The article presents the results of studies of Paleozoic deposits in the northeastern part of Western Siberia. Based on new drilling data obtained from Vostochno-Suzunskaya well the structure of the pre-Jurassic basement within the study area was analyzed. A description of the lithological composition of the rocks from bottom core samples of the Vostochno-Suzunskaya well is provided. On the basis of extended well-logging data, a geological and geophysical interpretation was carried out for the Vostochno-Suzunskaya and Medvezhya-316 wells. The results were correlated with the stratotype (Tochinskaya-11 well) in accordance with the structural-facial zoning scheme of Paleozoic depostits of Western Siberia and with seismic data across the entire area of study. Based on core description and well-logging data carbonate deposits of various composition typical of sedimentary platform covers were identified within the study area which are represented by dolomites with individual interbeds of limestones and argillaceous dolomites. Higher up the section variously carbonatized argillaceous rocks occur, presumably shales. The Paleozoic sedimentary deposits are unconformably overlain by Lower or Middle Jurassic sediments. In order to improve the reliability of the results biostratigraphic determinations are planned. Drilling of wells penetrating the Paleozoic sedimentary cover in this area and the study of prospective carbonate deposits may enhance accuracy of the distribution of pre-Jurassic reservoirs forecast within the study area, and opens up new prospects for hydrocarbon exploration in the region.

References

1. Vazhenina O.A., Trigub A.V., Ogibenin V.V. et al., Studies of West Siberia petroleum province margins: integrated geological exploration (In Russ.), Geologiya nefti i gaza, 2025, No. 3, pp. 31–49, DOI: https://doi.org/10.47148/0016-7894-2025-3-31-49

2. Krinin V.A., Western boundary of Siberian platform and petroleum potential of its margin (In Russ.), Geologiya nefti i gaza, 2024, No. 5, pp. 67–88,

DOI: https://doi.org/10.47148/0016-7894-2024-5-67-88

3. Saks V.N., Ronkina Z.Z., Yurskie i melovye otlozheniya Ust’-Eniseyskoy vpadiny (Jurassic and Cretaceous deposits of the Ust-Yenisei depression), Proceedings of Institute of Arctic Geology, 1957, V. 90, Leningrad: Gosgeoltekhizdat Publ., 1957, 232 p.

4. Miroshnikov L.D., On the geology of the pre-Jurassic basement in the northeastern part of the West Siberian Lowland (In Russ.), Geologiya i geofizika, 1960, No. 4, pp. 33–42.

5. Elkin E.A. et al., Stratigraphic scheme of the Cambrian deposits in the Yenisei region (West Siberia) (In Russ.), Geologiya i geofizika, 2001, V. 42, No. 7, pp. 1015–1027.

6. Stratigrafiya neftegazonosnykh basseynov Sibiri. Paleozoy Zapadnoy Sibiri (Stratigraphy of Siberian oil and gas basins. Paleozoic of Western Siberia): edited by Elkin E.A., Krasnov V.I., Novosibirsk: Publ. of the Siberian Branch of the Russian Academy of Sciences, GEO, 2001, 166 p.

7. Bochkarev V.S., Brekhuntsov A.M., Deshchenya N.P., The Paleozoic and Triassic evolution of West Siberia (data of comprehensive studies) (In Russ.), Geologiya i geofizika, 2003, V. 44, No. 1–2, pp. 120–143.

8. Elkin E.A. et al., Paleozoic facies megazones in the basement of the West Siberian geosyncline (In Russ.), Geologiya i geofizika, 2007, V. 48, No. 6, pp. 633–650.

9. Sennikov N.V. et al., The regional stratigraphic chart for the Ordovician of the West Siberian Lowland (In Russ.), Geologiya i mineral’no-syr’evye resursy Sibiri, 2023, No. 3, pp. 3–39, DOI: https://doi.org/10.20403/2078-0575-2023-3-3-39

10. Bochkarev V.S., Chuvashev B.I., Uralids and Neomobilizim (In Russ.), Gornye vedomosti, 2014, No. 11, pp. 6–25.

11. Sobornov K.O., Geodynamics of the north of the West Siberian basin in the Phanerozoic: a new interpretation and oil and gas potential (In Russ.), Geologiya nefti i gaza, 2025, No. 5, pp. 17–35, DOI: https://doi.org/10.47148/0016-7894-2025-5-17-35

The study aims to identify additional criteria for petroleum potential on well-explored areas. The research focuses on the northern part of the Bashkir arch situated within the territory of the Perm region. Its primary goal is to develop probabilistic-statistical models for assessing the degree of transformation of organic matter and to forecast the distribution of epigenetic bitumoids in the Upper Devonian–Tournasian section. This was solved using the statistical analysis methods and the construction of probabilistic models based on the study of bituminological properties of dispersed organic matter (DOM) in rocks. Linear regression analyses led to the development of individual and integrated predictive probabilistic models which indicates that the most reliable models correspond to specific tectonic regions and stratigraphic formations. Further research was aimed at understanding how the DOM of the Upper Devonian–Tournasian sedimentary formation affect the probabilistic Pepi criterion, which is responsible for the presence of mobile epibitumoids. An examination of the derived multivariable regression equations revealed that the critical parameters influencing the Pepi prediction criterion are primarily determined by the magnitude of the bitumen coefficient and the non-soluble residue component. Applying linear discriminant analysis yielded robust, high-accuracy multidimensional models capable of discriminating epigenetic-type bitumoids prone to form hydrocarbon accumulations. The final schematic representation of the composite probabilistic Pepi criterion across the Bashkir arch highlights the spatial distribution of mobile epibitumoids within the Upper Devonian–Tournasian lithologic sequence, which is an additional zonal criterion of oil and gas potential for the Bashkir arch of the Perm region.

References

1. Voevodkin V.L., Galkin V.I., Kozlova I.A., Razrabotka veroyatnostno-statisticheskikh modeley summarnogo zonal’nogo prognoza neftegazonosnosti po kharakteristikam rasseyannogo organicheskogo veshchestva porod (na primere territorii Permskogo kraya) (Development of probabilistic-statistical models for the total zonal forecast of oil and gas potential based on the characteristics of dispersed organic matter in rocks (using the Perm Territory as an example)), Moscow: Publ. of Gubkin University, 2024, 252 p.

2. Voevodkin V.L., Antonov D.V., Galkin V.I., Kozlova I.A., Generation of the probabilistic and statistical model for total organic carbon differentiation of rocks in the Perm region (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2023, no. 12, pp. 100-104, DOI: http://doi.org/10.24887/0028-2448-2023-12-100-104

3. Voevodkin V.L., On the issue of dispersed organic matter differentiation in the Upper Devonian-Tournaisian strata at the Perm Krai (In Russ.), Nedropol’zovanie, 2024, V. 24, no. 1, pp. 10-17, DOI: http://doi.org/10.15593/2712-8008/2024.1.2

4. Voevodkin V.L., Chalova P.O., Galkin V.I., Assessment of dispersed organic matter differentiation in the northern part of the Baskhirsky arch (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2024, No. 2, pp. 100–104, DOI: https://doi.org/10.24887/0028-2448-2024-6-8-12

5. Merson M.E., Voevodkin V.L., Galkin V.I., On the issue of constructing geological and mathematical models of the relationship between industrial reserves and resources for the territory of the Perm region (In Russ.), Geologiya, geofizika i razrabotka neftyanykh i gazovykh mestorozhdeniy, 2005, No. 9–10, pp. 15–18.

6. Voevodkin V.L., Galkin V.I., Krivoshchekov S.N., Investigation of the effect of oil-content and research criteria in the Perm region on the hydrocarbon deposits distribution (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2012, No. 6, pp. 30-34.

7. Voevodkin V.L., Rastegaev A.V., Galkin V.I., A study of the relationship between resources and oil reserves within the southeastern barrier reef of the Kama-Kinel trough system (In Russ.), Geologiya, geofizika i razrabotka neftyanykh i gazovykh mestorozhdeniy, 2005, No. 9–10, pp. 9–12.

8. Galkin V.I., Kozlova I.A., Development of probabilistic-statistical regional-zoning models of oil and gas potential prediction based on the data of geochemical studies of the upper Devonian carbonate deposits (In Russ.), Geologiya, geofizika i razrabotka neftyanykh i gazovykh mestorozhdeniy, 2016, no. 6, pp. 40-45.

9. Galkin V.I., Karaseva T.V., Kozlova I.A. et al., Differentiated probabilistic assessment of the generation processes in Domanic sediments of Perm region (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2014, no. 12, pp. 103-105.

10. Voevodkin V.L., Galkin V.I., Galkin S.V., Rastegaev A.V., Determination of promising directions for searching for oil and gas fields in the Perm region using probabilistic and statistical methods (In Russ.), Nauka – proizvodstvu, 2006, no. 1, pp. 1-5.

11. Galkin V.I., Kozlova I.A., Krivoshchekov S.N., Nosov M.A., Solutions to regional problems of forecasting oil bearing according to geological and geochemical analysis of dispersed organic matter of Domanic type rocks (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2015, no. 1, pp. 21-23

12. Voevodkin V.L., Galkin V.I., Kozlova I.A., Krivoshchekov S.N., Kozlov A.S., Hydrocarbons migration volumes within the limits of Solikamsk Depression (Pre-Ural Deflection) and possibilities of its use for the oil and gas content forecast (In Russ.), Geologiya, geofizika i razrabotka neftyanykh i gazovykh mestorozhdeniy, 2010,

no. 12, pp. 6-11.

13. Galkin V.I., Koshkin K.A., Melkishev O.A., Kozlova I.A., Geological and statistical simulation for assessment of zonal oil and gas potential formation processes in the Visimskaya monocline, IOP Conference Series: Earth and Environmental Science, 2021, V. 1021, DOI: https://doi.org/10.1088/1755-1315/1021/1/012061

Within the framework of this study, using the example of a unique oil and gas condensate field located in the Purovsky district of the Yamalo-Nenets autonomous region, the issues of clarifying the complex geological structure of the BU16(1-3) formation, characterized by the presence of an oil fringe, are considered in detail and resolved. A comprehensive multifactorial analysis was carried out, combining the study of core material, the interpretation of geophysical well logging data, the study of up-to-date field information, as well as the use of re-processed seismic data. As a result of the conducted research, the lenticular concept of the formation structure was substantiated and established, which significantly changes the idea of its structure. Special attention is paid to the analysis of seismic cubes of elastic properties and the construction of attribute maps of dynamic parameters. This approach enabled to prove the existence of two isolated deposits instead of the previously assumed single one. The key result of the work done was the revision of the phase state of hydrocarbon reserves: one of the identified deposits was transferred from the oil category to the gas-oil category. This clarification led to a significant increase in gas reserves and justified the need to transfer part of the oil reserves to the category of hard-to-recover ones. The developed and refined geological model enabled to substantiate a new, more rational strategy for reservoir development aimed at significantly increasing its geological and economic efficiency.

References

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3. Nesterov I.I., Bochkarev V.S., Shpil'man V.I., Neftegazonosnye kompleksy i strukturnye etazhi Zapadno-Sibirskoy ravniny (Oil and gas complexes and structural levels of the West Siberian Plain), Collected papers “Tektonika molodykh platform i ikh neftegazonosnost'” (Tectonics of young platforms and their oil and gas potential), Proceedings of conference, Moscow, 1981, pp. 17–19.

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Many hydrocarbon fields in Russia are currently in the late stages of development and are characterized by a low degree of remaining reserves. For effective additional study of deposits, it is necessary to improve various methodological approaches and work techniques. These will enable to refine the structure of geological objects and to identify areas of hydrocarbon fields not yet involved in development. The main method for studying the territory nowadays is seismic surveys. The accuracy of constructing surfaces of various horizons can vary within a fairly wide range, which depends on various factors and can be comparable to the amplitude of the identified structures. One of such factors is the zone of the upper part of the well section (ZUPS). The purpose of this work was to develop methodological approaches for analyzing ZUPS materials, structuring the obtained materials, identifying «pitfalls» while constructing lithological characteristics of this zone, and the possibilities of accounting for them when using time-varying data from historical well stock of the Republic of Bashkortostan. The solution to these issues became possible due to the involvement of materials from 16 license areas planned for seismic exploration, with an in-depth analysis of more than 12000 wells. Based on the work carried out, a technology for studying the ZUPS was obtained and tested for the first time as a preliminary stage in processing the acoustic signal within the framework of seismic exploration during the study of the Cenozoic-Paleozoic sedimentary cover.

References

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3. Metodicheskie rekomendatsii po ispol’zovaniyu dannykh seysmorazvedki dlya podscheta zapasov uglevodorodov v usloviyakh karbonatnykh porod s poristost’yu treshchinno-kavernovogo tipa (Guidelines on the use of seismic data to calculating hydrocarbon reserves in conditions of carbonate rocks with a fracture-cavern porosity): edited by Levyant V.B., Kozlov E.A., Khromova I.Yu. et al., Moscow: Publ. of TsGE, 2010, 250 p.

4. Brodov L.Yu., Kozlov E.A., Mushin I.A., Khat’yanov F.I., Strukturno-formatsionnaya interpretatsiya seysmicheskikh dannykh (Structural and formational interpretation of seismic data), Moscow: Nedra Publ., 1990, 299 p.

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DOI: https://doi.org/10.1190/1.1440465

One of the promising tasks of hydrogen energy is the creation of large-scale hydrogen storage systems. In this regard, the advantages of underground storage of hydrogen, both extracted from the subsoil and artificially produced, are obvious. However, the geological justification for choosing the most optimal sites from among the numerous depleted hydrocarbon deposits requires further justification in relation to various geological and tectonic conditions. Based on the results of the work a system of geological criteria for selecting optimal hydrogen storage facilities was proposed, a scientific and methodological approach was developed, which includes geoinformation analysis and multi-criteria ranking of facilities based on risk analysis, 37 fields within the Volga-Ural oil and gas province were analyzed according to the main criteria, and a risk matrix was compiled to analyze and evaluate depleted hydrocarbon deposits for underground hydrogen storage, the most promising facility for hydrogen storage was selected and the proposals for placing an experimental scientific and technological landfill for hydrogen storage on it was substantiated. Expanding the range of diagnostic criteria characterizing the geological and infrastructural positions of sites could yield even more reliable information.

References

1. Zivar D., Kumar S., Foroozesh J., Underground hydrogen storage: A comprehensive review, International journal of hydrogen energy, 2021, V. 46, No. 45,

pp. 23436–23462, DOI: https://doi.org/10.1016/j.ijhydene.2020.08.138

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12. Vinnikovskiy S.A., Koblova A.Z., Oshchepkov B.K. et al., Fiziko-khimicheckie svoystva neftey, gazov i bitumoidov Permskogo Prikam’ya (Physicochemical properties of oils, gases and bitumens of the Perm Kama region), Perm: Publ. of Kama branch of the All-Union Scientific Research Geological Exploration Oil Institute, Permneft Association, 1974, 603 p.

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16. Dantsova K.I., Ruzanov I.N., Khafizov S.F., Tekhnologii otsenki riskov neftegazovykh proektov (Technologies for risk assessment of oil and gas projects), Moscow: Publ. of Gubkin University, 2025, 56 p.

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18. Miloserdova L.V., Dantsova K.I., Khafizov S.F. et al., Connection of lineaments and nodes of their intersections with the oil and gas content of the Caspian syneclise and its framing (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2021, No. 6, pp. 22-26, DOI: https://doi.org/10.24887/0028-2448-2021-6-22-26

19. Dantsova K.I., Miloserdova L.V., Osipov A.V. et al., Monitoring gas leakage using remote sensing materials (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2022, No. 5, pp. 48-51, DOI: https://doi.org/10.24887/0028-2448-2022-5-48-51

The problem of identifying and studying potential source rocks in the Vendian deposits on the Siberian platform remains relevant. In this article, archival and new data on geochemistry of rocks and organic matter (OM) from the Khatyspyt formation of the Vendian were generalised. The distribution of OM was analysed in unified, entire section of the formation along Khorbusuonka river (tributary of the Olenek river). The levels of rocks anomalously enriched and depleted with OM were established and the conditions of their formation during sedimentogenesis were diagnosed. It is assumed, that the black shales extend to the north-west from the Olenek uplift. The study of the composition and distribution of hydrocarbon-biomarkers showed that oxidation-reduction conditions in the marine basin were changing during sedimentogenesis. The formation of black shales was under weakly reducing conditions without hydrogen sulfide contamination of waters. Carbonate sediments, depleted and weakly enriched with OM accumulated, as a rule, during stratification of the water column and under hydrogen sulfide contamination of waters. The OM catagenesis corresponds to early oil window, OM of the Khatyspyt formation was generating naphtides. The generalisation of information about structure of the sedimentary cover of the northeast of the Siberia shows that commercially productive oil and gas accumulations associated with realisation of the Khatyspyt source rock generative potential can be found in the Neoproterozoic and Palaeozoic deposits of the Sukhana depression and Lena-Anabar trough.

References

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2. Timoshina I.D., Geokhimiya organicheskogo veshchestva nefteproizvodyashchikh porod i neftey verkhnego dokembriya yuga Vostochnoy Sibiri (Geochemistry of organic matter in oil-producing rocks and oils of the Upper Precambrian of southern Eastern Siberia), Novosibirsk: Publ. of SB RAS. Geo, 2005, 166 p.

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4. Kashirtsev V.A., Parfenova T.M., Moiseev S.A. et al., The Sukhana sedimentary basin, Siberian platform: Source rock characterization and direct evidence of oil and gas presence (In Russ.), Geologiya i geofizika = Russian Geology and Geophysics, 2019, V. 60, No. 10, pp. 1472–1487, DOI: https://doi.org/10.15372/GiG2019119

5. Sobolev P.N., Lezhnin D.S., Panarin I.A. et al., Geochemical criteria of petroleum potential of the Riphean-Paleozoic sediments of the Lena-Anabarsky regional trough and adjacent territories (In Russ.), Geologiya, geofizika i razrabotka neftyanykh i gazovykh mestorozhdeniy, 2019, No. 8 (332), pp. 62–74,

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8. Parfenova T.M., Kochnev B.B., Nagovitsin K.E. et al., Geokhimiya organicheskogo veshchestva khatyspytskoy svity (vend, severo-vostok Sibirskoy platformy) (Geochemistry of organic matter of the Khatyspyt Formation (Vendian, northeastern Siberian Platform)), Collected papers “Uspekhi organicheskoy geokhimii” (Advances in organic geochemistry), Proceedings of All-Russian scientific conference, 11–15 October 2010, Novosibirsk: Publ. of IPGG SB RAS, 2010, pp. 265–268.

9. Lezhnin D.S., Afanasenkov A.P., Sobolev P.N., Naydenov L.F., Riphean-Palaeozoic series in the Khatanga-Lena interfluve: Geological structure and petroleum potential (In Russ.), Geologiya nefti i gaza, 2021, No. 4, pp. 7–28, DOI: https://doi.org/10.31087/0016-7894-2021-4-7-28

10. Nagovitsin K.E., Rogov V.I., Marusin V.V. et al., Revised Neoproterozoic and Terreneuvian stratigraphy of the Lena-Anabar Basin and north-western slope of the Olenek Uplift , Siberian Platform, Revised Precambrian Research, 2015, V. 270, pp. 226–245, DOI: https://doi.org/10.1016/j.precamres.2015.09.012

11. Peters K.E., Walters S.C., Moldowan J.M., The biomarker guide, Vol. 1, 2, New York: Cambridge University Press, 2005, 1155 p.

12. Grazhdankin D.V., Rogov V.I., Istoriya razvitiya verkhnevendskogo morya severo-vostoka Sibirskoy platformy (History of the development of the Upper Vendian Sea in the northeast of the Siberian platform), Collected papers “Fundamental’nye problemy izucheniya vulkanogenno-osadochnykh, terrigennykh i karbonatnykh kompleksov” (Fundamental problems of studying volcanogenic-sedimentary, terrigenous and carbonate complexes), Proceedings of All-Russian Lithological Conference dedicated to the memory of A.G. Kossovskaya and I.V. Khvorova, Moscow, 11–12 November 2020, Moscow: GEOS Publ., 2020, pp. 45–49.

13. Kontorovich A.E., Geokhimicheskie metody kolichestvennogo prognoza neftegazonosnosti (Geochemical methods for quantitative forecasting of oil and gas potential), Moscow: Nedra Publ., 1976, 250 p.

14. Kontorovich V.A., Kontorovich A.E., Moiseev S.A., Solov’ev M.V., Model of forming Neocomian clinoform complex of West-Siberian oil-and-gas bearing province with regard to isostasy (In Russ.), Geologiya nefti i gaza, 2014, No. 1, pp. 74–82.

15. Varaksina I.V., Shavarov R.D., Lithology and reservoir properties of Precembrian deposits of the Lena-Anabar oil-and-gas region (In Russ.), Izvestiya Tomskogo politekhnicheskogo universiteta. Inzhiniring georesursov, 2020, V. 331, No. 9, pp. 159–169, DOI: https://doi.org/10.18799/24131830/2020/9/2818

Quantitative criteria for identifying petrotypes in the volcanic deposits sections of the pre-Jurassic basement of the Krasnoleninsky arch of Western Siberia are proposed. Petrological dissecting of the pre-Jurassic deposits section based on well-logging data is a priority task, as it enables to establish the most promising petrotypes and create a basis for the subsequent allocation of reservoirs, estimation of the void space type and filtration-capacitive parameters. The studied deposits are dominated by acidic volcanites. Other types of rocks can be identified based on their natural radioactivity, measured using gamma ray logging. The physical basis of the complexation is the natural increase in density and decrease in natural radioactivity from acidic volcanites to medium and basic ones. The natural radioactivity and density of volcanic-sedimentary rocks depend on the ratio of sedimentary and volcanic material. In the sections of volcanic deposits, there are intra-formationary terrigenous rocks (mudstones, siltstones, sandstones, etc.), characterized by a decrease in natural radioactivity and an increase in density compared to acidic volcanites. The identification of secondary transformations can be performed using the parameters M, N, P, weakly dependent on the porosity coefficient and explicitly reflecting the influence of the material composition, as well as the void space features (fracturing and cavernosity). The separation of lavas and volcanic rocks is performed by the values of the porosity coefficient. Characteristic ranges for the porosity coefficient values for lavas of massive texture, lavas with voids and volcanic rocks are established. The boundaries between these groups are respectively 5-6 and 17 %.

References

1. Kropotova E.P., Korovina T.A., Romanov E.A., Fedortsov I.V., Sostoyanie izuchennosti i sovremennye vzglyady na stroenie, sostav i perspektivy doyurskikh otlozheniy zapadnoy chasti Surgutskogo rayona (Rogozhnikovskiy litsenzionnyy uchastok) (The state of knowledge and modern views on the structure, composition and prospects of pre-Jurassic deposits of the western part of the Surgut region (Rogozhnikovsky license area)),Proceedings of IX scientific and practical conference “Puti realizatsii neftegazovogo potentsiala KhMAO” (Ways of realization of oil and gas potential of KhMAO), Khanty-Mansiysk: IzdatNaukaService Publ., 2006, pp. 133–146.

2. Maleev E.F., Vulkanity (Volcanics), Moscow: Nedra Publ., 1980, 240 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. Dobryden S.V., Kornev V.A., Semenova T.V., Petrological separation and interwell correlation of volcanogenic rocks (In Russ.), Neftyanoe hozyaystvo = Oil Industry, 2021, No. 6, pp. 38–42, DOI: https://doi.org/10.24887/0028-2448-2021-6-38-42

The main task of mud logging directly while well drilling include accurate and timely identification of reservoirs and the assessment of their saturation. The data provided by mud logging are an important source of information for real-time decision-making, particularly in the precise adjustment of well trajectories within the framework of geosteering. Given that these operations are conducted in a strictly real-time and operational environment, timely assessment of data quality becomes essential. To address this need and enhance the credibility of the mud logging information, this paper presents a developed system of quantitative criteria for the operational assessment of mud logging data quality. This system was designed to methodically verify compliance with gas logging standards, ensure the consistency and detail of cuttings descriptions, and to control the accuracy of key technological parameters. The proposed approach characterized by its numerical grading system and methodological universality, making it suitable for scalable implementation and integration into automated data processing workflows. The criteria were tested on mud logging datasets acquired from both terrigenous and carbonate reservoirs across oil and gas fields in Western and Eastern Siberia. This pilot testing confirms the practical applicability and efficiency of the system by enabling a rapid and unified assessment of data quality accessible not only to specialized mud logging analysts but also to specialists in other areas of oil and gas industry.

References

1. RD 153-39.0-069-01. Tekhnicheskaya dokumentatsiya po provedeniyu geologo-tekhnologicheskikh issledovaniy neftyanykh i gazovykh skvazhin (Technical documentation for conducting geological and technological studies of oil and gas wells), Tver, 2001, 91 p.

2. Luk’yanov E.E., Geologo-tekhnologicheskie i geofizicheskie issledovaniya v protsesse bureniya (Geological, technological and geophysical studies during drilling), Novosibirsk: Publishing House “Nasledie Sibiri”, 2009, 752 p.

3. Il’yazov R.R., Nikiforov S.A., Chernikov E.Yu., Rakhimov T.R., Gas logging for geosteering and rapid determination of interfluid contacts while horizontal drilling

(In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2023, No. 2, pp. 72–77, DOI: https://doi.org/10.24887/0028-2448-2023-2-72-77

4. Luk’yanov E.E., Mud logging: Is there a light at the tunnel end? (In Russ.), Karotazhnik, 2008, No. 7(172), pp. 3–49.

5. Il’yazov R.R., Nowadays possibilities of gas logging during well drilling and the necessity of its integrated metrological support (In Russ.), Stroitel’stvo neftyanykh i gazovykh skvazhin na sushe i na more, 2023, No. 8(368), pp. 11–18, DOI: https://doi.org/10.33285/0130-3872-2023-8(368)-11-18

The article describes the principles of building hydrodynamic models with dynamic relative permeabilities of oil, water, and gas and the use of such models for calculating the current displacement efficiency. The key difference between dynamic relative permeability and static relative permeability is the dependence of shape and endpoints of relative permeability not only on the saturation of pore space with oil, water and gas, but also on the filtration rate. This feature enables to model flow processes with deviations from the linear Darcy’s law and to solve tasks that usually can’t be solved using conventional simulation models with static relative permeability. Moving from models with static relative permeability to models with dynamic relative permeability brings them in line with the actual development features and enables the implementation of new capabilities in digital simulation models: separating drained and undrained areas of oil deposits and oil reserves within them; directly calculating cumulative and current displacement efficiency; building maps of oil reserves not covered by displacement processes. The estimated oil recovery factor in models with dynamic relative permeability is defined by the endpoints of relative permeability for small and large capillary numbers and may differ from the oil recovery factor in models with static relative permeability both upwards and downwards. Solving these tasks is relevant for justifying the efficiency of infill well pattern, flooding technologies, profiles of horizontal and multilateral wells, and other technologies of enhanced oil recovery both for oil and gas brownfields and for fields with hard-to-recover reserves.

References

1. Mikhaylov N.N., Polishchuk V.I., Khazigaleeva Z.R., Modeling of residual oil distribution in flooded heterogeneous formations (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2014, No. 8, pp. 36–39.

2. Mikhaylov N.N., Ostatochnoe neftenasyshchenie razrabatyvaemykh plastov (Residual oil saturation of developed reservoirs), Moscow: Nedra Publ., 1992, 270 p.

3. Popkov V.I., Zatsepina S.V., Shakshin V.P., Using relative permeabilities dependent on capillary number in hydrodynamic models of oil and gas fields (In Russ.), Matematicheskoe modelirovanie, 2005, V. 17, No. 2, pp. 92–102.

4. Baykov V.A., Kolonskikh A.V., Makatrov A.K. et al., Development of ultra low-permeability oil reservoirs (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2013,

no. 10, pp. 52–56.

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DOI: https://doi.org/10.1061/jrcea4.0001172

6. Fjelde I., Lohne A., Abeysinghe K.P., Critical aspects in surfactant flooding procedure at mixed–wet conditions, SPE-174393-MS, 2015,

DOI: https://doi.org/10.2118/174393-MS

7. Blom S.M.P., Hagoort J., How to include the capillary number in gas condensate relative permeability functions, SPE-49268-MS, 1998,

DOI: https://doi.org/ 10.2118/49268–MS

8. Amaefule J.O., Handy L.L., The Effect of interfacial tensions on relative oil/water permeabilities of concolidated porous media, SPE-8793-PA, 1982, pp. 371–381,

DOI: https://doi.org/10.2118/9783-PA

9. Cheremisin N.A., Sonich V.N., Baturin N.E., Medvedev N.Ya., Basic physics of increasing the efficiency of developing granulated reservoirs (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2002, no. 8, pp. 38–42.

10. Kostyuchenko S.V., Cheremisin N.A., Direct calculation of sweep efficiency and localization of current recoverable oil reserves in digital models (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2019, no. 7, pp. 94–98, DOI: https://doi.org/10.24887/0028-2448-2019-7-94-98

11. Kostyuchenko S.V., Cheremisin N.A., Dynamic phase permeability for calculating oil locations in digital models (In Russ.), Izvestiya vysshikh uchebnykh zavedeniy. Neft’ i gaz, 2021, No. 5, pp. 168–176, DOI: https://doi.org/10.31660/0445-0108-2021-5-168-176

12. Pyatibratov P.V., About the physical meaning and definition of the volumetric sweep efficiency in the binomial formula for calculating oil recovery factor (In Russ.), Neftyanoe khozyaystvo = Oil Industry,   2024, No. 4, pp. 80–83, DOI: https://doi.org/10.24887/0028-2448-2024-4-80-83

There is an increase in associated petroleum gas (APG) production above design values at a number of oil fields in the final stage of development. The reason is the high water cut of productive formations and the release of free gas from oil in the bottom–hole zone when the bottom-hole pressure decreases below the saturation pressure. Exceeding the planned production of APG leads to malfunction of processing plants, complications in the processing of wellbore fluids and the need to burn excess gas on flares. A brief review of studies of the genesis of gases dissolved in reservoir water is performed, modern methods for predicting the gas content in mineralized water are considered. Existing software systems have low convergence of calculated values with laboratory and field data at high values of water cut and the gas-oil ratio (GOR). In order to increase accuracy, the Cubic Plus Association (CPA) type equation of state was modified. Empirical correlations were developed that estimate the percentage of water molecules forming hydrogen bonds in wells and field collection systems. The modified equation was tested at the fields of Rosneft Oil Company. A comparison of the measured GOR values with the design and calculated according to CPA showed that with a water cut of more than 92 % and a bottom–hole pressure below saturation pressure, the smallest error (5,47–10,8 %) is between the actual and calculated GOR according to CPA; in other cases, between the measured and the design GOR.

References

1. Khalfin R.S., Zeygman Yu.V., Predicting associated petroleum gas production taking into account the dissolution of gas in formation water based on the adaptation of the cubic equation of state (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2021, No. 9, pp. 65–69, DOI: https://doi.org/10.24887/0028-2448-2021-9-65-69

2. Mikhaylov V.G., Ponomarev A.I., Topol’nikov A.S., Prediction of gas factor taking into account gas dissolved in the water at late stages development of oil fields

(In Russ.), SOCAR Proceedings, 2017, No. 3, pp. 41–48, DOI: https://doi.org/10.5510/OGP20170300322

3. Kordik K.E., Bortnikov A.E., Leont’ev S.A., Results of laboratory modeling of formation fluid interaction with the injected water in conditions simulating liquid intensive discharge out of a formation (In Russ.), Geologiya, geofizika i razrabotka neftyanykh i gazovykh mestorozhdeniy, 2015, No. 2, pp. 66–69.

4. Batalin O.Yu., Vafina N.G., Transformation of deep fluid flow in the process of oil and gas field formation of north Western Siberia (In Russ.), Georesursy, 2019,

No. 21(3), pp. 25–30, DOI: https://doi.org/10.18599/grs.2019.3.25-30

5. Akulinchev B.P., Rakhbari N.Yu., The mechanism of water dissolved and free gases interaction during forming of hydrocarbons deposits (In Russ.), Georesursy. Geoenergetika. Geopolitika, 2011, No. 2(4).

6. Novikov D.A., Borisov E.V., Geochemistry of water-soluble gases in the oil and gas bearing sediments of the zone of junction between the Yenisei-Khatanga and the West Siberian basins (the Arctic regions of Siberia) (In Russ.), Georesursy, 2021, V. 23, No. 4, pp. 2–11, DOI: https://doi.org/10.18599/grs.2021.4.1

7. Novikov D.A., Gordeeva A.O., Chernykh A.V. et al., The influence of trap magmatism on the geochemical composition of brines of petroliferous deposits in the western areas of the Kureika Syneclise (Siberian Platform) (In Russ.), Geologiya i geofizika = Russian Geology and Geophysics, 2021, V. 62, No. 6, pp. 861–881,

DOI: https://doi.org/10.15372/GiG2020160

8. Kutyrev E.F., Shkandratov V.V., Belousov Yu.V., Some results of physical modeling of gas exchange processes in an oil-injected water system (In Russ.), Georesursy, 2008, No. 5, pp. 33–36.

9. Kanzafarov F.Ya., Change of properties of oil gas while in Samotlorskoye oilfield development (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2009, No. 1,

pp. 47–49.

10. Bortnikov A.E., Kutyrev E.F., Belousov Yu.V. et al., On the change in the gas factor of oil during the development of flooded deposits (In Russ.), Territoriya Neftegaz, 2010, No. 2, pp. 62–65.

11. Sorokin A.V., Sorokin V.D., Sorokina M.R., Formation of oil zones with different physical and chemical properties during the development of a deposit (In Russ.), Izvestiya vuzov. Neft’ i gaz, 2011, No. 3(87), pp. 41–47.

12. McGee K.A., Susak N.J., Sutton A.J., Haas J.L., The solubility of methane in sodium chloride brines, U.S. Geological Survey Open-File Report 81-1294, 1981, 42 p.,

DOI: https://doi.org/10.3133/ofr811294

13. Gang Gao, Zhilong Huang, Baojia Huang et al., The solution and exsolution characteristics of natural gas components in water at high temperature and pressure and their geological meaning, Petroleum Science, 2012, V. 9, pp. 25–30, DOI: https://doi.org/10.1007/s12182-012-0178-9

14. Li Sun, Jierong Liang, Solubility calculations of methane and ethane in aqueous electrolyte solutions, Journal of Solution Chemistry, 2021, No. 50(6), pp. 920–940.

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16. Novak N., Kontogeorgis G.M., Castier M., Economou I.G., Modeling of gas solubility in aqueous electrolyte solutions with the eSAFT-VR Mie equation of state, Industrial and Engineering Chemistry Research, 2021, No. 60(42), pp. 15327–15342.

17. Baojiang Sun, Haikang He, Xiaohui Sun et al., Prediction method of solubility of carbon dioxide and methane during gas invasion in deep-water drilling, Journal of Contaminant Hydrology, 2022, V. 251, DOI: https://doi.org/10.1016/j.jconhyd.2022.104081

18. Taherdangkoo R., Liu Q., Xing Y. et al., Predicting methane solubility in water and seawater by machine learning algorithms: Application to methane transport modeling, Journal of Contaminant Hydrology, 2021, V. 242, DOI: https://doi.org/10.1016/j.jconhyd.2021.103844

19. R. Nakhaei-Kohani, Atashrouz S., Hadavimoghaddam F. et al., Solubility of gaseous hydrocarbons in ionic liquids using equations of state and machine learning approaches, Scientific Reports, 2022, No. 12(1), DOI: https://doi.org/10.1038/s41598-022-17983-6

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No. 35, pp. 4310–4318, URL: https://www.sci-hub.ru/10.1021/ie9600203

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23. Aasberg-Petersen K., Stenby E., Fredenslund A., Prediction of high-pressure gas solubilities in aqueous mixtures of electrolytes, Industrial and Engineering Chemistry Research, 1991, No. 30, pp. 2180–2185, DOI: https://doi.org/10.1021/ie00057a019

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Conducted research and development experience showed that flooding efficiency depends significantly on the size and structure of pores and pore channels. The decline in flooding efficiency in low-permeability reservoirs led to an active search for alternative working agents. The majority of projects involve the injection of carbon dioxide and hydrocarbon gases. The key parameters influencing the efficiency of gas-based methods are miscibility pressure and displacement efficiency. By these criteria, nitrogen is the least attractive working fluid, but for reservoir pressure maintenance purposes, this gas offers a number of advantages. There are no criteria for the applicability of gas injection, including nitrogen, for reservoir pressure maintenance. This article presents the results of nitrogen injection modeling using a composite 3D hydrodynamic model to assess the effectiveness of its use for reservoir pressure maintenance in low-permeability reservoir conditions in the range of permeability values from 1·10-3 µm2 до 12·10-3 µm2. A range of absolute permeability coefficient values was obtained for which a greater volume of injected nitrogen (74 %) was effective in maintaining reservoir pressure. The distribution of injected gas by action mechanisms was assessed depending on absolute permeability values. When adapting nitrogen injection technology to specific geological and physical conditions for reservoir pressure maintenance, one of the main tasks is to determine the permissible range of reservoir permeability values.

References

1. Nazarova L.N., Comparison of the design and actual factors of oil recovery by the value of hydraulic conductivity for terrigene and carbonate formations (In Russ.), Neftepromyslovoe delo, 2015, No. 1, pp. 12–14.

2. Baykov V.A., Galeev R.R., Kolonskikh A.V., Makatrov A.K. et al., Nonlinear filtration in low-permeability reservoirs. Analisys and interpretation of laboratory core examination for Priobskoye oilfield (In Russ.), Nauchno-tekhnicheskiy vestnik OAO “NK “Rosneft’”, 2013, no. 2, pp. 8–12.

3. Baykov V.A., Galeev R.R., Kolonskikh A.V. et al., Nonlinear filtration in low-permeability reservoirs. Impact on the technological parameters of the field development

(In Russ.), Nauchno-tekhnicheskiy vestnik OAO “NK “Rosneft’”, 2013, no. 2, pp. 17–19.

4. Mikhaylov N.N., Tumanova E.S., Phase permeability of low-permeable collectors (In Russ.), Neftepromyslovoe delo, 2020, No. 8, pp. 28–38,

DOI: https://doi.org/10.30713/0207-2351-2020-8(620)-28-38.

5. Guzmann M.S., Review of a forgotten technology with high potential – The world largest nitrogen based IOR project in the supergiant field Cantarell, Mexico,

SPE-171239-MS, 2014, DOI: https://doi.org/10.2118/171239-MS

The use of comparables is a traditional approach for estimating investments in a prospective capital construction projects at the conceptual design stage. The application of this approach is complicated by the problem of correct comparable choose and correct determination of the prospective object key attribute in order to recalculate the cost of comparable, as well as the need to plan the dynamics of investments depending on various factors. The solution is to perform the estimation within a unified digital ecosystem that brings together specialists and experts and is based on a unified object structure – unified classifier of surface infrastructure objects. The article describes the process of selecting a comparable in a unified digital ecosystem using the prospective database of comparables and the automated selection algorithm. The existence of the database and the automated algorithm significantly simplifies the process of selecting and approving comparable objects. To simplify the process of cost recalculation from a comparable to an object being evaluated, unified methodological approaches for performing calculations are proposed. To compensate for the shortcomings associated with the stage of forming the dynamics of capital expenditures, a process flow for forming the dynamics of investments at the conceptual stage of work based on the developed layout-graph is proposed. The proposed changes to the investments calculation process are implemented as the «Dynamics of Capital Investments» plugin of the unified digital platform «RN-ALPHA».

References

1. Miroshnichenko R.V., Kolmogorova V.A., Erofeev E.L. et al., Development of approaches to capital expenditures estimation at conceptual design stage by object structure unification and use of application software (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2024, No. 11, pp. 51–55, DOI: https://doi.org/10.24887/0028-2448-2024-11-51-55

2. URL: https://mporosneft.ru/novosti/novosti-kompanii/rosneft-predstavila-novyie-czifrovyie-razrabotki-dlya...

3. Murashov B.A., Teplyakov N.F., Calculation and optimization of oil treatment and pumping facilities during project evaluation and reengineering (In Russ.), PRONEFT’’. Professional’no o nefti, 2018, No. 4(10), pp. 71–74, DOI: https://doi.org/10.24887/2587-7399-2018-4-71-74

4. Akhmetov R.N., Yunusov I.E., Optimization of the construction cost of linear surface objects using digital GIS systems and automated cost models (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2022, No. 8, pp. 90–93, DOI: https://doi.org/10.24887/0028-2448-2022-8-90-93

5. Kislenko N.A., Barabanova Yu.A., Belinskiy A.V. et al., Artificial intelligence in investment management: Today and future (In Russ.), Gazovaya promyshlennost’, 2025, No. 8(885), pp. 110–123.

The investment decision-making process for early-stage projects in the oil and gas industry is associated with high levels of uncertainties and risks due to limited geological data accuracy, variability in development technology parameters, and volatility of macroeconomic environment. A comprehensive integrated probabilistic methodology was developed to address these challenges. It provides systematic identification of key technical uncertainty groups, analysis of corresponding probability distributions, and sequential integration of all computation stages into a unified automated workflow controlled externally via MS Excel and API interfaces. Multivariate modeling followed by statistical processing of results enable to derive standard P10, P50, P90 cases for cumulative oil production and net present value (NPV), but also quantitative estimation of positive economic outcome probability. The practical implementation of the approach is demonstrated on a real oil field using specialized software and an external control system. The case study shows that the probabilistic approach enables a quantitative assessment of the range of possible cumulative production and NPV values, evaluation of the baseline deterministic forecast reliability, and adjustment of target production profile to a more realistic P50 scenario. The obtained results formed the basis for the positive investment decision to launch the project; subsequent actual production performance after start-up confirmed the conservative assumption of the baseline scenario and corresponded to P30, thereby validating the effectiveness of comprehensive uncertainty integration at early planning stages.

References

1. Merrow E.W., Industrial megaprojects. Concepts, strategies, and practices for success, Hoboken, New Jersey: John Wiley & Sons, Inc., 2011, 414 p.,

DOI: https://doi.org/10.1002/9781119201045

2. Mohus E., Over budget, Over time, and reduced revenue, over and over again – An analysis of the Norwegian petroleum industry’s inability to forecast production: Master thesis, University of Stavanger, 2018, 122 p.

3. OTC-26309-MS. Reservoir-schedule coupled uncertainty analysis for PD projects: Optimization opportunities and improvements for more robust production forecasts, 2015, 12 p.

4. Silveira M. et al., Utilization of the GRM (Geological Representative Models) to integrate different types of uncertainties in the decision making process,

SPE-120924-MS, 2009, DOI: https://doi.org/10.2118/120924-MS

5. Williams G. et al., Top-down reservoir modeling, SPE-89974-MS, 2004, DOI: https://doi.org/10.2118/89974-MS

This article examines the Gazprom Neft Companу approach to predictive reengineering of surface infrastructure, which aims at shifting from point optimization solutions to systematic efficiency management. The article presents practical cases demonstrating three key directions for realizing the potential of reengineering. The first case demonstrates a methodology for cluster reengineering aimed at reducing operating costs by preservation of the excess equipment. By modeling the surface infrastructure, the authors identified a scenario for changing the configuration and composition of equipment that ensures optimal load of facilities and eliminates technical limitations of well operation. The second case focuses on optimizing of capital costs by implementing a detailed analysis of the existing infrastructure with decomposition down to individual equipment units. A systematic approach to analyzing a significant number of facilities is enabled by a specialized analytical tool and makes it possible to avoid purchasing new equipment over a three-year period. The third case addresses the lifting of infrastructure restrictions that are limiting liquid hydrocarbon production. Process modeling ensures the necessary throughput capacity of the surface infrastructure for the collection and preparation of associated petroleum gas under growing gas-oil ratio conditions, without loss of product quality and at an optimal investment level. The conclusion notes the effects of the implementation of predictive reengineering, and emphasizes the versatility of the presented solutions and their potential for replication.

References

1. Gilaev G.G., Khabibullin M.Ya., Antoniadi D.G., Infrastructure reengineering as an effective tool for maintaining base production (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2022, No. 1, pp. 77–81, DOI: https://doi.org/10.24887/0028-2448-2022-1-77-81

2. Mozhchil’ A.F., Bazyleva N.Z., Yanina I.V. et al., Benchmarking as a tool for systematic work on improving the efficiency (potential) at Gazprom Neft (In Russ.) Neftyanoe khozyaystvo = Oil Industry, 2023, No. 12, pp. 6–11, DOI: https://doi.org/10.24887/0028-2448-2023-12-6-11

3. Mozhchil’ A.F., Khasanov M.M., Pislegin M.N. et al., Predictive reengineering: effectively realizing the potential of mature fields (In Russ.), Neftegazovoe delo, 2026,

V. 24, No. 1, pp. 42–51, DOI: https://doi.org/10.17122/ngdelo-2026-1-40-49

4. Isakov A.S., Chuprina D.V., Khoroshev A.N. et al., Operational efficiency improvement of oil and gas production in domain of surface infrastructure (In Russ.) Neftyanoe khozyaystvo = Oil Industry, 2024, No. 8, pp. 116–121, DOI: https://doi.org/10.24887/0028-2448-2024-8-116-121

5. Nekrasov N.O., Fayzrakhmanov G.G., Mavlyavov I.R., Prospects for application of integrated simulation for mature fields (In Russ.), PROneft’. Professional’no o nefti, 2025, V. 10, No. 2, pp. 120–131, DOI: https://doi.org/10.51890/2587-7399-2025-10-2-120-131

6. Zotkin O.V., Yudin E.V., Plokhova K.F. et al., Hybrid integrated asset model – flexible oilfield management tool (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2023, No. 4, pp. 86–90, DOI: https://doi.org/10.24887/0028-2448-2023-4-86-90

7. Asmandiyarov R.N., Barkalov S.Yu., Galeev R.R. et al., Improving the economic efficiency of oil production at the “Gazpromneft-Khantos” fields (In Russ.), PRONEFT’’. Professional’no o nefti, 2021, V. 6, No. 3, pp. 136–143, DOI: https://doi.org/10.51890/2587-7399-2021-6-3-136-143

8. Sidorenko D.D., Afanas’ev A.A., Mal’tsev A.A. et al., Application of optimization algorithms to production management: Removing infrastructure constraints (In Russ.), PROneft’. Professional’no o nefti, 2025, V. 10, No. 1, pp. 90–97, DOI: https://doi.org/10.51890/2587-7399-2025-10-1-90-97

9. Baydalzhi E.A., Programma reinzhiniringa Novoportovskogo NGKM. Optimizatsionnye resheniya. Novye tekhnologii v gazovoy promyshlennosti (gaz, neft’, energetika) (Novoportovskoye oil and gas condensate field reengineering program. Optimization solutions. New technologies in the gas industry (gas, oil, energy)), Moscow: Publ. of Gubkin University, 2023, pp. 199–200.

10. Il’ina L.A., Demina A.A., Economic effects of reengineering of ground infrastructure of oil and gas producing enterprises (In Russ.), Vestnik Samarskogo gos. ekonomicheskogo universiteta, 2021, No. 3, pp. 36–42, DOI: https://doi.org/10.46554/1993-0453-2021-3-197-36-42

The paper under consideration presents the field experience of using the tracer’s inflow profile monitoring system in the cemented completion for the reduction of environmental risks. Nowadays there are no examples of the use of tracer’s inflow profile monitoring systems for cemented completion in world practice. Existing technologies are unable to perform high-quality measurements in these conditions, or there is no such opportunity as a result of the technological limitations. Oil producing companies are forced to bear significant financial costs and increased operational risks when operating the horizontal wells using conventional methods of production logging with the delivery of complex measuring equipment to the target depth on a geophysical cable or with the use of coil tubing. Oil and gas production companies have to reduce the production logging programs in order to reduce the costs, which excludes the possibility of reaching the maximum potential of the hydrocarbon recovery in the long term. The tracer’s inflow profile monitoring technologies used in the jobs described in this article enable the high-quality monitoring of the well’s operation for a long time without interrupting the production process, at the same time significantly reducing capital and operating costs along with reducing environmental risks during well operation.

References

1. Geofizicheskie issledovaniya skvazhin: spravochnik mastera po promyslovoy geofizike (Well survey: a reference guide for field geophysics): edited by Martynov V.G., Lazutkina N.E., Khokhlova M.S., Moscow: Infrainzheneriya Publ., 2009.

2. Gur’yanov A., Katashov A., Ovchinnikov K. et al., About the technology of marker monitoring of horizontal wells (In Russ.), Neftegazovaya vertikal’, 2020, No. 9–10, pp. 99–103.

3. Proceedings of 6th scientific and practical conference “Gorizontal’nye skvazhiny 2024” (Horizontal wells 2024), Kazan, 13–16 May 2024, Moscow: Geomodel’ Razvitie Publ., 2024, 354 p.

4. Patent RU2702446C1, Method for determination of well fluid influx from separate well intervals, Inventor: Zhuravlev O.N.

5. Zotov E.N., Bayunov S.V., Musaev M.N. et al., Application of marker systems for determining the inflow profile at the Samotlor field (In Russ.), Neftegazovaya vertikal’, 2025, No. 3.

The article discusses current trends aimed at improving the quality and accuracy of cost estimates at the project design stage. On the one hand, the high importance of cost estimates for making managerial decisions and ensuring the economic efficiency of construction projects determines the need to develop measures to improve the accuracy of estimates. On the other hand, it is necessary to take into account that the estimated documentation is based on design documentation, which also has a certain accuracy of the engineering decisions made. And if at the pre–project stages, as well as at the stage of developing detailed documentation, the methods and approaches of cost estimation are clear and logical (in both world and Russian practice), then at the stage of developing project documentation they are more contradictory, and some of them carry the risks of illusory achievement of the initial goal – to increase the accuracy of the cost estimate. The article analyzes the changes in the approach to the development of estimates at the stage of project documentation from the point of view of methods and trends of recent times, draws an analogy with world practice, and shows the risks associated with attempts to improve the accuracy of estimates using the proposed methods.

References

1. Kenneth K., McDonald D.F. JR, Miller B.A. et al., Cost estimate classification system – As applied in engineering procurement, and construction for the process industries, AACE International Recommended Practices, 2005.

2. Lakhaev S.V., Strategiya razvitiya tsenoobrazovaniya v stroitel’stve. Realizuemye meropriyatiya (Construction pricing development strategy. Implemented measures), URL: https://gge.ru

3. MDS 81-02-13-2014. Metodicheskie dokumenty po formirovaniyu smetnogo razdela proektnoy dokumentatsii s primeneniem ukrupnennykh normativov tseny konstruktivnykh resheniy (Methodological documents for the formation of the estimate section of design documentation using consolidated standards for the price of design solutions).

This article examines the transformation of tubing repair processes through the transition to stationary workshop facilities equipped with automated and robotic cleaning systems. The inefficiency of traditional manual and chemical methods is demonstrated, particularly under severe clogging, which lead to localized thread damage, inconsistent surface quality, and uncontrolled waste generation. The structure of the technological line is presented, including the following modules: input control, comprehensive diagnostics, positioning, hydraulic, plasma and ultrasonic cleaning, drying, non-destructive testing, thread restoration and hydraulic tests. The key element is the introduction of a digital twin and a unified automated process control system, providing end-to-end accounting, adaptive control of processing parameters and cycle forecasting. Based on a review of leading manufacturers’ equipment and analysis of industrial pilot trials, implementation, and commercial operation across the Western Siberian and Volga-Ural regions (2022–2026), significant technological and economic efficiencies are confirmed: throughput increases by 45–65 %, cleaning time is halved, water and reagents consumption is reduced by 40-50 %, and the share of scrap decreases by 70-80 %. Particular attention is paid to environmental safety through the use of closed water recycling circuits and minimizing the presence of personnel in the hazardous area. Recommendations for modular design, selection of proven solutions, AI integration, and workforce training are provided to guide future industry development.

References

1. Il’in K.O., Kraevskiy N.N., Gavrilova O.A. et al., Methodological foundations for the implementation of robotic systems in order to improve the efficiency of repairing tubing (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2021, no. 9, pp. 108–111, DOI: https://doi.org/10.24887/0028-2448-2021-9-108-111

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

3. NTS-Lider. Ochistka NKT: tekhnologicheskie resheniya dlya statsionarnykh i peredvizhnykh kompleksov (Tubing cleaning: Technological solutions for stationary and mobile systems), URL: https://www.nts-leader.ru/services/remont-i-servis-trub/diagnostika-i-remont-nkt/ochistka-nkt/

4. Progress-spetsoborudovanie. Avtomatizirovannaya liniya moyki nasosno-kompressornykh trub vysokim davleniem (Automated high-pressure tubing cleaning line), URL: https://p-so.ru/products/avtomatizirovannaya_liniya_moyki_nasosno-kompressornih_trub_nkt_visokim_dav...

5. NPP Tekhmashkonstruktsiya. Avtomatizirovannaya liniya moyki nasosno-kompressornykh trub (Automated line for washing pump and compressor pipes),

URL: https://npp-tmk.ru/product/dlya-remonta-i-diagnostiki-nasosno-kompressornykh-trub/avtomatizirovannay...

6. Progress-spetsoborudovanie. Moyka nasosno-kompressornykh trub aktivatornogo tipa (Activator-type cleaning of pump and compressor pipes),

URL: https://p-so.ru/products/moyka_nasosno-kompressornih_trub_nkt_aktivatornogo_tipa-4

7. Senokosov A.E., Ushakov M.Yu., Senokosov E.S., Gaskarov V.Z., Plasma cleaning complex for tubing and pump rods (In Russ.), Sfera. Neft’ i gaz, 2015, No. 3,

pp. 72–75.

8. Zevs. Tekhnologicheskiy kompleks elektrogidroimpul’snoy ochistki nasosno-kompressornykh trub ot tverdykh otlozheniy Zevs-41 (Zeus-41 technological complex for electrohydropulse cleaning of pump and compressor pipes from solid deposits), URL: https://zevs-irp.ru/articles/tekhnologicheskiy-kompleks-elektrogidroimpulsnoy-ochistki-nasosno-kompr...

9. Ul’tra-Fil’tr. Ul’trazvukovye ustanovki TUZ dlya ochistki trub (Ultrasonic installations TUZ for cleaning pipes), URL: https://ultra-filter.ru/equipment_ultra/tubes.php

The separation of stable oil-water emulsions is a significant part of the operating and energy costs in the process of field oil preparation. This is associated with the use of demulsifiers, which accelerate the emulsion separation process. In the process of field oil preparation, heating of incoming well products is used by burning associated hydrocarbon gas. The paper considers the possibility of using physical methods that can improve the efficiency of existing oil treatment methods at the Taylakovskoye field. The proposed method for increasing the rate of emulsion separation is based on exposure to a controlled ultrasonic field. Tests were carried out on «live» emulsions, for which the separation efficiency in an acoustic field was determined depending on the product temperature, the concentration of the demulsifier, the frequency and time of exposure to the emitter. Particular attention was paid to studying the formation causes and factors contributing to the stability of water-oil emulsions of the Taylakovskoye field. The research conducted led to the development of a technological solution for the use of an acoustic wave excitation system installed directly on the inlet pipelines of the complex oil treatment units. Conventional main oil pipelines were used as resonant channels for ultrasonic vibrations, contributing to additional activation of the demulsifier to separate well products into phases. The pilot work demonstrated the possibility of reducing the volume of demulsifiers used. This technological solution contributed to improving the quality of oil preparation at the current installation and reducing the temperature factor during product separation.

References

1. Lekomtsev A.V., Ilyushin P.Y., Derendyaev K.A. et al., Separation of stable water-oil emulsion using ultrasonic action, Chemical and Petroleum Engineering, 2020,

V. 55, No. 11-12, pp. 869-875, DOI: https://doi.org/10.1007/s10556-020-00706-x

2. Sakhabutdinov R.Z., Sudykin A.N., Gubaydulin F.R., Study of ultrasonic dehydration process for heavy oil (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2013,

No. 10, pp. 116–119.

3. Romanova Y.N., Maryutina T., Musina N.S., Spivakov B.Y., Application of ultrasonic treatment for demulsification of stable water-in-oil emulsions, Journal of Petroleum Science and Engineering, 2022, V. 209, DOI: https://doi.org/10.1016/j.petrol.2021.109977

4. Sudykin A.N., Issledovanie i razrabotka tekhnologiy razdeleniya ustoychivykh vodoneftyanykh emul’siy s primeneniem fizicheskikh metodov (Research and development of technologies for the separation of stable water-oil emulsions using physical methods): thesis of candidate of technical science, Bugul’ma, 2013, 159 s.

5. Khmelev V.N., Barsukov R.V., Golykh R.N. et al., Identification of optimal modes of ultrasonic pulse action for coagulation in liquid-dispersed media, South-Siberian

Scientific Bulletin, 2017, V. 3, pp. 15–20.

6. Den’gaev A.V., Verbitskiy V.S., Mishchenko I.T. et al., Prospects for the use of ultrasonic influence in the process of preparation of oil at the Priobskoye field (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2020, No. 3, pp. 28–30, DOI: https://doi.org/10.24887/0028-2448-2020-3-28-30

7. Patent RU2768664C2, Method of ultrasonic dispersion of demulsifier in oil-water emulsion, Inventors: Afanas’ev A.V., Getalov A.A., Den’gaev A.V. et al.

Protecting equipment from mechanical impurities during liquid hydrocarbon transport and production is a critical task. Various types of strainer filters are used for this purpose. However, filter operation involves an increase in pressure drop and contamination of the filter element, which in turn leads to higher operational costs for liquid pumping and filter maintenance. The study objective is to investigate the design of vertical strainers utilized in the oil industry. To unify the results, all parameters of the studied filter are presented without units of measurement, enabling the results to be scaled to other filter sizes. This article describes ways to improve the performance of strainer filters used in oil transportation. Using numerical modeling and a software package for automated batch calculations, the dependence of the pressure drop on the filter design parameters was determined. The presented design optimization options are selected based on the minimum capital costs for reconstructing the filter connection assembly. The methods for solving this problem, the software packages used, and additional design tools are described. The results obtained are analyzed, and the feasibility of their application is presented. Specific recommendations are given on the optimal position and angle of the inlet and outlet nozzles, the optimal radius of the filter element, and the optimal wave parameters in the case of a corrugated filter element.

References

1. Kolmakov E.A., Kondrashov P.M., Zen’kov I.V., Review of filter designs used in oil production by means of electric submersible pumps (In Russ.), Vestnik Kuzbasskogo gosudarstvennogo tekhnicheskogo universiteta, 2016, No. 1(113), pp. 150–157.

2. G.V. Okromelidze, D.S. Loparev, N.G. Deminskaya et al., New approaches to bench tests of in-well filters in thermobaric conditions on the example of the Yareg deposit (In Russ.), Neftepromyslovoe delo, 2019, No. 10(610), pp. 47–52, DOI: https://doi.org/10.30713/0207-2351-2019-10(610)-47-52

3. Van Kh., Korotaeva T.P., Podgornov V.M., Comparison of bottom-hole filters for an unstable reservoir with high viscous oil (In Russ.), Stroitel’stvo neftyanykh i gazovykh skvazhin na sushe i na more, 2020, No. 9(333), pp. 37–41, DOI: https://doi.org/10.33285/0130-3872-2020-9(333)-37-41

4. Urazakov K.R., Abdullin N.A., Alimetov Sh.A., Comparison of bottom-hole filters for an unstable reservoir with high viscous oil (In Russ.), Neftegazovoe delo, 2020,

V. 18, No. 5, pp. 122–130, DOI: https://doi.org/10.17122/ngdelo-2020-5-122-130

5. Van Kh., Podgornov V.M., Mo Ts., Experimental studies of the efficiency of filter elements of downhole filters in a high-viscosity oil flow (In Russ.), Stroitel’stvo neftyanykh i gazovykh skvazhin na sushe i na more, 2022, No. 1(349), pp. 43–47, DOI: https://doi.org/10.33285/0130-3872-2022-1(349)-43-47. - EDN: ZGGMOJ

6. Savanin A.S., Improvement of regulatory documents used in measuring the quantity and quality indicators of oil and petroleum products (In Russ.), Zakonodatel’naya i prikladnaya metrologiya, No. 5(185), 2023, pp. 26–30.

7. Aralov O.V. Buyanov I.V., Savanin A.S., Evaluation of reliability of developed technical devices using tests (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2025,

No. 2, pp. 72–77, DOI: https://doi.org/10.24887/0028-2448-2025-2-72-77

8. Bulat A.V., Karelina S.A., Analysis of the possibility of using filter elements to protect downhole pumping equipment from mechanical impurities (In Russ.), Oborudovanie i tekhnologii dlya neftegazovogo kompleksa, 2021, No. 5(125), pp. 18–23, DOI: https://doi.org/10.33285/1999-6934-2021-5(125)-18-23

9. Teplov O., Fomenko V., Valiev T., Optimization of blade machines in the pSeven software package (In Russ.), SAPR i grafika, 2023, No. 1(317), pp. 10–13.

10. Shabliy L.S., Krivtsov A.V., Kolmakova D.A., Komp’yuternoe modelirovanie tipovykh gidravlicheskikh i gazodinamicheskikh protsessov dvigateley i energeticheskikh ustanovok v ANSYS Fluent (Computer simulation of typical hydraulic and gas-dynamic processes of engines and power plants in ANSYS Fluent), Samara: Publ. of Samara University, 2017, 109 p.

11. Ziganshin A.M., Vychislitel’naya gidrodinamika. Postanovka i reshenie zadach v protsessore Fluent (Computational Fluid Dynamics: Problem Formulation and Solving on the Fluent Processor), Kazan: Publ. Of Kazan State University of Architecture and Civil Engineering, 2013, 79 p.

Terrestrial laser scanning (TLS) technology is a promising tool for digital transformation in the construction industry, particularly for reconstruction, technical refurbishment, and major repairs of oil and gas field facilities. A digital information model (DIM) reconstructed from the TLS point cloud of laser reflections (PLC) enables not only the geometric position of an object in space to be taken into account but also to monitor its technical condition. A current research area is the development of a comprehensive algorithm for DIM reconstruction from the TLS PLC using Russian software. The goal of this work is to implement and test an algorithm for DIM reconstruction for an oil and gas facility from the TLS PLC using «NanoCAD», «ReClouds», «Model Studio CS», and «CADLib» software. The proposed algorithm includes fieldwork – TLS surveys, non-destructive testing of buildings and structures – as well as office work to process the TLS cloud and reconstruct the DIM in Russian software. Based on the experience of using the resulting DIM, practical applications were identified. It was concluded that the DIM of existing building structures and utilities, combined with the PLC cloud, panoramas from TLS points, and a digital elevation model, provide a highly detailed basis for designing facilities in their actual state. This is due to the ability to take into account the accurate geometric position and technical condition of existing facilities, as well as identify conflicts between design and existing 3D models.

References

1. Nafiev R.Sh., 3D modelirovanie arkhitekturno-stroitel’nykh resheniy kustovoy ploshchadki na baze po Model Studio CS (3D modeling of architectural and construction solutions for a well pad based on Model Studio CS), Proceedings of 67th University Scientific and Technical Conference of Students and Young Scientists: Reports of the Conference of Students and Young Scientists, Tomsk, 19–23 April 2021, Tomsk: Publ. of Tomsk State University of Architecture and Civil Engineering, 2021,

pp. 217–219.

2. Yamov A.V., Isupov N.S., Serbin S.A., Fomin N.I., Life cycle model of a digital information model at the construction stage (In Russ.), Vestnik evraziyskoy nauki, 2025, V. 17, no. 6.

3. Merkulov A.D., Lavrennikova O.A., Informatsionnoe modelirovanie po rezul’tatam tsifrovykh izyskaniy s podgotovkoy ispolnitel’nykh modeley sushchestvuyushchey real’nosti (Information modeling based on the results of digital surveys with the preparation of executive models of the existing reality), Collected papers “Programmnoe obespechenie dlya tsifrovizatsii predpriyatiy i organizatsiy” (Software for digitalization of enterprises and organizations), Proceedings of II All-Russian scientific and practical conference, Magnitogorsk, 1–2 July 2024, Magnitogorsk: Publ. of Magnitogorsk State Technical University named after G.I. Nosov, 2024, pp. 93–94.

4. Avrenyuk A.N. et al., 3D modeling of Rosneft objects at various stages of their life cycle (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2024, no. 8, pp. 34–37, DOI: https://doi.org/10.24887/0028-2448-2024-8-34-37

5. Didichin D.G., Pavlov V.A., Avrenyuk A.N. et al., 3D engineering for Rosneft oil producing facilities construction (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2022, no. 11, pp. 64‒67, DOI: https://doi.org/10.24887/0028-2448-2022-11-64-67

6. SP 333.1325800.2020. Building information modeling. Modeling guidelines for various project life cycle stages.

Dispersed soils located in places of storage, transportation and processing of hydrocarbon materials are most often affected by oil products pollution. Various technologies for cleaning soils contaminated with petroleum products are widely discussed in the press, and many of them are often not without drawbacks. The article analyzes, from the point of view of energy intensity, the technology of cleaning sandy or similar soils by water washing, which has a number of advantages over other technologies primarily due to its technical accessibility. It is shown that the efficiency of washing contaminated sandy soil with water is determined by the amount of energy spent on the process. Currently, the greatest contribution of the required energy is made by heating the washing water to the maximum possible temperature combined with mechanical stirring. The calculation of the energy spent on the process of cleaning sandy soils was performed. The theoretical calculations are confirmed by experimental studies. Measurements of the fuel oil content in the sand before and after the experiments were performed using the gravimetric method according to federal environmental regulatory document HDPE F 16.1.41-04. Effective laboratory-scale ultrasonic cavitation in industrial conditions is still not applicable due to the lack of ultrasound sources of sufficient power. It is proposed to use hydrodynamic cavitation instead of ultrasonic and an example of using hydrodynamic cavitation for washing tar sands is given.

References

1. Omel'yanyuk M.V., Pakhlyan I.A., Abolishment of Kuban oil fields during the Great Patriotic War: History and present (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2025, No. 11, pp. 140-141.

2. Vasil’ev A.V., Analytical review of methods and technical solutions of reduction of negative impact of wastes during development of oil and gas fields (In Russ.), Akademicheskiy Vestnik ELPIT, 2024, V. 9, No. 4, pp. 12–25.

3. Ongarbaev E.K., Tileuberdi E., Imanbaev E.I., Mansurov Z.A., Efficient processing of oil sands into purpose products (In Russ.), Gorenie i plazmokhimiya, 2021, V. 19,

No. 4, pp. 299–308, DOI: https://doi.org/10.18321/cpc467

4. Agarwal A., Liu Y., Zhou Y., Remediation of oil-contaminated sand with self-collapsing air microbubbles, Environmental Science and Pollution Research, 2016, V. 23, pp. 23876–23883, DOI: https://doi.org/10.1007/s11356-016-7601-5

5. Kumoh Y.S., Cha J., Lim M. et al., Comparison of ultrasonic and conventional mechanical soil-washing processes for diesel-contaminated sand, Industrial and engineering chemistry research, 2011, V. 50, No. 4, pp. 2400–2407, DOI: https://doi.org/10.1021/ie1016688

6. Chen C.S., Tien Ch.-Ju., Remediation of lubricant contaminated soils by cavitation microjet shock wave soil washing system with ozonation, Soil and Sediment Contamination, 2023, V. 32, No. 8, pp. 1053–1065, DOI: https://doi.org/10.1080/15320383.2022.2164558

7. Sherman P., Emulsion Science, Academic Press Inc., 1968, 496 p.

8. Feng Yingming, Modification and separation of oil sand with ultrasonic wave and analysis of its products, International Journal of Mining Science and Technology, 2013, V. 23, No. 4, pp. 531–535, DOI: https://doi.org/10.1016/j.ijmst.2013.07.011

9. Stebeleva O.P., Minakov A.V., Application of cavitation in oil processing: an overview of mechanisms and results of treatment, ACS omega, 2021, V. 6, No. 47,

pp. 31411–31420, DOI: https://doi.org/10.1021/acsomega.1c05858

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

11. Bukharin N., El Hassan M., Nobes D., Omelyanyuk M., Reducing energy consumption during bitumen separation from oil sand, Energy Reports, 2020, V. 6,