas for side drilling. In order to quickly identify these areas, to choose the optimal method of their development and the azimuth, it becomes necessary to develop additional methods that are accessible and efficient, but do not reduce the reliability of forecasts and calculation of the effect of the proposed GTA. The article discusses an approach that includes preliminary area calculations of the expected production indicators, which enables to accelerate the procedure for selecting areas for the main types of GTA. The work analyzed formulas for calculating forecast oil flow rates for the main types of production wells at the Vikulovskaya formation of the Krasnoleninsky uplift, and initial data for calculations were established. The results of the calculations are maps of forecast oil flow rates that take into account the geological properties of the site, its current energy state, and the water cut of the extracted product.

References

1. Yanukyan A.P., Osobennosti razrabotki mestorozhdeniy nefti gorizontal'nymi skvazhinami (Features of oil field development by horizontal wells), Surgut: Publ. of TIU, 2020, 13 p.

2. Telkov A.P., Grachev S.I., Gidromekhanika plasta primenitel'no k prikladnym zadacham razrabotki neftyanykh i gazovykh mestorozhdeniy (Hydromechanics of the reservoir as applied to applied problems of oil and gas field development), Part II, Tyumen': Publ. of TyumSPTU, 2009, 269 p.

3. Bembel' S.R., Geologiya i kartirovanie osobennostey stroeniya mestorozhdeniy nefti i gaza Zapadnoy Sibiri (Geology and mapping of structural features of oil and gas fields in Western Siberia), Tyumen': Publ. of TIU, 2016, 215 p.

The article covers the topic of modern energy challenges which demand the development of efficient enhanced oil recovery (EOR) technologies, particularly in the context of growing depleting of conventional reserves and the exploitation of unconventional hydrocarbons. One of the promising solutions is the use of carbon dioxide enhanced oil recovery (CO2-EOR) method, which not only increases oil production volumes but also addresses environmental concerns through CO2 capture and storage. This study examines the utilization of CO2 in its various phase states (liquid, gaseous, supercritical), in combination with water and as part of dispersed systems (foams, surfactants, nanoparticles, and other additives). A comparative analysis of their efficiency under diverse geological and operational conditions is presented. It is demonstrated that CO2, due to its unique properties such as solubility, density, and phase transitions, significantly enhances oil recovery. Special attention is given to combined approaches and innovative dispersed systems that improve injection distribution and process efficiency. The article includes modeling results of continuous CO2 injection into a terrigenous reservoir using a case study from the Volga-Ural oil and gas province. The modeling confirms the advantages of CO2 as an EOR agent compared to traditional waterflooding methods (increase in oil recovery factor is of 1,1 %).

References

1. Smirnova E.A., Saychenko L.A., Hydrodynamic modeling and evaluation of partial substitution of cushion gas during creation of temporary underground gas storage in an aquifer, International Journal of Engineering, 2024, V. 37, no. 7, pp. 1221–1230, DOI: http://doi.org/10.5829/ije.2024.37.07a.02

2. Taber J.J., Martin F.D., Seright R.S., EOR screening criteria revisited. Part 1: Introduction to screening criteria and enhanced recovery field projects, SPE-35385-PA, 1997, DOI: http://doi.org/10.2118/35385-PA

3. Skobelev D., Cherepovitsyna A., Guseva T., Carbon capture and storage: net zero contribution and cost estimation approaches, Journal of Mining Institute, 2023,

V. 259, pp. 125–140, DOI: http://doi.org/10.31897/PMI.2023.10

4. Zhang L. et al., CO2 EOR and storage in Jilin oilfield China: Monitoring program and preliminary results, J Pet Sci Eng., 2015, V. 125, pp. 1–12,

DOI: http://doi.org/10.1016/J.PETROL.2014.11.005

5. Pavlova P.L., Bashmur K.A., Bukhtoyarov V.V., Analysis and development of proposals to improve the equipment and technologies of capture and injection of carbon dioxide at the oil fields, SOCAR Proceedings, 2022, Special Issue no. 1, DOI: http://doi.org/10.5510/OGP2022SI100687

6. Liu J. et al., Quantitative study of CO2 huff-n-puff enhanced oil recovery in tight formation using online NMR technology, J Pet Sci Eng., 2022, V. 216,

DOI: http://doi.org/10.1016/J.PETROL.2022.110688

7. Korobov G.Y. et al., Analysis of nucleation time of gas hydrates in presence of paraffin during mechanized oil production, International Journal of Engineering, 2024,

V. 37, no. 7, pp. 1343–1356, DOI: http://doi.org/10.5829/IJE.2024.37.07A.13

8. Zhang Y. et al., Molecular dynamics simulation of bubble nucleation and growth during CO2 Huff-n-Puff process in a CO­2­-heavy oil system, Geoenergy Science and Engineering, 2023, V. 227, DOI: http://doi.org/10.1016/J.GEOEN.2023.211852

9. Khan J.A. et al., Application of foam assisted water-alternating-gas flooding and quantification of resistivity and water saturation by experiment and simulation to determine foam propagation in sandstone, Heliyon, 2024, V. 10, no. 3, DOI: http://doi.org/10.1016/J.HELIYON.2024.E25435

10. Sun X. et al., On the application of surfactant and water alternating gas (SAG/WAG) injection to improve oil recovery in tight reservoirs, Energy Reports, 2021, V. 7,

pp. 2452–2459, DOI: http://doi.org/10.1016/J.EGYR.2021.04.034

11. Cheng Y. et al., A laboratory investigation of CO2 influence on solvent-assisted polymer flooding for improving viscous oil recovery on Alaska North Slope, Geoenergy Science and Engineering, 2023, V. 229, DOI: http://doi.org/10.1016/J.GEOEN.2023.212053

12. Shafiei M. et al., A comprehensive review direct methods to overcome the limitations of gas injection during the EOR process, Sci Rep., 2024, V. 14, no. 1,

DOI: http://doi.org/10.1038/s41598-024-58217-1

13. Sun X. et al., Experimental study of hybrid nanofluid-alternating-CO2 microbubble injection as a novel method for enhancing heavy oil recovery, J Mol Liq., 2024,

V. 395, DOI: http://doi.org/10.1016/J.MOLLIQ.2023.123835

14. Ricky E.X. et al., A comprehensive review on CO2 thickeners for CO2 mobility control in enhanced oil recovery: Recent advances and future outlook, Journal of Industrial and Engineering Chemistry, 2023, V. 126, pp. 69–91, DOI: http://doi.org/10.1016/j.jiec.2023.06.018

15. Pal R., Ghara M., Chattaraj P.K., Activation of small molecules and hydrogenation of CO2 catalyzed by frustrated Lewis pairs, Catalysts, 2022, V. 12, no. 2,

DOI: http://doi.org/10.3390/catal12020201

Reservoir production allocation is one of the most important issues of the multilayer marine oil field development. The solution of the issue is determined by the need to monitor and report oil recovery per reservoirs, localize remaining reserves, plan and implement infill drilling and well intervention programs to manage oil field development. In the meantime, production logging is not always technically possible or economically feasible in marine conditions. Production logging is limited by drilling rig availability on the platform, used for all downhole operations, and the high costs of all well interventions. The complex logistics and the harsh natural and climatic conditions introduce additional complications and restrictions for offshore operations. This paper summarizes the experience of oil production allocation per reservoirs using oil geochemical analysis for Piltun-Astokhskoye oil and gas condensate field. The methodology was developed for quantitative assessment of reservoir contribution to oil production based on oil geochemical analysis for a binary system. The methodology is deployed for well and reservoir surveillance and management, and used for reservoir production allocation, remaining reserves localization, refining geological and hydrodynamic models, planning and control of infill drilling and well intervention programs.The Expert and Technical Council of the State Reserves Commission of the Russian Federation approved the methodology in November 2024.

References

1. Dashkov R.Yu., Gafarov T.N., Singurov A.A. et al., Features of control over field development from offshore platforms (In Russ.), Gazovaya promyshlennost', 2022,

no. 7(835), pp. 28-38.

2. Schafer D., Bommarito O., Cooper K. et al., Geochemical oil fingerprinting - Implications of production allocations at Prudhoe Bay field, Alaska, SPE-146914-MS, 2011, DOI: https://doi.org/10.2118/146914-MS

3. Russkikh E.V., Murinov K.Yu., Using the chromatographic analysis for comparison of oil compositions and separation of production of wells, exploiting multilayer objects (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2017, no. 10, pp. 28–32, DOI: https://doi.org/10.24887/0028-2448-2017-10-28-32

4. Seytkhaziev E.Sh., Eltay G.G., Pangereeva Sh.S., Sarsenbekov N.D., Quantitative allocation of commingled production of crude oils from wells in Uzen field using geochemical analysis (In Russ.), Neft' i gaz, 2019, no. 4(112), pp. 87–113.

5. Xing Lingbo, Teerman S., Descant F., Time lapse production allocation using oil fingerprinting for production optimization in deepwater Gulf Mexico, SPE-193601-MS, 2019, DOI: https://doi.org/10.2118/193601-MS

6. Shipaeva M.S., Talipova K.R., Sudakov V.A. et al., Flow Profile Estimating in production wells based on chemical composition of fluids (an example on Volga.Ural Petroleum and gas Province) (In Russ.), Georesursy, 2023, no. 25(4), pp. 121–127, DOI: https://doi.org/10.18599/grs.2023.4.9

7. Pavlov D.V., Vasil'ev A.S., Oil fingerprinting technology for well and reservoir management (In Russ.), SPE-187781-MS, 2017, DOI: https://doi.org/10.2118/187781-MS

8. Pavlov D.V., Gafarov T.N., Oblakov R.G. et al., Geochemical characteristics of oils from Piltun-Astokhskoye oil and gas condensate field (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2025, no. 3, pp. 80–85, DOI: https://doi.org/10.24887/0028-2448-2025-3-80-85

9. Kaufman R.L., Ahmed A.S., Elsinger R.J., Gas chromatography as a development and production tool for fingerprinting oils from individual reservoirs: Applications in the Gulf of Mexico, Proceeding GCSSEPM Ninth Annual research Conference, 1990, pp. 263–282, DOI: https://doi.org/10.5724/gcs.90.09.0263

10. Kaufman R.L., Ahmed A.S., Hempkins W.B., A new technique for the analysis of commingled oils and its application to production allocation calculations, Proc. Ind. Petr. Ass. 16th Annual Convention, 1987, pp. 247–268, DOI: https://doi.org/10.29118/ipa.13.247.268

11. McCaffrey M.A., Ohms D.H., Werner M.S.Ch. et al., Geochemical allocation of commingled oil production or commingled gas production, SPE-144618-MS, 2011,

DOI: https://doi.org/10.2118/144618-MS

12. Nouvelle X., Rojas K., Stankiewicz A., Novel method of production back-allocation using geochemical fingerprinting, SPE-160812-MS, 2012,

DOI: https://doi.org/10.2118/160812-MS

Oil is one of the most valuable sources of energy, accounting for over 30 % of global primary energy consumption and about 20 % of global gross domestic product. In recent decades, there has been a significant increase in oil production, leading to the depletion of traditional oil resources. In this regard, more and more attention is being paid to hard-to-recover reserves (HTR). Hard-to-recover oil reserves (HROR) refer to those, the development of which requires the use of complex technologies and significant investment. In Russia, taxation of the oil and gas industry is an important and key instrument of state regulation. One of the main issues in taxation of HROR is determining the optimal tax level. Too high rates may lead to a decrease in investment in the development of such resources, and too low rates may not provide sufficient revenue for the state. When adopting a new taxation system for HTR, it is necessary to take into account many factors, such as economic conditions, technological capabilities and the interests of various market participants. This article examines the technology of developing a subsoil site in Western Siberia using a system of horizontal wells located across the direction of regional stress with an increased number of hydraulic fracturing stages (more than 16), and also proposes the use of an improved tax benefit in the form of a fixed deduction in the amount of capital investments in the years of active drilling of well pads with HTR.

References

1. V RF dolya trudnoizvlekaemoy nefti sostavlyaet pochti 60% obshchego ob"ema zapasov (In the Russian Federation, the share of hard-to-recover oil is almost 60% of the total volume of reserves), URL: https://tass.ru/ekonomika/19348339

2. Yumaev M.M., Current issues of taxation of the mineral resource complex of the Russian Federation (In Russ.), Finansy: ezhemesyachnyy teoreticheskiy i nauchno-prakticheskiy zhurnal, 2023, no. 1, pp. 29-35.

3. Kapishev D.Yu., Rakhimov M.R., Mironenko A.A., The choice of the optimal system for the development of ultra-low-permeable reservoirs on the example of the Erginsky license area on the Priobskoye field (In Russ.), Ekspozitsiya Neft' Gaz, 2022, no. 7, pp. 62–65, DOI: https://doi.org/10.24412/2076-6785-2022-7-62-65

4. Slozhnyy put' trudnoy nefti. Obzor (The difficult path of difficult oil. Review), URL: https://www.interfax.ru/business/843599

The article describes the advantages of using multiwell deconvolution to determine reservoir pressure at all operation stages of the well under study. The workflow process of reservoir pressure recovery in the presence of interfering wells is given. The RN-VEGA software package has the functionality of restoring reservoir pressure dynamics based on multi-well deconvolution and the method of fictitious periodic buildups in a customized deconvolution model. The functionality was tested on synthetic data and approbated on actual data of oil wells in low-permeability reservoirs. The values of the model parameters used in testing are close to the geological and physical characteristics of deposits with low-permeability reservoirs. The test well operation histories containing drawdown and buildup periods were modeled for testing. The last interval containing the buildup was removed from the synthetic histories. The deconvolution model is adjusted based on the reduced history data, the reservoir pressure was restored using the fictitious buildups method, with the duration of the fictitious buildups corresponding to the duration of the removed buildup. The value of the restored reservoir pressure at the beginning of the buildup was then compared with the value of the model bottomhole pressure at the end of the buildup. The functionality was approbated on production data using the same scenario. The results of testing and approbation were presented, which showed good coherence between the value of the restored reservoir pressure and the value of the bottomhole pressure at the end of the actual buildup.

References

1. Cumming J.A., Wooff D.A., Whittle T., Gringarten A.C., Multiwell deconvolution, SPE-166458-PA, 2014, DOI: http://doi.org/10.2118/166458-PA

2. Levitan M.M., Deconvolution of multiwell test data, SPE-102484-MS, 2006, DOI: http://doi.org/10.2118/102484-MS

3. Asalkhuzina G.F., Davletbaev A.Ya., Salakhov T.R., Loshak A.A. et al., Applying decline analysis for reservoir pressure determination (In Russ.),

Neftyanoe khozyaystvo = Oil Industry, 2022, no. 10, pp. 30-33, DOI: http://doi.org/10.24887/0028-2448-2022-10-30-33

4. Earlougher R.C. Jr., Advances in well test analysis, SPE Monograph Series, 1977, V. 5, 264 p.

5. Dake
L.P., The practice of reservoir engineering, Elsevier Science, 2001, 570 p.

In terms of increasing the efficiency of development of hard-to-recover reserves of the Achimov deposits in Western Siberia, a generalization of the indicators of long-term operation of the facility at typical oil fields is of particular interest. At the oilfield under consideration, the low-permeability Achimov layer is currently the first object of operation in terms of current oil production and the second in terms of oil reserves. This horizon has a significant area, but the oil saturated thickness and density of recoverable reserves are small. The maximum oil production rate was achieved in 2019. Production rates of more than 2 % were recorded from 2010 to 2019. The current drilling capacity of the well design fund is 75 %. Less than a half of the initial recoverable reserves were developed with a water content of about 80 %. Several stages were identified in the formation of the development system for the Achimov layer over the history. The ratio of the number of producing wells to injection wells has decreased to 2,1, the current compensation is at the level of 100 %. In the last decade, the average flow rate of liquid at the facility has increased. The commissioning of horizontal wells, side shafts and hydraulic fracturing have an important role in increasing and stabilizing of oil production in Achimov layer. It is recommended to continue drilling production, injection wells and side shafts, to carry out primary and repeated hydraulic fracturing, to transfer wells to the Achimov horizon from other development sites.

References

1. Vil'chik N.A., Zapasy nefti i otsenka rentabel'nosti razrabotki achimovskoy tolshchi (Oil reserves and assessment of the profitability of the development of the Achimov formation), Proceedings of scientific and practical conference named after N.N. Lisovsky, Kazan, 1–2 September 2019, Kazan, 2011.

2. Filonenko O.N., Osobennosti stroeniya zalezhey nefti achimovskoy tolshchi i zalegayushchikh vyshe gorizontov neokoma zapadnoy chasti Nizhnevartovskogo megavala (Features of the structure of oil deposits of the Achimov formation and the overlying Neocomian horizons of the western part of the Nizhnevartovsk megaswell), Proceedings of SibNIINP, 1986, pp. 11–17.

3. Nesterov V.N., Kharakhinov V.V., Semyanov A.A. et al., Geologicheskaya razvedka neftyanykh mestorozhdeniy Nizhnevartovskogo Priob'ya (Geological exploration of oil fields in the Nizhnevartovsk Ob region), Moscow: Nauchnyy mir Publ., 2006, pp. 151–167.

4. Ershov S.V., Kazanenkov V.A, Kontorovich A.E., Stroenie i perspektivy neftenosnosti klinoformnykh otlozheniy neokoma Nizhnevartovskogo svoda (Structure and oil-bearing potential of clinoform deposits of the Neocomian Nizhnevartovsk arch), Proceedings of III scientific and practical conference in Khanty-Mansiysk, 2000, Khanty-Mansiysk, 2000, pp. 39–48.

5. Baranov T.S., Mitkarev V.A., Bykov V.V. et al., Future prospects for oil resource base of Rosneft Oil Company OJSC in HMAO (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2009, no. 4, pp. 65–67.

6. Khitrenko A.V., Minkhatova A.M., Orlov V.A. et al., Influence of the main factors on the conditions of formation of the achimov formation (In Russ.), PRONEFT''.

Professional'no o nefti = PROneft. Professionally about oil, 2020, no. 2, pp. 18–24, DOI: https://doi.org/10.7868/S2587739920020020

7. Timirgalin A.A., Butorina M.G., Novikov N.A. et al., Achimov regional model as a business tool for forming a portfolio of new options for geological exploration in Western Siberia (In Russ.), PRONEFT''. Professional'no o nefti = PROneft. Professionally about oil, 2020, no. 3, pp. 10–15, DOI: https://doi.org/10.7868/S2587739920030015

8. Pecherin T.N., Galkina N.Yu., Mar'ina N.D., Osobennosti razrabotki achimovskikh otlozheniy Surgutskogo svoda (Features of the development of the Achimov deposits of the Surgut arch), Proceedings of XXI scientific and practical conference in Khanty-Mansiysk, 2018, Khanty-Mansiysk, 2018, pp. 51–59.

9. Chernobrovkina I.V. et al., Monitoring of oil field development: The path of development, new approaches to development (In Russ.), Vestnik nedropol'zovatelya KhMAO-Yugry, 2023, V. 31, pp. 3–10.

10. Gorbunov S.A., Nezhdanov A.A., Ponomarev V.A., Turenkov N.A., Geologiya i neftegazonosnost' achimovskoy tolshchi Zapadnoy Sibiri (Geology and oil and gas content of the Achimov strata of Western Siberia), Moscow: Publ. of Academy of Mining Sciences, 2000, 247 p.

11. Cherevko M.A., Optimizatsiya sistemy gorizontal'nykh skvazhin i treshchin pri razrabotke ul'tranizkopronitsaemykh kollektorov (Optimization of a system of horizontal wells and fractures in the development of ultra-low-permeability reservoirs): thesis of candidate of technical science, Tyumen, 2015.

12. Cherevko M.A., Yanin K.E., The first results of the application of multi-stage hydraulic fracturing in horizontal wells Priobskoye field (In Russ.), Neftyanoe

khozyaystvo = Oil Industry, 2015, no. 2, pp. 74–77.

13. Cherevko M.A., Yanin A.N., Yanin K.E., Razrabotka neftyanykh mestorozhdeniy Zapadnoy Sibiri gorizontal'nymi skvazhinami s mnogostadiynymi gidrorazryvami plasta (Development of oil fields in Western Siberia by horizontal wells with multi-stage hydraulic fracturing), Tyumen – Kurgan: Zaural'e Publ., 2015, 268 p.

14. Cherevko M.A., Yanin K.E., Analiz rezul'tatov ostanovki i vozobnovleniya dobychi na neftyanom promysle Aganskogo mestorozhdeniya (Analysis of the results of stopping and resuming production at the Aganskoye oil field), Proceedings of scientific and practical conference named after N.N. Lisovsky, St. Petersburg,

4–5 September 2024, St. Petersburg, 2024.

Research was conducted on the corrosion products formed after five years of operation of the PMR-20 tread alloy in a tank containing water with moderate salinity, with a salt content of 234 g/l. The experiments were carried out in the laboratory of the Department of Machinery and Equipment for Oil and Gas and Chemical Industries to perform both qualitative and quantitative assessments of the chemical and ionic composition of the corrosion products. The corrosion products were collected from a functioning protector which was used for protecting a vertical cylindrical RVS-500 tank from corrosion. Photographs of the PMR-20 tread alloy before and after six years of exposure in the tank clearly show significant areas of corrosion damage, as well as the formation of corrosion product deposits on its surface. A detailed analysis of the corrosion products revealed the underlying causes of their formation and helped evaluate whether the alloy could continue to be effectively used for corrosion protection. Methods for qualitative analysis of corrosion processes were presented, such as the drop indicator method, which facilitated the accurate identification of the ionic composition of the corrosion products. The study provided insights into the efficiency of the PMR-20 tread alloy in protecting industrial equipment operating in environments with aggressive saline conditions, ensuring its reliability for extended use.

References

1. Fazlutdinov K.K., Protektornaya zashchita ot korrozii s ispol’zovaniem magniya (Protective corrosion protection using magnesium), URL: https://zctc.ru/sections/magnesium_protection

2. Kats N.G., Chemical analysis of the magnesium alloy corrosion destruction (In Russ.), Vestnik Samarskogo gosudarstvennogo tekhnicheskogo universiteta Seriya “Tekhnicheskie nauki” = Vestnik of Samara State Technical University. Technical Sciences Series, 2018, no. 1(57), pp. 173–176.

3. Kats N.G., Ibatullin I.D., Parfenova S.N., Efficiency of tread alloys for vertical steel tanks (In Russ.), Neftegazovoe delo, 2023, V. 21, no. 5, pp. 192-197,

DOI: https://doi.org/10.17122/ngdelo-2023-5-192-197

4. Kats N.G., Zhivaeva V.V., Parfenova S.N., Corrosion protection of vertical tanks (In Russ.), Stroitel’stvo neftyanykh i gazovykh skvazhin na sushe i na more, 2021,

no. 11(347), pp. 61-64, DOI: https://doi.org/10.33285/0130-3872-2021-11(347)-61-64

5. Vasil’ev S.V., Kats N.G., Parfenova S.N. et al., General characteristic and properties of produced waters (In Russ.), Stroitel’stvo neftyanykh i gazovykh skvazhin na sushe i na more, 2011, no. 12, pp. 41-42.

6. Ammosov G.S., Ivanov D.S., Ammosov A.P., The features of corrosion exhaustion of tanks resource and assessment of intensity of stress state increasing in welds

(In Russ.), Nauka i obrazovanie, 2017, no. 1, pp. 75–80.

7. Kats N.G., Konovalenko D.V., Vasil’ev S.V., The analysis of the magnesium protector alloys destruction (In Russ.), Vestnik Samarskogo gosudarstvennogo tekhnicheskogo universiteta Seriya “Tekhnicheskie nauki” = Vestnik of Samara State Technical University. Technical Sciences Series, 2015, no. 4(48), pp. 130–134.

8. Kachestvennyy khimicheskiy analiz korrozionnogo porazheniya (Qualitative chemical analysis of corrosion damage), http://delta-grup.ru/bibliot/41/278.htm

Transportation of oil and petroleum products through main pipelines (MP) is accompanied by water accumulations (WA) formation. The most technological method of removing WA is by pumping the flow of oil/petroleum products. Several methods are known for predicting the flow rate, ensuring the beginning of simultaneous removal of the entire volume of WA. The proposed calculation formulas have either not been confirmed experimentally, or were acquired as a result of processing experimental data obtained on tubes of small diameter. The article describes the formula obtained in The Pipeline Transport Institute LLC, as a result of modeling the removal of WA from pipelines up to 1200 mm in diameter and successfully tested experimentally on the MP. The results of comparing the error in calculating the outrigger velocity according to this formula and the dependencies proposed by various authors are presented. New methodology, developed by The Pipeline Transport Institute LLC, enables to identify the locations of WA at a given pumping rate and properties of the pumped liquid, to assess the volume of WA and the additional energy consumption for pumping. An analysis of the operation of all the Transneft’s PJSC MPs was carried out. The sites of increased corrosion hazard of MPs were identified, recommendations given on the choice of a method for cleaning from WA. The article provides an example of the profile study of a technological section of one of the MPs for the location and size of WA at various flow rates and viscosity of the pumped oil.

References

1. Lebedich S.P., Issledovanie i razrabotka metodov povysheniya kachestva nefti pri perekachke po magistral'nym truboprovodam (Research and development of methods for improving the quality of oil when pumped through main pipelines): thesis of candidate of technical science, Ufa, 1979.

2. Kutukov S.E., Razrabotka metodov funktsional'noy diagnostiki tekhnologicheskikh rezhimov ekspluatatsii magistral'nykh nefteprovodov (Development of methods for functional diagnostics of technological modes of trunk pipelines operation): thesis of doctor of technical science, Ufa, 2003.

3. Lokshin A.A., Sovershenstvovanie tekhnologiy ekspluatatsii otkrytykh emkostey v sistemakh transporta i khraneniya nefti (Improving technologies for the operation of open tanks in oil transportation and storage systems): thesis of candidate of technical science, Ufa, 1999.

4. Akhmadullin K.R., Energosberegayushchie tekhnologii ochistki nefteproduktoprovodov gel'nymi sistemami (Energy-saving technologies for cleaning oil pipelines with gel systems): thesis of candidate of technical science, Ufa, 2001.

5. Porayko I.N., Savel'ev M.P., Vasilenko S.K., Cleaning of the Nizhnevartovsk-Ust-Balyk oil pipeline with high-viscosity polyacrylamide gels (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 1978, no. 3, pp. 61–65.

6. Korshak A.A., Pshenin V.V., Modeling of water slug removal from oil pipelines by methods of computational fluid dynamics (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2023, no. 10, pp. 117–122, DOI: https://doi.org/10.24887/0028-2448-2023-10-117-122.

7. GOST R 51858-2020. Neft'. Obshchie tekhnicheskie usloviya (Crude petroleum. General specifications).

8. Gallyamov A.K., Gubin V.E., Vliyanie skopleniy vody i gaza na ekspluatatsionnye kharakteristiki magistral'nykh truboprovodov (The influence of water and gas accumulations on the operational characteristics of main pipelines), Moscow: Publ. of VNIIOENG, 1970, 43 p.

9. Shammazov A.M., Gallyamov A.K., Korobkov G.E., About gas and liquid accumulations in pipelines (In Russ.), Izvestiya vuzov. Neft' i gaz, 1972, no. 8, pp. 82–87.

10. Korshak A.A., About removal of water clusters by pumping liquid flow (In Russ.), Problemy sbora, podgotovki i transporta nefti i nefteproduktov, 2018, no. 6(116),

pp. 90–98, DOI: https://doi.org/10.17122/ntj-oil-2018-6-90-98

11. Zholobov V.V., Moretskiy V.Yu., Talipov R.F., Distribution of volume of water accumulations in profile oil pipeline (In Russ.), Nauka i tehnologii truboprovodnogo transporta nefti i nefteproduktov = Science & Technologies: Oil and Oil Products Pipeline Transportation, 2022, no. 5, pp. 438–451, DOI: https://doi.org/10.28999/2541-9595-2022-12-5-438-451

12. Charnyy I.A., The influence of terrain and fixed inclusions of liquid or gas on the throughput of pipelines (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 1965, no. 6, pp. 51–55.

13. Lur'e M.V., Removal of water accumulations from the pipeline with the help of the pumped oil flow (In Russ.), Nauka i tehnologii truboprovodnogo transporta nefti i nefteproduktov = Science & Technologies: Oil and Oil Products Pipeline Transportation, 2017, no. 1(28), pp. 62–68.

14. Gallyamov A.K., Issledovaniya po povysheniyu effektivnosti ekspluatatsii gazonefteprovodov (Research on improving the efficiency of gas and oil pipelines): thesis of doctor of technical science, Ufa, 1973. s.

15. Didkovskaya A.S., Predotvrashchenie tekhnologicheskikh oslozhneniy posledovatel'noy perekachki nefteproduktov v usloviyakh nepolnoy zagruzki (Prevention of technological complications of sequential pumping of petroleum products under partial loading conditions): thesis of candidate of technical science, Moscow, 1998.

16. Gallyamov A.K., Baykov I.R., Aminev R.M., Estimation of the rate of removal of fluid accumulations from lower sections of pipeline systems (In Russ.), Izvestiya vuzov. Neft' i gaz, 1969, no. 12, pp. 73-76.

The article presents a comprehensive methodology for assessing climate risks, developed and implemented in Zarubezhneft JSC. The process consists of six interrelated phases: collection of climate data (based on materials of Roshydromet and regional models of CORDEx), the comparison of actual criteria with the baseline values, the calculation of the intensity changes, the assessment of negative impact on the free cash flow and volumes of production, cross-functional risk modeling sessions and damages modeling with the use of specialized software (ModelRisk, @Risk). Using the example of abnormal atmospheric precipitations in 2022, it is shown how going beyond the forecast ranges leads to a reassessment of the risk and assigning it the status of significant. Special attention is paid to the role of interdisciplinary risk sessions bringing together experts from various fields, which enables not only to adjust estimates, but also to identify opportunities such as reducing infrastructure operating costs when temperature conditions change. The modeling results are integrated into the financial and economic models of the company, ensuring transparency of management decisions. The methodology complies with the principles of ESG (Environmental, Social, Governance) and demonstrates the effectiveness of a systematic approach to minimize damage and increase business sustainability. The introduction of artificial intelligence tools to improve the accuracy of forecasts in the face of growing climatic uncertainty is recognized as a promising area of development.

References

1. IPCC, 2021: Climate Change 2021: The Physical Science Basis. Contribution of Working Group I to the Sixth Assessment Report of the Intergovernmental Panel on Climate Change: edited by Masson-Delmotte V. et al., Cambridge University Press, Cambridge, United Kingdom and New York, NY, USA, 2023, 2391 p.,

DOI: https://doi.org/10.1017/9781009157896

2. SASB Standards: Oil & Gas – Exploration & Production. Sustainable Industry Classification System® (SICS®) EM-EP, under Stewardship of the International Sustainability Standards Board,Version 2023-12, URL: https://sasb.ifrs.org/standards/

The article analyzes the state of the oil industry in a number of regions of the South of Russia: the Rostov Region, the Krasnodar Territory and the Stavropol Territory. It is shown that the oil industry of the regions of the South of Russia has a significant potential, the development of which requires purposeful efforts focused on the introduction of innovative technologies in oil production and refining to minimize the impact on the environment and increase the efficiency of the use of natural resources. Within the framework of this study, a comprehensive analysis of the factors that have a special impact on the sustainable development of the oil industry of these regions was carried out, taking into account economic and political aspects. In addition, special attention was paid to the existing state support programs, which are aimed at modernizing the industry and increasing its competitiveness, based on today's realities. In addition to the economic analysis of the industry, the results of a sociological survey among the heads of industrial production were included, which enabled to determine key ideas about the functioning of the oil complex. As a result of the analysis, the factors influencing the development of the oil industry in the regions under study are identified, as well as a number of conditions ensuring its efficiency are substantiated. Attention was focused on the need to form a comprehensive system for stimulating industrial development, which is based on the state support for the oil industry in the regions.

References

1. Trofimov S.E., State policy in the oil and gas complex of Russia: current state and strategic prospects (In Russ.), Neftegaz.RU, 2024, no. 10(154),

URL: https://magazine.neftegaz.ru/articles/gosregulirovanie/860039-gosudarstvennaya-politika-v-neftegazov...

2. Trofimov S.E., Institutional approach to state regulation of oil and gas industry: Methodological provisions of advanced development of the Russian economy (In Russ.), Neftegaz.RU, 2024, no. 7(151), URL: https://magazine.neftegaz.ru/articles/gosregulirovanie/842902-institutsionalnyy-podkhod-k-gosudarstv...

3. Krasivskaya V.N., The state’s role in modernisation of oil branch in the last third. Of XIX – the beginning of the XX centuries (In Russ.), Vestnik Surgutskogo gosudarstvennogo pedagogicheskogo universiteta, 2018, no. 6(57), pp. 137–142, DOI: 10.26105/SSPU.2019.57.6.013

4. Ponomarenko T.V., Gorbatyuk I.G., Solov'eva V.M., Dirani F., Choosing forms and tools of state support for oil and gas projects (In Russ.), Ekonomika, predprinimatel'stvo i pravo = Journal of Economics, Entrepreneurship and Law, 2024, V. 14, no. 7, pp. 3419–3434, DOI: https://doi.org/10.18334/epp.14.7.121091

5. URL: https://admkrai.krasnodar.ru/content/1140/

6. URL: https://23.rosstat.gov.ru/production_kk

7. Novoshakhtinskiy NPZ napravit 40 mlrd rub. na sozdanie moshchnostey dlya vypuska Evro-5 (Novoshakhtinsky Oil Refinery to allocate 40 billion rubles to create capacity for Euro-5 production), Neftegaz.ru, 2021, URL: https://neftegaz.ru/news/neftechim/728420-novoshakhtinskiy-npz-napravit-40-mlrd-rub-na-sozdanie-mosh...

8. Krasnodarskiy kray – lider YuFO po neftepererabotke (Krasnodar Krai is the leader in the Southern Federal District in oil refining), URL: https://pav-edin23.ru/2022/09/03/krasnodarskij-kraj-lider-yufo-po-neftepererabotke/

9. Kratkaya kharakteristika Rostovskoy oblasti (Brief description of the Rostov region), URL: https://www.donland.ru/activity/7/

10. URL: https://minprom.donland.ru/activity/2370/

11. Ofitsial'nyy internet-portal Ministerstva energetiki, promyshlennosti i svyazi Stavropol'skogo kraya (Official Internet portal of the Ministry of Energy, Industry and Communications of Stavropol Krai), URL: https://www.stavminprom.ru/

12. Informatsionnyy pasport Stavropol'skogo kraya (Information passport of Stavropol Krai), URL: https://www.mid.ru/ru/foreign_policy/economic_diplomacy/vnesneekonomiceskie-svazi-sub-ektov-rossijsk...

13. Idrisov G.I., Promyshlennaya politika Rossii v sovremennykh usloviyakh (Industrial policy of Russia in modern conditions), Moscow: Publ. of The Gaidar Institute, 2016, 160 p.

14. Luk'yanova A. A. Avramchikova N.T., Ivanov D.S., Analysis of factors for increasing the efficiency of the oil and gas complex and their impact on the stability of the regional economic system (In Russ.), Vestnik evraziyskoy nauki, 2023, V. 15, no. 4. – EDN PZZLXL.

15. Energeticheskaya strategiya na period do 2035 goda, utverzhdena rasporyazheniem Pravitel'stva ot 9 iyunya 2020 goda №1523-r (Energy Strategy for the period up to 2035, approved by Government Decree No. 1523-r dated June 9, 2020), URL: https://www.consultant.ru/document/cons_doc_ LAW_354840/

16. Glukhova E.V., State participation as a necessary condition for the development of the oil and gas complex (In Russ.), Nauchnoe obozrenie. Ekonomicheskie nauki, 2023, no. 3, pp. 5-9, DOI: https://doi.org/10.17513/sres.1124

17. Golodnyuk R.A., Brazhnikova L.N., Tarash L.I. et al., Vyyavlenie mer gosudarstvennoy podderzhki prioritetnykh napravleniy razvitiya promyshlennosti (Identification of measures of state support for priority areas of industrial development), Donetsk: Publ. of Institute of Economic Research, 2022, 42 p.

18. Oil and gas complex of Russia and modern realities: Interview with the President of the Union of Oil and Gas Producers of Russia G.I. Shmal (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2022, no. 8, pp. 6–10.

19. Certificate of state registration of database no. 2024620982 RF. Razvitie ekonomicheskogo i promyshlennogo potentsiala rossiyskogo gosudarstva v usloviyakh tekhnologicheskoy blokady i sanktsiy Zapada: sovetskiy opyt i sovremennye resheniya (rezul'taty issledovaniya) (Development of the economic and industrial potential of the Russian state in the context of the technological blockade and sanctions of the West: Soviet experience and modern solutions (research results)), Authors: Chuev S.V., Polyakov M.B., Afanas'ev V.Ya. et al.

20. Chuev S.V., Afanas'ev V.Ya., Belokonev S.Yu. et al., Razvitie ekonomicheskogo i promyshlennogo potentsiala rossiyskogo gosudarstva v usloviyakh tekhnologicheskoy blokady i sanktsiy Zapada: sovetskiy opyt i sovremennye resheniya (Development of the economic and industrial potential of the Russian state in the context of the technological blockade and sanctions of the West: Soviet experience and modern solutions), Moscow: Publ. of State University of Management, 2023, 258 p.

21. Kadeeva Z.K., Government support for priority sectors of industry in contemporary conditions (In Russ.), Upravlenie ustoychivym razvitiem, 2016, no. 4(05), pp. 33–37.