References

1. Rukhin L.B., Osnovy litologii (Fundamentals of lithology), Leningrad: Gostoptekhizdat Publ., 1961, 780 p.

2. Chernikov O.A., Preobrazovaniye peschano-alevrolitovykh porod i ikh poristost′ (Transformation of sandy-siltstone rocks and their porosity), Moscow: Nauka Publ., 1969, 120 p.

3. Ivanov V.A., Khramova V.G., Diyarov D.O., Struktura porovogo prostranstva kollektorov nefti i gaza (The structure of the pore space of oil and gas reservoirs), Moscow: Nedra Publ., 1974, 97 p.

4. Kotyakhov F.I., Quantitative assessment of the structure of pore channels in oil and gas reservoir rocks (In Russ.), Neftepromyslovoye delo, 1962, no. 1, pp. 35–38.

5. Leybenzon L.S., Dvizheniye prirodnykh zhidkostey i gazov v poristoy srede (Movement of natural liquids and gases in a porous medium), Moscow – Leningrad: Gostekhteorizdat Publ., 1947, 244 p.

6. Mukhidinov SH.V., Tekhnologiya operativnykh issledovaniy neftegazonosnykh otlozheniy v razreze buryashchikhsya skvazhin na osnove metoda yaderno-magnitnogo rezonansa (na primere Vygnayakhinskogo mestorozhdeniya Zapadnoy Sibiri) (Technology for operational studies of oil and gas-bearing deposits in the section of drilled wells based on the nuclear magnetic resonance method (using the Vygnayakhinskoye field in Western Siberia as an example)): thesis of candidate of technical science, Moscow, 2011.

7. Belyakov E.O., The basic laws of the concept of pore space connectedness for petrophysical modeling of reservoir properties of Terrigenous oil rocks (In Russ.), PROneft′. Professional′no o nefti, 2020, No. 2, pp. 38–43, DOI: https://doi.org/10.7868/S2587739920020032

8. Vayner M.I., O vliyanii statisticheskogo kriteriya podobiya mikrostruktur poristoy sredy na kharakteristiki techeniya dvukhfaznoy zhidkosti v oblasti avtomodel′nosti po kriteriyu (On the influence of the statistical criterion of similarity of microstructures of a porous medium on the characteristics of the flow of a two-phase fluid in the region of self-similarity according to the criterion), Nauchno-tekhnicheskiy sbornik po dobyche nefti / VNII, 1964, Issue 25, pp. 57–70.

9. Vayner M.I., On some characteristic features of the structure of homogeneous porous media reservoirs (In Russ.), Izvestiya AN SSSR. Mekhanika zhidkosti i gaza = Fluid Dynamics, 1965, no. 5, pp. 166–168.

10. Kovalenko E.K., Khalimov E.M., K voprosu o vzaimosvyazi pronitsayemosti s pustotnost′yu i udel′noy poverkhnost′yu pri uchete struktury porody (On the relationship between permeability, voidage and specific surface area when taking into account the rock structure), Collected papers “Razrabotka i uvelicheniye nefteotdachi neftyanykh mestorozhdeniy” (Development and enhancement of oil recovery from oil fields), Moscow: Nedra Publ., 1967, pp. 60–65.

11. Tiab D., Donaldson E C., Petrophysics: theory and practice of measuring reservoir rock and fluid transport, Elsevier Inc., 2004, 926 p.

12. Engelhardt W., Der Porenraum der Sedimente, Berlin: Springer verl., 1960, 207 p.

13. Dullien F.A., Dhavan G.K., Nur Gurak, Babjak L., A relationship between pore structure and residual oil saturation in tertiary surfactant floods, SPEJ, 1972, V. 12, No. 14, pp. 289-296, DOI: https://doi.org/10.2118/3040-PA

14. Carman P., The flow of gases through porous media, London, 1956, 182 p.

15. Dmitrievskiy A.N., Sistemnyy litologo-geneticheskiy analiz neftegazonosnykh osadochnykh basseynov (System lithological and genetic analysis of oil and gas sedimentary basins), Moscow: Nauka Publ., 1982, 230 p.

The objective of the work is to develop and implement a tool for automated integration and visualization of geological and geophysical data in a unified interactive interface. A dynamic tablet was created that enables automatic visualization of various data from corporate databases. The relevance of this tool is due to the need for operational analysis of geological and geophysical data to improve the work efficiency. Previously used methods of processing data from geophysical well surveys (GWS), geological and technological studies (GTS), core research, and other data mainly involved manual collection from disparate corporate information databases and lacked automated tools for data collection and operational visualization. The tool provides operational display and comparison of large volumes of information, including GWS results, GTS data, core research, and reservoir testing results. It can also be used for systematization of the data used; development of unified templates for various types of tasks; creation of an intuitive interface with the ability to customize data display; utilization of existing functionality in the domestic software complex used by the company for curves, intervals, and graphical primitives; integration with corporate information systems; visual comparison of different types of research or periodic studies of the same type from different dates. The practical significance of the work is confirmed by the successful implementation of the tool in production and its demand. The dynamic tablet is actively used by more than 350 specialists of the company. The use of the tool significantly accelerates data analysis and improves the quality of decision-making.

The article examines the importance of paleogeographic reconstructions for elements predicting of hydrocarbon system in poorly studied areas of the Barents-Kara region. Source rocks, reservoirs, and seals are formed in specific sedimentary environments and their properties directly depend on the genetic type of the host rocks. The creation of conceptual paleogeographic models becomes a key tool for predicting the distribution of the hydrocarbon system elements across the poor studied area. The sedimentary paleoenvironments determination is based on the analysis of outcrop, well core data and the results of seismic interpretation. Large tectonic elements with varying evolution and total sedimentary cover thickness were used as a basis for paleoreconstructions. The models were created taking into account the possible proximity of paleogeographic zones and the principle of sequential changes in environments across the surface and time. This paper presents paleogeographic models for key stages in the development of the Barents-Kara region during the Paleozoic, demonstrating the potential of petroleum source rocks predicting their properties and maturity in various zones. Paleogeographic reconstructions enabled to predict the distribution of thicknesses of lower, middle and late Paleozoic sedimentary units and to identify zones of development of potential oil and gas source rocks and natural reservoirs in the section of the sedimentary cover.

References

1. Malyshev N.A., Verzhbitskiy V.E., Skaryatin M.V. et al., Stratigraphic drilling in the Northern Kara Sea: First case and preliminary results (In Russ.), Geologiya i geofizika, 2023, V. 64, No. 3, pp. 46–65, DOI: https://doi.org/10.15372/gig2022131

2. Suslova A.A., Mordasova A.V., Gilayev R.M. et al., Phanerozoic history of the Barents-Kara region as the framework for petroleum potential assessment (In Russ.), Georesursy, 2025, V. 27, No. 2, pp. 74–92, DOI: https://doi.org/10.18599/grs.2025.2.7

3. Suslova A.A., Stupakova A.V., Bol′shakova M.A. et al., Characteristics of oil and gas source strata in the Barents-Kara region - the basis for basin analysis and resource forecasting (In Russ.), Delovoy zhurnal Neftegaz.RU, 2021, No. 2, pp. 65–71.

4. Kotik I.S., Maydl′ T.V., Kotik O.S., Pronina N.V., Petroleum source rocks of the Silurian deposits on the Chernov Swell (Timan-Pechora Basin) (In Russ.), Georesursy, 2020, No. 22(3), pp. 12–20, DOI: https://doi.org/10.18599/grs.2020.3.12-20

5. Abay T.V., Karlsen D.A., Olaussen S. et al., Organic geochemistry of Cambro-Ordovician succession of Ny Friesland, Svalbard, High Arctic Norway: Petroleum generation potential and bulk geochemical properties, Journal of Petroleum Science and Engineering, 2022, V. 218, No. 4, DOI: https://doi.org/10.1016/j.petrol.2022.111033

6. Blumenberg M., Weniger P., Kus J. et al., Geochemistry of a middle Devonian cannel coal (Munindalen) in comparison with Carboniferous coals from Svalbard, Arktos, 2018, No. 4, DOI: https://doi.org/10.1007/s41063-018-0038-y

7. Kolesnikova T.O., Mordasova A.V., Suslova A.A. et al., Evolution and formation conditions of petroleum potential of the Barents-North Kara Sea shelf based on basin modelling (In Russ.), Georesursy, 2025, V. 27, No. 2, pp. 93–117, DOI: https://doi.org/10.18599/grs.2025.2.8

8. Koeverden J.H., Nakrem H.A., Karlsen D.A., Migrated oil on Novaya Zemlya, Russian Arctic: Evidence for a novel petroleum system in the eastern Barents Sea and the Kara Sea, AAPG Bulletin, 2010, V. 94, No. 6, pp. 791–817, DOI: https://doi.org/10.1306/10200909146

9. Stupakova A.V., Bol′shakova M.A., Suslova A.A. et al., Generation potential, distribution area and maturity of the Barents-Kara Sea source rocks (In Russ.), Georesursy, 2021, V. 23, No. 2, pp. 6–25, DOI: https://doi.org/10.18599/grs.2021.2.1

10. Abdelmalak M.M., Minakov A., Faleide Ja.I., Drachev S.S., Lomonosov Ridge composite tectono-sedimentary element, Arctic Ocean, Geological Society memoir, 2024, V. 57, No. 1, DOI: https://doi.org/10.1144/m57-2022-72

The article presents a comprehensive method for interpreting geochemical data to reconstruct paleogeographic sedimentation conditions and optimize geosteering. The relevance of the work stems from the increasing volume of detailed geochemical information (from pulsed neutron gamma-ray spectrometry logging) and the need for its effective use in petroleum geology. Using a case study of the elemental composition analysis of rocks from the Bazhenov suite (well XX9, Western Siberia), the authors demonstrate a transition from merely recording the concentrations of individual elements (Si, Al, Fe, Mn, S, etc.) to constructing a system of interconnected geochemical coefficients. Key ratios (Si/Al, Fe/Mn, (Mg+Ca)/Al, S/Fe, K/Al, and others) are interpreted as indicators of paleogeographic environments. They enable the reconstruction of oxidation-reduction conditions in bottom waters, changes in biological productivity, sources of terrigenous material, and sea-level fluctuations. Based on the analysis of coefficient trends throughout the section, six paleogeographic intervals were identified, reflecting the evolution of the Bazhenov basin. The practical outcome of the work is the identification of stable geochemical markers. Quantitative criteria are proposed for identifying siliceous (Si/Al > 5), argillaceous (Al/Fe > 3), carbonate ((Mg+Ca)/Al > 0,5), and organic-rich (Fe/Mn > 15 and S/Fe > 100) layers. These markers can be used for real-time lithological identification of rocks and for geosteering. Integration of geochemical logging into the drilling process and the application of the interpretation method enable the creation of intelligent dynamic reservoir models. This directly contributes to increasing the contact ratio with the productive reservoir and improving the efficiency of field development.

References

1. Kopylov S.I., Sokolov S.V., Khomyakov A.S. et al., Software and methods for AINK-PL (Pulse-neutron gamma-spectrometry tool) (In Russ.), Karotazhnik, AIS, 2024, No. 2(328), pp. 43-65.

2. Hatch J.R., Leventhal J.S., Relationship between inferred redox potential of the depositional environment and geochemistry of the Upper Pennsylvanian (Missourian) Stark Shale Member of the Dennis Limestone, Wabaunsee County, Kansas, U.S.A., Chemical Geology, 1992, V. 99, No. 1–3, pp. 65–82,

DOI: https://doi.org/10.1016/0009-2541(92)90031-Y

3. Tribovillard N. et al., Trace metals as paleoredox and paleoproductivity proxies: An update, Chemical Geology, 2006, V. 232, No. 1–2, pp. 12–32,

DOI: https://doi.org/10.1016/j.chemgeo.2006.02.012

4. 4. Eder V.G., Krasavchikov V.O., Zanin Yu.N., Zamiraylova A.G., Svyaz' soderzhaniy organicheskogo ugleroda s porodoobrazuyushchimi elementami v porodakh bazhenovskoy svity Zapadnoy Sibiri (Relationship between organic carbon content and rock-forming elements in the rocks of the Bazhenov Formation of Western Siberia), In: Litologiya i poleznye iskopaemye (Lithology and minerals), 2001, No. 3, pp. 274–281.

5. Nesbitt H.W., Young G.M., Early Proterozoic climates and plate motions inferred from major element chemistry of lutites, Nature, 1982, V. 299, pp. 715–717,

DOI: https://doi.org/10.1038/299715a0

6. Beus A.A, Grigoryan S.V., Geokhimicheskie metody poiskov i razvedki mestorozhdeniy tverdykh poleznykh iskopaemykh (Geochemical methods of prospecting and exploration of solid mineral deposits), Moscow: Nedra Publ., 1975, 280 p.

The calculation of oil and gas reserves is strategically important for the country. One of the ways to perform it is geological modeling, which is carried out using the example of the P stratum of the Vogulkin formation of the Kayumovsky oil field, located in the Kondinsky district of the Khanty-Mansiysk Autonomous Region. The field was discovered in 1971, and the development began from the upper part of the Pre-Jurassic deposits of the KV stratum in 2005. In 2008, 2D and 3D seismic surveys delineated and detailed the P stratum located under the KV stratum. The geological reserves of oil and dissolved gas categories were calculated and approved for the field, and the oil recovery coefficient equals to 0,4. Eight complex uneven oil deposits were identified within the P stratum. The total oil-bearing area of the reservoir is 82520 thousand m2 with a depth of 2071 to 2407 m. The Kayumovsky oil field is recognized as unprofitable. After analyzing the stages of development of the P stratum, geological models of the Upper Jurassic sediments were constructed and the initial geological/recoverable reserves of oil and dissolved gas were clarified. It is proposed to drill the promising western deposit of the Vogulkin formation of the Abalak suite with horizontal sidetrack wells with a new water-based drilling fluid with nanoafrons to ensure the well walls stability. According to the drilling results, the increase in reserves in category B1 will amount to 18 % relative to accepted reserves.

References

1. Ivanova T.N., Chikisheva O.A., Definition of three-dimensional geological model on the example of the Perm region field (In Russ.), Estestvennye i tekhnicheskiye nauki, 2019, no. 3(129), pp. 115–118.

2. Mishulovich P.M., Petrov S.V., Geometallurgical models creation principles (In Russ.), Vestnik Sankt-Peterburgskogo universiteta. Nauki o Zemle, 2019, V. 64, no. 2,

pp. 249–266, DOI: https://doi.org/10.21638/spbu07.2019.205

3. Serebryakov A.O., Geologicheskoye mnogomernoye tsifrovoye modelirovaniye mestorozhdeniy (Geological multidimensional digital modeling of deposits), Moscow – Vologda: Infra-Inzheneriya Publ., 2021, 236 p.

4. Itkin V.Yu., Modelirovaniye geologicheskikh sistem (Modeling of geological systems), Moscow: Yurayt Publ., 2021, 85 p.

5. Gladkov E.A., Geologicheskoye i gidrodinamicheskoye modelirovaniye mestorozhdeniy nefti i gaza (Geological and hydrodynamic modeling of oil and gas fields), Tomsk: Publ. of TPU, 2012, 99 p.

6. Aleksandrov V.M., Belkina V.A., San′kova N.V. et al., Modelirovaniye geologo-geofizicheskikh parametrov. Dvukhmernoye modelirovaniye (Modeling of geological and geophysical parameters. Two-dimensional modeling), Moscow – Vologda: Infra-Inzheneriya Publ., 2023, 236 p.

7. Patent no 2835336 C1 RF. Composition for producing water-based drilling mud, Inventor: Ivanova T.N.

This paper presents the collaborative work experience of Zarubezhneft JSC, Giprovostokneft JSC, and RMNTK-Nefteotdacha LLC in optimizing technological solutions for the construction of geothermal wells at the Mutnovskoye field, located on the Kamchatka Peninsula. Given the remoteness from traditional oil and gas production centers and the imperative to enhance power supply reliability, the development of geothermal energy in this region holds critical economic importance. The field is characterized by unique geological and engineering conditions: high formation temperatures, reaching up to 350 °С, highly abrasive formations and a high risk of lost circulation during drilling and cementing operations. Building upon advanced oil and gas industry expertise, a comprehensive set of technological solutions was developed and implemented, including: the use of Polycrystalline Diamond Compact (PDC) bits, specifically engineered for the challenging conditions of the Mutnovskoye field; the integration of a Measurement While Drilling (MWD) downhole telemetry system; optimization of the well design and adjustment of the drilling fluid system; implementing enhanced procedures with the drilling crew to optimize well construction operations. The deployment of these solutions resulted in a significant improvement in drilling efficiency compared to previously drilled wells in the field. Furthermore, ensuring wellbore longevity is identified as the next priority. To address this challenge, a research and development project was initiated to refine the cementing slurry formulation and the cementing technology itself.

References

1. World Energy Outlook 2025. International Energy Agency (IEA), Paris, 2025, URL: https://www.iea.org/reports/world-energy-outlook-2025

2. The Future of Geothermal Energy. International Energy Agency (IEA), Paris, 2023, URL: https://iea.blob.core.windows.net/assets/cbe6ad3a-eb3e-463f-8b2a-5d1fa4ce39bf/TheFutureofGeothermal....

3. TASS. Solodov: na Kamchatke v blizhayshie 10 let dolya zelenoy energetiki vyrastet do 42 % (TASS. Solodov: In Kamchatka, the share of green energy will increase to 42 % in the next 10 years.), URL: https://tass.ru/ekonomika/24706297/

Under conditions of increased density of infill drilling, a critical issue is assessing the interference between new and existing wells. This paper presents a new approach to evaluating the productivity of horizontal wells, accounting for fracture trajectories during refracturing operations in densely drilled areas. With high well density and long-term production, hydraulic fracture trajectories become sensitive to both the pressure gradient in the target zone and to pre-existing, propped fractures from earlier stages. Considering these factors enables a more reliable productivity forecast and helps to identify the risks of fracture-driven interactions (fracture hits) with offset wells. In some cases, this enables to adjust fracturing parameters to achieve the desired geometry under conditions of highly heterogeneous local pressure and stress distribution. Fracture trajectory modeling was performed using a module developed as part of an innovative project at Rosneft Oil Company. Well productivity was assessed by integrating predicted fracture orientations for two completion methods: open hole and cemented plug-and-perf (PnP). Both technologies are applicable in formations with either low or high in-situ stress contrast. The study demonstrates that the primary risk in low-contrast environments is fracture interference with neighboring wells, while in high-contrast environments the main risk is the inability to achieve the designed fracture geometry.

References

1. Osorgin P.A., Kashapov A.A., Yegorov E.L. et al., Development of low-permeable terrigenous reservoirs using horizontal wells with multiple hydraulic fractures at Priobskoye license area of RN-Yuganskneftegas LLC (In Russ.), Neftyanoye khozyaystvo = Oil Industry, 2023, No. 6, pp. 38-43, DOI: https://doi.org/10.24887/0028-2448-2023-6-38-43

2. Yerastov S.A., Sadykov A.M., Gallyamov I.F. et al., The study of propagation of multiple hydraulic fractures in horizontal wells for the case of infill drilling (In Russ.),

Ekspozitsiya Neft′ Gaz, 2024, No. 5, pp. 44–49, DOI: https://doi.org/10.24412/2076-6785-2024-5-44-59

3. Kashapov A.A., Yegorov E.L., Kulushev M.M. et al., System approach to estimating the efficiency of infill drilling on the oil fields of Rosneft Oil Company (In Russ.), Neftyanoye khozyaystvo = Oil Industry, 2024, No. 4, pp. 64–69, DOI: https://doi.org/10.24887/0028-2448-2024-4-64-69

4. Galeev R.R., Zorin A.M., Kolonskikh A.V. et al., Optimal waterflood pattern selection with use of multiple fractured horizontal wells for development of the low-permeability formations (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2013, No. 10, pp. 62–65.

5. Rodionova I.I., Shabalin M.A., Mironenko A.A. et al., Field development plan and well completion system optimization for ultra-tight and ultra-heterogeneous oil reservoirs (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2019, No. 10, pp. 72–76, DOI: https://doi.org/10.24887/0028-2448-2019-10-72-76

6. Fedorov A.E., Dilmuhametov I.R., Povalyaev A.A. et al., Multivariate optimization of the development systems for low–permeability reservoirs of oil fields of the Achimov formation, SPE-201811-MS, 2020, DOI: https://doi.org/10.2118/201811-MS

7. Fedorov A.I., Davletova A.R., Kolonskikh A.V., Toropov K.V., Justification of the necessity to consider the effects of changes in the formation stress state in the low permeability reservoirs development (In Russ.), Nauchno-tekhnicheskiy vestnik OAO “NK “Rosneft’”, 2013, No. 2(31), pp. 25-29.

8. Berchenko I., Detournay E., Deviation of hydraulic fractures through poroelastic stress changes induced by fluid injection and pumping, International Journal of Rock Mechanics and Mining Sciences, 1997, V. 34, No. 6, pp. 1009–1019, DOI: https://doi.org/10.1016/S1365-1609(97)80010-X

9. Roussel N.P., Sharma M.M., Optimizing fracture spacing and sequencing in horizontal-well fracturing, SPE-127986-PA, 2011, DOI: https://doi.org/10.2118/127986-PA

10. Fedorov A.I., Davletova A.R., Reservoir stress state simulator for determining of fracture growth direction (In Russ.), Geofizicheskie issledovaniya = Geophysical research, 2014, V. 15, No. 1, pp. 15–26.

11. Certificate of state registration of computer program No. 2023667682. Programmnyy kompleks geologicheskogo modelirovaniya “RN-GEOSIM” 2.0 (PK “RN-GEOSIM” 2.0) (Software package for geological modeling «RN-GEOSIM» 2.0 (PC «RN-GEOSIM» 2.0)), Authors: Zakrevskiy K.E., Akhmetshina G.R.,

Bezrukov A.V. et al.

12. Saakyan M.I., Zakrevskiy K.E., Gazizov R.K. et al., The prospects of corporate geological modeling software creation (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2019, No. 11, pp. 50-54., DOI: https://doi.org/10.24887/0028-2448-2019-11-50-54

13. Badykov I.Kh., Baykov V.A., Borshchuk O.S., The software package «RN-KIM» as a tool for hydrodynamic modeling of hydrocarbon deposits (In Russ.), Nedropol’zovanie XXI vek, 2015, No. 4, pp. 96–103.

14. Davletova A.R., Bikbulatova G.R., Fedorov A.I., Davletbaev A.YA., Geomechanical simulation of hydraulic fractures growth direction and trajectory in the low permeability reservoirs development (in Russ.), Nauchno-tekhnicheskiy vestnik OAO “NK “Rosneftʹ”, 2014, No. 1, pp. 40–43.

15. Latypov I.D., Borisov G.A., Khaydar A.M. et al., Reorientation refracturing on RN-Yuganskneftegaz LLC oilfields (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2011, No. 6, pp. 34–38.

16. Mitsukova D.S., Gil′miyanova A.A., Eyubov F.T. et al., Compaction drilling at Priobskoye oil field, retrospective analysis and prospects for further use (In Russ.), Neftegazovoye delo, 2022, No. 3, pp. 17–37, DOI: https://doi.org/10.17122/ngdelo-2022-3-17-37

17. Crouch S.L., Starfield A.M., Boundary element methods in solid mechanics, Unwin Hyman, 1990, 322 p.

One of the pressing tasks in the oil industry is developing effective methods for enhanced oil recovery (EOR) to increase the profitable operation period of fields during late-stage development. To improve the oil displacement coefficient, a surfactant-polymer flooding project was implemented at one of the fields operated by RUSVIETPETRO JV LLC. This field is characterized by complex operating conditions: high formation temperatures (70 °C), high salinity (209 g/l), hydrophobic carbonate reservoir, absence of pressure maintenance system, harsh Arctic climate, remoteness of the field, and limited accessibility of transport infrastructure. For this project, criteria were established for selecting surfactants and polymers, with an domestic produced surfactant selected based on these criteria. The effectiveness of the chosen surfactant-polymer formulation was confirmed through laboratory tests through experiments evaluating capillary desaturation curves with surfactant-polymer and surfactant compositions, experiments assessing oil displacement efficiency. The primary parameters determined during filtration experiments are presented along with their transfer into full-scale hydrodynamic models. The paper presents an approach for choosing sites for conducting a pilot project using hydrodynamic simulation, forming selection criteria for the most efficient areas for waterflooding/surfactant-polymer flooding. An optimal strategy for implementing surfactant-polymer flooding without prior history of water injection is defined, involving two consecutive phases: implementation of waterflooding at Site № 1 followed by surfactant-polymer flooding at Site № 2. Major risks associated with planning the pilot project are also outlined.

References

1. Petrakov A.M., Rogova T.S., Makarshin S.V. et al., Selection of surfactant-polymer technology for enhanced oil recovery project in carbonate formations of Central-Khoreiver uplift (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2020, no. 1, pp. 66–70, DOI: https://doi.org/10.24887/0028-2448-2020-1-66-70

2. Kruglov D.S., Kornilov A.V., Tkachev I.V. et al., Development of surfactant-polymer flooding technology for carbonate reservoirs with high salinity formation water and high reservoir temperature (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2023, no. 1, pp. 44–48, DOI: https://doi.org/10.24887/0028-2448-2023-1-44-48

3. Yousef A.A., Liu J.S., Blanchard G.W. et al., Smart waterflooding: Industry’s first field test in carbonate reservoirs, SPE-159526-MS, 2012,

DOI: https://doi.org/10.2118/159526-MS

4. Shakeel M., Pourafshary M., Hashmet M.R., Hybrid engineered water-polymer flooding in carbonates: A review of mechanisms and case studies, App. Sci., 2020,

No. 10(6087), DOI: https://doi.org/10.3390/app10176087

5. Yudin E.V., Bagmanov R.D., Khairullin M.M. et al., Development of approach to modelling complex structure carbonate reservoirs using example of the Central Khoreyver uplift fields (In Russ.), SPE-187811-MS, 2017, DOI: https://doi.org/10.2118/187811-MS

6. Hu Guo, Ma Dou, Wang Hanqing, Review of capillary number in chemical enhanced oil recovery, SPE-175172-MS, 2015, DOI: https://doi.org/10.2118/175172-MS

7. Jabri R., Mjeni R., Gharbi M., Alkindi A., Optimizing field scale polymer development in strong aquifer fields in the south of the Sultanate of Oman, SPE-195055-MS, DOI: https://doi.org/10.2118/195055-MS

The paper presents systematic analysis of tracer study research method. The authors keep track of the progress of tracer monitoring from a tool for solution of local diagnostic problems to key element of comprehensive systems for production monitoring and management, integrated into the concept of digital field twins. The paper covers the main field applications of tracer technology, including evaluation of reservoir connectivity, optimization of waterflood systems, surveillance of enhanced oil recovery projects, and inflow profile monitoring. The relationship between reservoir facies heterogeneity and fluid (oil and water) flow pattern is examined in detail. Using the example of Bobrikovian formation of Sabanchinskoye field, confinement of formation damage zones to facies boundaries and spatial distribution of fracturing in terrigenous sediments are explained. It was proven that adequate description of reservoir fluid dynamics necessitates combination of lithological and facies models, rather than application of a lithological model alone. The conducted analysis provided the basis for the hypothesis describing fundamental principles for improvement of sweep and displacement efficiencies considering optimization of field development system, i.e. relative location of injection and production wells within each facies (geological body). The study also gives evidence of the processes of local fines migration and formation damage, which must be considered during field development. Tracer study became a critically important source of data for calibration of reservoir simulation models and support of real-time decision making within intelligent field concept. The research laid the foundations for application of facies-driven approach to interpretation of tracer data.

References

1. Tronov V.P., Fil′tratsionnyye protsessy i razrabotka neftyanykh mestorozhdeniy (Filtration processes and development of oil fields), Kazan: Fen Publ., 2004, 582 p.

2. Antonov G.P., Shalin P.A., Khisamov R.S., et al., Specification of geological structure of D1 formation at Abdrahmanovskaya area on the basis of indicative surveys results (In Russ.), Neftyanoye khozyaystvo = Oil Industry, 2002, No. 1, pp. 31-33.

3. Sokolovskiy E.V., Solov’ev G.B., Trenchikov Yu.I., Indikatornye metody izucheniya neftegazonosnykh plastov (Indicator methods for the study of oil and gas reservoirs), Moscow: Nedra Publ., 1986, 157 p.

4. Kuz′min YU.A., Khozyainov M.S., Study of the filtration characteristics of injected water in the Jurassic deposits of Siberia using a tritium indicator (In Russ.), Neftyanoye khozyaystvo = Oil Industry, 1985, No. 6, pp. 36-40.

5. Muradyan A.V., Khozyainov M.S., Interpretation of indicator method data for assessing the filtration parameters of an oil reservoir (In Russ.), Geologiya nefti i gaza, 1987, No. 9, pp. 54-57.

6. Tronov V.P., Tronov A.V., Ochistka vod razlichnykh tipov dlya ispol’zovaniya v sisteme PPD (Purification of various types of water for use in the reservoir pressure maintenance system), Kazan: Fen Publ., 2001, 560 p.

7. Dekhtyarev V.A., On necessity of studying facies variability in mature oil fields (In Russ.), Neftyanaya provintsiya, 2025, No. 2, pp. 1–20,

DOI: https://doi.org/10.25689/NP.2025.2.1-20

8. Abdulmazitov R.G., Sattarov R.Z., Latifullin F.M., Uchet izmeneniya kollektorskikh svoystv plasta pri dlitel′noy razrabotke neftyanogo ob′′yekta (Taking into account changes in reservoir properties during long-term development of an oil field), Collected papers “Aktual’nye problemy geologii i razrabotki neftyanykh mestorozhdeniy Tatarstana” (Actual problems of geology and development of Tatarstan oil fields), Moscow: Zakon i poryadok Publ., 2006, pp. 167–173.

The paper investigates the temperature dependence of filtration processes of viscoplastic oil in porous media. The relevance of this study is associated with the increasing amount of hard-to-recover hydrocarbon reserves, which are often represented by highly viscous and non-Newtonian oils, for which the classical Darcy law cannot be directly applied. A mathematical filtration model is proposed in which oil viscosity depends on the pressure gradient, enabling the consideration of a threshold shear gradient and the structural breakdown behaviour of viscoplastic oil. A radially symmetric filtration problem is analyzed, taking into account variations in density, filtration velocity, and temperature during fluid flow in the reservoir. Numerical simulations are performed to evaluate the temporal and spatial temperature distributions for both viscoplastic and Newtonian oils. Particular attention is paid to the influence of adiabatic effects and the Joule–Thomson effect on temperature evolution in the near-wellbore zone and at greater distances from the well. The results show that the temperature behaviour of viscoplastic oil significantly differs from that of conventional oil and strongly depends on filtration time and rheological properties. The obtained results demonstrate the advantages of the proposed modelling approach for a more accurate description of filtration and thermal processes in reservoirs containing viscoplastic oils. The study has practical significance for reservoir engineering and may contribute to improving the efficiency of well operation and production performance.

References

1. Vylomov D.D., Shtin N.A., Optimization of the search for zones of residual reserves with considering the non-newtonian properties of oil in the process of hydrodynamic modeling (In Russ.), Ekspozitsiya Neft′ Gaz, 2021, no. 2, pp. 57–60, URL: https://doi.org/10.24412/2076-6785-2021-2-57-60

2. Maksimov V.M., Dmitriyev N.M., Mikhaylov N.N. et al., Innovatory technologics of the effective development of hydrocarbon fields with hard-extractive reserves on the base of new physico-mathematical models and adequate simulation (In Russ.), Georesursy, geoenergetika, geopolitika, 2012, no. 2.

3. Grachev S.I., Korotenko V.A., Kushakova N.P. et al., Liquid filtration in anomalous collectors (In Russ.), Izvestiya TPU, 2019, no. 7, pp. 104–113,

DOI: https://doi.org/10.18799/24131830/2019/7/2183

4. Akhmedov S.A., Akhmedova Z.KH., Mathematical modeling of the problems of displacement of the paraffin oil with water, taking into account the water injection technology (In Russ.), Vestnik Dagestanskogo gosudarstvennogo universiteta. Seriya 1: Yestestvennyye nauki, 2019, V. 34, no. 1, pp. 32-39,

DOI: https://doi.org/10.21779/2542-0321-2019-34-1-32-39

5. Mustafayev S.D., Gasymova S.A.-G., Influence of viscoplastic oil properties on well performance in the presence of a sand plug at the bottomhole (In Russ.), Neftyanoye khozyaystvo = Oil Industry, 2019, no. 2, pp. 58–60, DOI: https://doi.org/10.24887/0028-2448-2019-2-58-60

The paper presents the results of pilot testing of an innovative modular downhole measuring system ALGA-GIK-28 for wells equipped with sucker rod pumps and production packers. This system was developed to reduce high maintenance costs for conventional permanent monitoring systems which require a workover crew to pull the pumping equipment out of hole for replacement, resulting in significant operational expenses and production losses. The key innovation of the system lies in its modular design, comprising a permanent downhole crossover installed on the tubing string and a retrievable measuring module equipped with pressure and temperature sensors. The module can be quickly run in hole and pulled out using a standard wireline through the annulus without the need for well shut-down or a workover crew. The paper provides details on mechanics of the module setting, locking, and tight connection within the crossover. The results of tests at TATNEFT PJSC field confirmed functional reliability of the system in-situ. These tests demonstrated efficient operation of the valve system, tightness of connection, and reliability of below-packer and annulus casing pressures measurement under well dynamic behavior. It was found that this technology reduces the measuring system replacement time by 24 hours compared to conventional methods. The implementation of the presented system is a technological shift in the field of real-time monitoring of production process parameters, paving the way for the development of more flexible, cost-effective, and efficient monitoring systems. This contributes to optimizing well inventory management and reducing operational expenses.

The article presents a comparative analysis of the results of gas chromatography studies of the component composition of Devonian oil and asphaltene–resin–paraffin deposits (ARPD). The component composition of normal and iso-alkanes in the range from C10 to C40 was performed using a Shimadzu GC 2010 Plus chromatograph. It was established that ARPD are predominantly composed of high-molecular-weight n-alkanes C26–C40, which concentration is 5–6 times higher than their content in oil. To quantify the selectivity of hydrocarbon transfer into the solid phase, the solid-phase transition index (SPTI) was introduced, calculated as the ratio of a component's concentration in ARPD to its concentration in oil. Analysis of SPTI values showed that the critical accumulation threshold is typical for alkanes C27 and above, with maxima for ceresins C37–C39. The higher heterogeneity of ARPD composition compared to oil composition confirms the significant influence of individual geological and technical well conditions on the deposit formation process. Correlations between the component composition of ARPD, the melting point of deposits, and their structural-mechanical properties were established. The results reveal the potential of using chromatographic oil studies to predict the composition and properties of ARPD and to develop a methodology for the targeted selection of technologies and chemical reagents for their removal.

References

1. Gus’kova I.A., Khayarova D.R., ASPO. Upravlenie oslozhnenyami na pozdney stadii razrabotki (Asphalt, resin and paraffin deposits. Management of complications in late-stage development), Al’met’evsk: Publ. of Almetyevsk State Oil Institute, 2023, 200 s.

2. Ibragimov N.G., Tronov V.P., Gus’kova I.A., Teoriya i praktika metodov bor’by s organicheskimi otlozheniyami na pozdney stadii razrabotki neftyanykh mestorozhdeniy (Theory and practice of methods of struggle with organic varnish in the late stage of development of oil fields), Moscow: Neftyanoe khozyaystvo Publ., 2010, 238 p.

3. Rogachev M.K., Khaybullina K.Sh., Development of the chemical composition for removal of asphaltene-resin-paraffin deposits in oil wells (In Russ.), Mezhdunarodnyy nauchno-issledovatel’skiy zhurnal, 2016,

No. 2–2(44), pp, DOI: https://doi.org/10.18454/IRJ.2016.44.117

4. Rogachev M.K., Fiziko-khimicheskie metody sovershenstvovaniya protsessov dobychi nefti v oslozhnennykh usloviyakh (Physicochemical methods of improving oil production processes in difficult conditions): thesis of doctor of technical science, Ufa, 2002.

5. Ivanova L.V., Burov E.A., Koshelev V.N., Asphaltene-resin-paraffin deposits in the processes of oil production, transportation and storage

(In Russ.), Neftegazovoe delo = Oil and Gas Business , 2011, no. 1,

pp. 268–284.

6. Aleksandrov A.N., Rogachev M.K., Determination of temperature of model oil solutions saturation with paraffin (In Russ.), Mezhdunarodnyy nauchno-issledovatel’skiy zhurnal, 2017, No. 6–2(60), pp. 103–108,

DOI: https://doi.org/10.23670/IRJ.2017.60.021

7. Nebogina N.A., Judina N.V., Effect of phase transitions in high-wax crude oil and emulsions on structural-and-rheological properties (In Russ.), Neftekhimiya = Petroleum Chemistry, 2020, V. 60, No. 4, pp. 511–519,

DOI: https://doi.org/10.31857/S0028242120040103

8. Barskaya E.E., Ganeeva Yu.M., Yusupov T.N., D’yanova D.I., Forecasting problems in oil production based on analysis of their chemical composition and physicochemical properties (In Russ.), Vestnik Kazanskogo tekhnologicheskogo universiteta, 2012, V. 15, no. 6,

pp. 166–169.

9. Yusupova T.N., Ganeeva Yu.M., Romanov G.V., Barskaya E.E., Fiziko-khimicheskie protsessy v produktivnykh neftyanykh plastakh (Physical and chemical processes in the productive oil reservoirs), Moscow: Nauka Publ., 2015, 412 p.

10. Tronov V.P., Mekhanizm obrazovaniya smolo-parafinovykh otlozheniy i bor’ba s nimi (Mechanism of formation of resin-paraffin deposits and its control), Moscow: Nedra Publ., 1969, 192 p.

11. Kagan YA.M., O fiziko-khimicheskikh osnovakh preduprezhdeniya obrazovaniya smolo-parafinovykh otlozheniy s pomoshch′yu poley, sozdavayemykh elektricheskim tokom (On the physicochemical principles of preventing the formation of resin-paraffin deposits using fields created by electric current), In: Bor′ba s otlozheniyami parafina (Combating paraffin deposits), Moscow: Nedra Publ., 1965, pp. 170–182.

The article presents the results of long-term research by Irkutsk Oil Company Group to develop a technology for purification of high-sulfur crude oils from hydrogen sulfide and light mercaptans for the conditions of the East Siberian oil and gas province. The weighty share of Irkutsk Oil Company Group reserves is presented by hydrocarbon deposits with sour and high-sulfur crude oil, which also contain significant amounts of harmful sulfur-containing impurities of hydrogen sulfide and methyl and ethyl mercaptans. The content of these impurities is regulated by state and interstate regulations due to their strong corrosive activity. Their neutralization in oil is a pressing issue for the company and the industry. Through a literature review of international technological solutions and own laboratory and field research, an effective two-component composition consisting of an organic absorbent and an alkaline catalyst was identified. The organic absorbent is acrylonitrile. Pure or mixed working solutions of potassium or sodium hydroxide dissolved in water, hydrocarbons or mixed solvents (water and a low-freezing additive) were selected as the alkaline catalyst. The conducted research ensured a pour point corresponding to the climatic zone of the Company's region of operation. Laboratory and field testing revealed that oil treated with this two-component composition meets state and interstate standards for hydrogen sulfide content, as well as the total amount of methyl and ethyl mercaptans.

References

1. Khimiya seraorganicheskikh soyedineniy, soderzhashchikhsya v neftyakh i nefteproduktakh (Chemistry of organosulfur compounds contained in oils and petroleum products), Ufa – Moscow: Gostoptekhizdat Publ., 1958–1968, V. 1–9.

2. Sigeru Oae, Khimiya organicheskikh soyedineniy sery (Chemistry of organic sulfur compounds), Moscow: Khimiya Publ., 1975, 512 p.

3. Voronkov M.G., Vyazankin N.S., Deryagina E.N. et al., Reaktsii sery s organicheskimi soyedineniyami (Reactions of sulfur with organic compounds), Novosibirsk: Nauka Publ., 1979, 367 p.

4. Mazgarov A.M., Sernistyye soyedineniya uglevodorodnogo syr′ya (Sulfur compounds of hydrocarbon raw materials), Kazan′: Publ. of Kazan University, 2015, 36 p.

5. Salikhov R.M., Parashchenko M.K., Chertovskikh E.O. et al., Primary treatment of hydrocarbons at the sites of Irkutsk Oil Company using mobile and block-modular technologies (In Russ.), Neftyanoye khozyaystvo = Oil Industry, 2020, No. 9, pp. 68–71, DOI: https://doi.org/10.24887/0028-2448-2020-9-68-71

6. Arensdorf J., Horaska D., Treatment of mercaptans in Canadian condensate, SPE-141217-MS, 2011, DOI: https://doi.org/10.2118/141217-MS

7. Gershbein L.L., Hurd C.D., The reaction of hydrogen sulfide with acrylonitrile, acrylic ester and crotonaldehyde, Journal of the American Chemical Society, 1947, V. 69.2, pp. 241–242.

8. Adams R., Organic reactions, J. Wiley & Sons, Chapman & Hall, 1960, pp. 80-135.

9. Patent US11078403B2. Synergistic sulfide scavenging additives for use in oilfield operations, Inventors: Liu Shi, Funian Zhao, Liangwei Qu, Corrin E.

10. Reaktsii i metody issledovaniya organicheskikh soyedineniy (Reactions and methods of studying organic compounds), Part 2, Moscow – Leningrad: GNTIKHL Publ., 1952, 320 p.

11. Kashchavtsev V.E., Dytyuk L.T., Zlobin A.S., Kleymenov V.F., Bor′ba s otlozheniyem gipsa v protsesse razrabotki i ekspluatatsii neftyanykh mestorozhdeniy (Control of gypsum deposition during oil field development and operation), Moscow: Publ. of VNIIOENG, 1976, 63 p.

12. Kashchavtsev V.E., Mishchenko I.T., Soleobrazovanie pri dobyche nefti (Salt formation in oil production), Moscow: Orbita-M Publ., 2004, 432 p.

13. Chertovskikh E.O., Kunayev R.U., Kachin V.A., Karpikov A.V., Gypsum deposits under oil and gas production at Verkhnechonskoe oil/gas condensate field (In Russ.), Vestnik IrGTU, 2013, No. 12(83), pp. 143–148.

14. Salikhov R.M., Kostyuk I.I., Development and implementation of measures focused on increasing the time between repairs for the artificial lift equipment in Irkutsk Oil Company (In Russ.), Neftyanoye khozyaystvo = Oil Industry, 2020, No. 9, pp. 55–58, DOI: https://doi.org/10.24887/0028-2448-2020-9-55-58

15. Salikhov R.M., Chertovskikh E.O., Gil′mutdinov B.R. et al., Special aspects of chemical reagents use under high mineralization of produced waters (In Russ.), Neftyanoye khozyaystvo = Oil Industry, 2020, No. 9, pp. 59–62, DOI: https://doi.org/10.24887/0028-2448-2020-9-59-62

16. Folomeyev A.E., Salikhov R.M., Chertovskikh E.O., Opyt bor′by s gipsoobrazovaniyem v usloviyakh anomal′no vysokoy kontsentratsii soleobrazuyushchikh ionov – Prakticheskiye aspekty neftepromyslovoy khimii (Experience in combating gypsum formation under conditions of abnormally high concentrations of salt-forming ions – Practical aspects of oilfield chemistry), Proceedings of scientific and practical conference, Ufa: Publ. of BashNIPIneft′, 2023, pp. 188–190.

17. Salikhov R.M., Chertovskikh E.O., Gil′mutdinov B.R. et al., Experience in combating gypsum deposits under conditions of abnormally high concentration of salt-forming ions at Yaraktinskoye oil field (In Russ.), Neftyanoye khozyaystvo = Oil Industry, 2023, No. 9, pp. 128–132, DOI: https://doi.org/10.24887/0028-2448-2023-9-128-132

18. Patent RU2832622C1. Method of removing sulphur-containing compounds from oil and gas condensate, Inventors: Gubanov M.A., Svistunov A.S., Shabayeva E.V., Troynikov A.D., Tsekov O.O.

The use of aphron-based fluids during drilling and killing well operation in low reservoir pressure conditions reduces the negative impact on reservoir porosity and permeability compared to standard process fluids. Temporary formation isolation in this case is achieved by microbubbles in the process fluid, which enter the pore space during repression operations and, by expanding, create a barrier that prevents subsequent penetration of bridging agents into the near-wellbore zone. A study on the influence of the concentration of the main components of aphron-based fluids  biopolymer (xanthan gum) and surfactant  on the physical properties of aphron-based systems is presented. Two series of experiments were conducted: one with an anionic surfactant (sodium dodecyl sulfate) and one with a zwitterionic surfactant (cocamidopropyl betaine). Density, viscosity, shear pressure and dispersion were measured for each of the prepared compositions. The aging process of the aphron-containing compositions was also studied. The study results reflect the recommended biopolymer and surfactant concentrations for the preparation of process fluids for temporary formation isolation. The study revealed that the optimal xanthan gum concentration is 0,5 %. This polymer content ensures the stability of the aphron-based fluid for more than 24 hours. The threshold surfactant content at which the required process parameters of the aphron-based fluid are achieved is 0,025 %. A further increase in the concentration of surfactants leads to a significant decrease in density, an increase in foam multiplicity and an increase in the viscosity of the composition.

References

1. Yamov G.A., Ibragimova D.R., Milovanova V.V., Applicability of technology for killing gas and gas-condensate wells with foam compositions in Rosneft fields (In Russ.), Territorija NEFTEGAZ, 2021, No. 9, 10, pp. 58–66.

2. Patent no. 2330942 RF, Method of killing wells with abnormal low formation pressure, Inventors: Magadova L.A., Magadov R.S., Silin M.A., Gaevoy E.G., Efimov N.N., Nazyrov R.R., Larchenko Yu.A., Gur’yanov O.V.

3. Tikhomirov V.K., Peny. Teoriya i praktika ikh poluchenija i razrusheniya (Foams. Theory and practice of their production and destruction), Moscow: Khimiya Publ., 1983, 264 p.

4. Andaeva E.A., Sidorov L.S., Sidorov Ju.L., Jamen effect as a factor of wells productivity increase (In Russ.), Stroitel’stvo neftjanykh i gazovykh skvazhin na sushe i na more, 2013, no. 5, pp. 26–30.

5. Amiyan V.A. et al., Primenenie pennykh sistem v neftegazodobyche (Application of foam systems in oil and gas production), Moscow: Nedra Publ., 1987, 229 p.

6. Sebba F., Foams and biliquid foams. Aphrons, New York: Wiley, 1987, 236 p.

7. Brookey T., Micro-bubbles: New Aphron drill-in fluid technique reduces formation damage in horizontal wells, SPE-39589-MS, 1998,

DOI: https://doi.org/10.2118/39589-MS

8. Perepelkin K.E., Matveev V.S., Gazovye emul’sii (Gas emulsions), Leningrad: Khimiya Publ., 1979, 200 .

9. Alizadeh A., Khamehchi E., Experimental investigation of the oil based Aphron drilling fluid for determining the most stable fluid formulation, Journal of Petroleum Science and Engineering, 2019, V. 174, pp. 525–532, DOI: https://doi.org/10.1016/j.petrol.2018.11.065

10. Bjorndalen N., Kuru E., Physico-chemical characterization of Aphron-based drilling fluids, Journal of Canadian Petroleum Technology, 2008, V. 47, No. 1,

DOI: https://doi.org/10.2118/2005-050

11. Growcock F., Enhanced wellbore stabilization and reservoir productivity with Aphron drilling fluid technology, Houston, Texas: MASI Technologies, 2005, 171 p.,

DOI: https://doi.org/10.2172/896513

12. Mehrjoo H., Kazemzadeh Y., Ismail I. et al., A comprehensive review of colloidal gas Aphrons applications in the oil industry, Journal of Petroleum Exploration and Production Technology, 2025, No. 15, DOI: https://doi.org/10.1007/s13202-025-01944-6

13. Arabloo M., Shahri M.P., Experimental studies on stability and viscoplastic modeling of colloidal gas aphron (CGA) based drilling fluids, Journal of Petroleum Science and Engineering, 2014, V. 113, pp. 8–22, DOI: https://doi.org/10.1016/j.petrol.2013.12.002

14. Pasdar M., Kazemzadeh E., Kamari E., Insight into selection of appropriate formulation for colloidal gas Aphron (CGA)-based drilling fluids, Petroleum Science, 2020, No. 17, pp. 759–767, DOI: https://doi.org/10.1007/s12182-020-00435-z

15. Ramirez F., Greaves R., Montilva J., Experience using Microbubbles-Aphron drilling fluid in mature reservoirs of Lake Maracaibo, SPE-73710-MS, 2002,

DOI: https://doi.org/10.2118/73710-MS

16. Rjazanov A.A., Sklyuev P.V., BabitskayaK.I., Bulgakov S.A., Application of viscoelastic systems in oil production intensification processes (In Russ.), Neftegazovoe delo, 2024, V. 22, No. 1, pp. 99–111, DOI: https://doi.org/10.17122/ngdelo-2024-1-99-111

17. Babitskaya K.I., Konovalov V.V., Study on impact of the size of compound micelles comprised of anionic and nonionic surfactants on efficiency of residual oil displacement after flooding, ARPN Journal of Engineering and Applied Sciences, 2016, V. 11, No. 16, pp. 9622–9626.

18. Nikitin V.I., Agrelkina M.M., Justification for the selection of a relative permeability model in the task of predicting drilling fluid filtrate invasion into the formation, International Journal of Engineering, 2025, No. 38(10), pp. 2312–2320, DOI: https://doi.org/10.5829/ije.2025.38.10a.08

The paper discusses the results of federal project implementation on the creation of advanced engineering schools, using the example of Almetyevsk State Technological University «Petroleum Higher School», which cooperates with TATNEFT PJSC. The model of a harmonious triad industry – science – education was adopted as the conceptual basis, going back to the ideas of M.A. Lavrentyev and the experience of Bauman Moscow State Technical University. Transferring this approach to the framework of an oil and gas university enables to create a working prototype of a new system of engineering education. On the industrial track, comprehensive regional projects on integrated modeling are implemented, including development analysis, construction of geological–hydrodynamic and surface network models, and the formation of integrated models of fields and gathering systems. Examples are given of improving the accuracy of hydrodynamic models by accounting for low-amplitude faulting, using seismic–facies modeling, developing an in-well gas-lift technology for multilayer reservoirs. The scientific engineering track is presented by the development of a software product based on an integral SAGD model and by studies of waterflooding in fractured–porous reservoirs using a discrete fracture model with allowance for geomechanical effects. The educational track is implemented through a practice oriented master’s program in integrated reservoir modeling, built around the work of multidisciplinary student teams on real industrial projects. The combination of industrial, scientific and educational projects, enhanced by the development of proprietary software products, forms a basis for transforming engineering education and strengthens the technological sovereignty of the oil and gas industry.

References

1. Barbashina N.S., Tihomirov G.V., Shevchenko V.I., Best practices of advanced engineering schools (In Russ.), Professorskiy zhurnal «Tehnicheskie nauki», 2023,

No. 1(6), pp. 4–21, DOI: https://doi.org/10.18572/2686-8598-2023-6-1-4-21

2. Lavrent′yev M.A., Triedinstvo: nauka – kadry – proizvodstvo: otvety na voprosy Z. Ibragimovoy, korrespondenta zhurnala “Ekonomika i organizatsiya promyshlennogo proizvodstva” (The Trinity: Science - Personnel - Production: Answers to questions from Z. Ibragimova, correspondent for the journal "Economics and Organization of Industrial Production"), In: Rossiyskaya akademiya nauk. Sibirskoye otdelenie: Strategiya liderov (Russian Academy of Sciences. Siberian Branch: Leadership Strategy), Novosibirsk: Nauka, 2007, pp. 118–121, URL: https://prometeus.nsc.ru/elibrary/2007str/118-121.ssi

3. Rudskoj A.I., Borovkov A.I., Romanov P.I., Russian experience in engineering education development (In Russ.), Vysshee obrazovanie v Rossii, 2018, No. 1, pp. 151–162.

4. Certificate of state registration of the computer program No. 2025619232. Programma dlya rascheta optimal’nykh tekhnologicheskikh parametrov parogravitathionnogo drenazha (Program for calculating the optimal technological parameters of steam-gravity drainage), Authors: Pichugin O.N., Gil’manov A.Ja., Fedorov K.M., Shevelev A.P.

5. Pichugin O.N., Viktorov Je.P., Kolevatov A.A., Hromova I.Ju., Povyshenie tochnosti gidrodinamicheskoy modeli pri vklyuchenii maloamplitudnykh razryvnykh narushenij, vydelennykh po vysokorazreshennym seysmicheskim dannym (Improving the accuracy of the hydrodynamic model when including low-amplitude faults identified from high-resolution seismic data), Proceedings of Russian Industry Energy Conference: ROEK 2025, 21–23 October 2025, Moscow, 2025.

6. Legostaev D.Y., Rodionov S.P., Pichugin O.N., Il’in A.S., Issledovanie osobennostej razrabotki treshhinno-porovykh kollektorov s primeneniem zavodneniya na osnove modeli diskretnykh treshin i uchetom geomekhanicheskikh effektov (Study of the development features of fractured-pore reservoirs using waterflooding based on a model of discrete fractures and taking into account geomechanical effects), Proceedings of international conference ″Trudnoizvlekaemye zapasy nefti″ (Hard-to-recover oil reserves), Al’met’evsk, 2024, pp. 259–260.

7. Pichugin O.N., Digital transformation: from modeling to field management (In Russ,), Neft’. Gaz. Novacii, 2024, no. 4, pp. 23–25.

8. Aliev T.I., Osnovy proektirovaniya sistem (System design fundamentals), Publ. of ITMO University, 2015, 120 p.

9.Mirzadzhanzade A.Kh., Khasanov M.M., Bakhtizin R.N., Modelirovanie protsessov neftegazodobychi. Nelineynost’, neravnovesnost’, neopredelennost’ (Modelling of oil and gas production processes. Nonlinearity, disequilibrium, uncertainty), Moscow-Izhevsk: Publ. of Institute of Computer Science, 2004, 307 p.

The paper presents the results of research conducted at the Pipeline Transport Institute LLC regarding digitalization of quality management processes for the equipment used at the main pipeline transport facilities of oil and oil products. A technique is proposed to combine algorithms for generating ontological models of pipeline facilities, smart (SMART) technologies for structuring text documents, which enables fundamental transformation of existing methods of work with regulatory requirements for equipment at all stages of its lifecycle. Specific features of industry requirements for equipment, both in the existing (traditional) human-readable format and in the proposed machine-readable and machine-interpretable SMART form, are considered, and plans for further digital transformation of equipment quality management processes are outlined. The relevance of this article correlates with the recommendations and plans of the Federal Agency for Technical Regulation and Metrology of the Russian Federation to increase the share of developed standardization documents in machine-readable format to 80 %, reduce the average time to develop regulatory documents to 7 months, promote machine-readable requirements at the federal level. Generating text documents from ontological models using document templates minimizes routine operations, which enables to reallocate resources to more important tasks and reduce the number of human errors. The transition to working with requirements in a digital format shall enable design institutes, construction and supervisory organizations, certification bodies, and testing laboratories (centers) operating in the field of pipeline transport of oil and oil products to reduce the costs of creation, adjustment and expert analysis of all types of regulatory requirements.

References

1. V’yunov S.I., Aralov O.V., Tuzov V.Yu., Investigation of the possibility to create a SMART standard of the GS type of Transneft PJSC and subsequent SMART certification of equipment (In Russ.), Nauka i tehnologii truboprovodnogo transporta nefti i nefteproduktov = Science & Technologies: Oil and Oil Products Pipeline Transportation, 2024, V. 14, No. 5, pp. 470–480, DOI: https://doi.org/10.28999/2541-9595-2024-14-5-470-480

2. V’yunov S.I., Buyanov I.V., Kontseptsiya tsifrovogo razvitiya sistemy upravleniya kachestvom produktsii v truboprovodnom transporte nefti i nefteproduktov (The concept of digital development of the quality management system for products in pipeline transportation of oil and oil products), Proceedings of XIX International scientific and practical conference “Truboprovodnyy transport – 2024” (Pipeline Transport – 2024), Ufa, 20–22 November 2024, V. 1, pp. 225–227.

3. Shishenkov M.A., Chuzhinov E.S., Ontological description of automated process control systems (In Russ.), Avtomatizatsiya i informatizatsiya TEK, 2025, No. 1(618), pp. 15–24.

4. Dmitrieva S.Yu., Basic principles for SMART standards development (In Russ.), Standarty i kachestvo, 2021, no. 12(1014), pp. 22–25.

5. Artemova V.R., Dmitrieva S.Yu., Techexpert SMART: Creating documents in smart format (In Russ.), Standarty i kachestvo, 2023, No. 3(1029), pp. 48–53.

6. AO “Kodeks”: Promyshlennost’ nuzhdaetsya v umnykh standartakh (“Kodeks” JSC: Industry needs smart standards), 2021,

URL: https://kodeks.ru/news/read/promyshlennost-nujdaetsya-v-umnyh-standartah

7. Shishenkov M.A., Primeneniye ontologiy dlya avtomatizatsii obrabotki informatsionnykh resursov ob′′yektov transporta nefti (Application of ontologies to automate the processing of information resources of oil transport facilities), Collected papers “Aktual′nyye problemy nefti i gaza” (Current issues in oil and gas), Proceedings of VII All-Russian Youth Scientific Conference, Moscow, 16–18 October 2024, Moscow: Publ. of Oil and Gas Research Institute RAS, 2024, pp. 394–396.

8. Sysoeva E.A., Rozhkova T.A., Digital technologies in the products conformity assessment (In Russ.), Kompetentnost’, 2019, No. 8, pp. 20–25.

9. Unguryan E., SMART standards (In Russ.), Standarty i kachestvo, 2021, No. 12, pp. 26-28.

10. olmykov E.A., Vorontsova Yu.V., Vorontsova A.N., How to go to smart (machine-readable) standards (In Russ.), Izvestiya VolgGTU, 2022, No. 1(260), pp. 17–20, DOI: https://doi.org/10.35211/1990-5297-2022-1-260-17-20

11. Loibl A., Manoaran T., Nagarajan A., Procedure for the transfer of standards into machine-actionability, Journal of Advanced Mechanical Design, Systems, and Manufacturing, 2020, V. 14, No. 2, DOI: https://doi.org/10.1299/jamdsm.2020jamdsm0022

12. Ehring D., Luttmer I., Pluhnau R., Nagarajah A., SMART standards - concept for the automated transfer of standard contents into a machine-actionable form, Proceedings of 31st CIRP Design Conference 2021 (CIRP Design 2021), Published by Elsevier Ltd., 2021, DOI: https://doi.org/10.1016/j.procir.2021.05.025

13. PNST 864-2023. Umnyye (SMART) standarty. Obshchiye polozheniya (PNST 864-2023 Smart (SMART) standards. General provisions),

URL: https://protect.gost.ru/document.aspx?control=7&id=255709

The work is devoted to the problem of assessing changes in the stress-strain state of a tank during the development of irregular settlement of the bottom panel in the vicinity of the wall. The reasons for the development of irregular settlements in the soil foundations of vertical steel tanks (VST) and the possible consequences of operating structures in such conditions are presented. The article substantiates the relevance of studying the tank stress-strain state when the settlement area is located in the zone of action of the edge effect from the wall using a numerical method. The main characteristics of the finite-element model of the tank VST-20000, used in the calculations, and the values of all parameters necessary for the calculations are presented. More than 100 calculations were carried out, based on the results of which diagrams of the distribution of maximum equivalent stresses in metal structures of VST were obtained at various thicknesses of the bottom panel, radii and locations of the settlement zone relative to the wall. Based on the results obtained, the dependences of the maximum equivalent stresses in the tank wall on the given radii and locations of the settlement zone relative to the VST wall were developed for the case of maximum permissible settlement. Analytical dependencies were also established that enable to determine the boundaries of the edge effect zone and the maximum permissible value of settlement within this zone.

References

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