Nowadays, there is a fairly large number of examples of the development of so-called isolated areas of abnormally high formation pressure (AHFP). The condition for their formation is not only lateral but also vertical isolation, that is, a return to hydrostatic pressure beneath the AHFP zone and, consequently, the presence of a lower seal associated with gas generation processes and its entry into adjacent microporosity zones. Data on this part of the section are very limited due to both objective (geological) and subjective (technological) factors. Moreover, the AHFP interval is often perceived as «infinite» with no lower boundary. Similarly, the appearance of igneous (effusive) rocks in a section is often perceived as the base of a sedimentary cover, whereas a multi-kilometer «normal» sedimentary section can be established beneath the effusive rocks. The purpose of this article is to draw the attention of specialists to the possibility of such phenomena as the isolation of AHFP zones and their impact on hydrocarbon systems. Particular attention should be paid to the influence of isolated AHFP zones on the increased potential of underlying complexes, where new promising horizons may be identified. This is particularly relevant for deep and ultra-deep sections. Such pressure regressions must be taken into account when modeling the development of hydrocarbon systems, especially superimposed ones. Furthermore, isolation of AHFP can form vast areas with so-called «unconventional» massive reservoirs, which may become the target of exploration.

References

1. Allen P.A., Allen J.R., Basin analysis: Principles and application to petroleum play assessment, John Wiley & Sons, 2013, 640 p.

2. Galushkin Yu.I., Modelirovanie osadochnykh basseynov i otsenka ikh neftegazonosnosti (Simulation of sedimentary basins and assessment of their oil and gas potential), Moscow: Nauchnyy mir Publ., 2007, 456 p.

3. Reshenie VI Mezhvedomstvennogo stratigraficheskogo soveshchaniya po rassmotreniyu i prinyatiyu utochnennykh stratigraficheskikh skhem mezozoyskikh otlozheniy Zapadnoy Sibiri (Decision VI of the interdepartmental stratigraphic meeting on the review and adoption of refined stratigraphic schemes of the Mesozoic deposits of Western Siberia), Novosibirsk: Publ. of SNIIGGiMS, 2004, 114 p.

4. Grigorenko T.V., Savostin G.G., Kalmykov A.G. et al., Domanic oil shale sediments organic matter and saturating fluids characteristics on the territory of the Tatarstan Republic (In Russ.), Georesursy, 2025, V. 27, No. 1, pp. 221–235, DOI: https://doi.org/10.18599/grs.2025.1.25

5. Hantschel T., Kauerauf A.I., Fundamentals of basin and petroleum systems modeling, Springer-Verlag Berlin Heidelberg, 2009, 492 p.

6. Emel’yanenko O.A., Khafizov S.F., Kalmykov G.A. et al., Promising hydrocarbon systems of the Mangyshlak oil and gas basin (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2025, No. 5, pp. 32–37, DOI: https://doi.org/10.24887/0028-2448-2025-5-32-37

Basin modeling is currently a key tool for studying the geological evolution and assessing the functioning of hydrocarbon systems in various territories. During the preliminary assessment of a territory's oil and gas potential, it increases the likelihood of successfully drilling new wells, and during the development phase, it can play a significant role, especially when working with a complex obkect, such as the example discussed in this paper. The article presents the results of basin modeling of various scenarios for the oil deposits formation in Late Jurassic and Early Cretaceous strata on the southeastern side of the Frolov megadepression. To improve the accuracy of modeling, an approach for the initial kinetic spectra reconstruction based on the kerogen conversion laboratory modeling results and 1D basin modeling was proposed. The obtained results showed that in the case of high kerogen reactivity productive deposits are saturated with fluids from the Lower and Middle Jurassic source rocks, which do not correspond to the results of comparing the molecular composition of the oils and extracts from the source rocks. It is possible to achieve a significant contribution of hydrocarbons generated by the Bazhenov formation in the case of hydrothermal fluid impact during the Late Cretaceous or Paleogene time, or in the case of lateral migration from neighboring areas with more transformed Bazhenov deposits.

References

1. Allen P.A., Allen J.R., Basin analysis: Principles and application to petroleum play assessment, John Wiley & Sons, 2013, 640 p.

2. Galushkin Yu.I., Modelirovanie osadochnykh basseynov i otsenka ikh neftegazonosnosti (Simulation of sedimentary basins and assessment of their oil and gas potential), Moscow: Nauchnyy mir Publ., 2007, 456 p.

3. Reshenie VI Mezhvedomstvennogo stratigraficheskogo soveshchaniya po rassmotreniyu i prinyatiyu utochnennykh stratigraficheskikh skhem mezozoyskikh otlozheniy Zapadnoy Sibiri (Decision VI of the interdepartmental stratigraphic meeting on the review and adoption of refined stratigraphic schemes of the Mesozoic deposits of Western Siberia), Novosibirsk: Publ. of SNIIGGiMS, 2004, 114 p.

4. Grigorenko T.V., Savostin G.G., Kalmykov A.G. et al., Domanic oil shale sediments organic matter and saturating fluids characteristics on the territory of the Tatarstan Republic (In Russ.), Georesursy, 2025, V. 27, No. 1, pp. 221–235, DOI: https://doi.org/10.18599/grs.2025.1.25

5. Hantschel T., Kauerauf A.I., Fundamentals of basin and petroleum systems modeling, Springer-Verlag Berlin Heidelberg, 2009, 492 p.

6. Emel’yanenko O.A., Khafizov S.F., Kalmykov G.A. et al., Promising hydrocarbon systems of the Mangyshlak oil and gas basin (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2025, No. 5, pp. 32–37, DOI: https://doi.org/10.24887/0028-2448-2025-5-32-37

Volcanic systems and associated volcanoclastic rocks are complex objects that may contain commercial hydrocarbon deposits. Their importance in the exploration of new oil and gas fields is currently greatly underestimated, and accumulated knowledge remains insufficient. According to published data, the success rate of discovering economically beneficial reserves in these formations is very high, so all examples of development of individual deposits in China, India, Japan, Indonesia, Argentina, and elsewhere require further study. The reservoir properties of these rocks depend on their geological age and position within the geological section, and this criterion should be taken into account when selecting potential analogs. Petrophysical reservoir properties deteriorate with depth to 3200–4000 m, after which they retain their potential to a depth of 5500–6200 m, and likely beyond. The pore space is characterized by a complex structure, which enables high permeability values with relatively low porosity. This creates the potential for the formation of massive natural gas reservoirs, confined by capillary seals, in the central parts of the basins. In the Russian Federation, one of the promising oil and gas basins associated with effusives is the Zeya-Bureya basin, genetically related to the significantly better-studied Songliao basin (China). For the Upper Paleozoic sections of the southeastern Kazakhstan basins, such analogs could be the Sichuan and Junggar oil and gas basins (China), where numerous oil and gas deposits were discovered and are under development.

References

1. Oppenheimer C., Pyle D.M., Barclay J., Volcanic degassing, London: Geological Society, 2003, 420 p.

2. Volcanic rocks and soils: edited by Rotonda T., Cecconi M., Silvestri F., Tommasi P., Boca Raton: CRC Press, 2015, 200 p.

3. Volcanic rocks: edited by Malheiro A.M., Nunes J.C., Boca Raton: CRC Press, 2013, 222 p.

4. Nurbekova R., Smirnova N., Goncharev I. et al., High-quality source rocks in an underexplored basin: The upper Carboniferous–Permian succession in the Zaysan Basin (Kazakhstan), International Journal of Coal Geology, 2023, V. 272, DOI: https://doi.org/10.1016/j.coal.2023.104254

5. Kushnir A.R. et al., Probing permeability and microstructure: Unravelling the role of a low permeability dome on the explosivity of Merapi (Indonesia), Journal of Volcanology and Geothermal Research, 2016, V. 316, pp. 56–71, DOI: https://doi.org/10.1016/j.jvolgeores.2016.02.012

6. Qiquan Ran, Yongjun Wang, Yuanhui Sun et al., Volcanic gas reservoir characterization, Amsterdam: Elsevier, 2014, 604 p.

7. Jiaqi Liu, Pujun Wang, Yan Zhang et al., Volcanic rock-hosted natural hydrocarbon resources: A review, In: Updates in volcanology - New advances in understanding volcanic systems: edited by Nemeth K., 2012, DOI: https://doi.org/10.5772/54587

8. Piao Wu, Dujie Hou, Lanzhu Cao et al., Paleoenvironment and organic characterization of the lower cretaceous lacustrine source rocks in the Erlian basin: The influence of hydrothermal and volcanic activity on the source rock quality, ACS Omega, 2023, V. 8, No. 2, pp. 1885–1991, DOI: https://doi.org/10.1021/acsomega.2c03487

9. Jiyan Li, Xuanlong Shan, Zhe Sun et al., Thermal simulation of basic volcanic fluid influence on different source rocks, Chinese Journal of Geochemistry, 2014, V. 33,

pp. 168–172, DOI: https://doi.org/10.1007/s11631-014-0673-3

10. Zou Caineng, Volcanic reservoirs in petroleum exploration, Amsterdam: Elsevier, 2013, 204 p.

11. Liu Chaoyang, Eugenio Nicotra, Xuanlong Shan et al., The Cretaceous volcanism of the Songliao Basin: Mantle sources, magma evolution processes and implications for the NE China geodynamics – A review, Earth-Science Reviews, 2023, V. 237, DOI: https://doi.org/10.1016/j.earscirev.2022.104294

12. Kontorovich A.E., Ershov S.V., Shestakova N.I. et al., Tectonic structure and history of geological development of the Zeya-Bureya sedimentary basin according to the results of integrated interpretation of drilling and seismic exploration materials (In Russ.), Tikhookeanskaya geologiya, 2024, V. 43, No. 4, pp. 3–22,

DOI: https://doi.org/10.30911/0207-4028-2024-43-4-3-22

13. Rosgeology has assessed the resource potential of the Zeya-Bureinskaya hydrocarbon-rich area in the Amur Region (In Russ.), Neftegaz.RU, 2017, 12 May,

Based on the seismogeological model of the structure of the northern side of the Vilyui hemisyneclise proposed by the authors, the spatial position and features of the occurrence of the Kuonam formation rocks are determined, and the modern boundaries of their distribution are clarified. The absence of rocks of the Kuonam formation in the junction zone of the Vilyui hemisyneclise and the Predverkhoyansky marginal trough was established. The lithological characteristics of the rocks are given, based on the results of drilling a parametric well. The results of 1D basin modeling enabled the assessment of the catagenetic transformation of the organic matter of the Kuonam formation rocks, the current depths of possible localization of oil and gas formation zones were determined. Based on the results of kinematic and dynamic interpretation of the seismic survey results, the physical properties of rocks and their area variation were studied. The zones of permafrost rocks, maximum compaction and minor decompression of rocks are identified. An assumption is made about the relationship between the nature of changes in rock properties and the presence and catagenetic transformation of organic matter. By combining structural, kinematic, and dynamic interpretation data with basin modeling results, the relationship between the nature of changes in rock properties and the catagenetic transformation of organic matter was confirmed. Studying the physical properties of the Kuonam formation's petroleum source rocks using the common depth point method, along with basin modeling, can form the basis for a separate petroleum potential forecast within the Vilyui hemisyneclise.

References

1. Fayzullin G.I., Myachev S.B., Noskova E.S. et al., Alternative title: Petroleum Geology – Theoretical and Applied Studies (In Russ.), Neftegazovaya geologiya. Teoriya i praktika, 2025, V. 20, No. 4, DOI: https://doi.org/10.17353/2070-5379

2. Staroseltsev V.S., Tectonic and oil and gas geological zoning of the southern coast and the adjoining shelf of the Laptev Sea (In Russ.), Geologiya i mineral’no-syryevye resursy Sibiri, 2012, No. 3, pp. 32–37.

3. Gayduk V.V., Vilyuyskaya srednepaleozoyskaya riftovaya sistema (Vilyui Middle Paleozoic rift system), Yakutsk: Publ. of Yakutsk Division of Geophysic Survey of the Siberian Branch of the AS USSR, 1988, 128 p.

4. Gardner G.H.F., Gardner L.W., Gregory A.R., Formation Velocity and Density – the Diagnostic Basics for Stratigraphic Traps, Geophysics, 1974, V. 39, No. 6,

pp. 770–780, DOI: https://doi.org/10.1190/1.1440465

5. Gorlov D.A., Levshunova S.P., Root D.V., Migurskiy S.F., Geopetroleum zoning of Lower-Middle Cambrian Kuonamsky formation in Lena-Tungussky petroleum province (In Russ.), Geologiya nefti i gaza, 2023, No. 6, pp. 67–79, DOI: https://doi.org/10.47148/0016-7894-2023-6-67-79

6. Tetenkin D.D., Germakhanov A.A., Kasparov O.S. et al., The implementation and efficiency assessment of the Federal strategic initiative "Geology. Legend revival"

(In Russ.), Nedropol’zovanie XXI vek, 2022, No. 1(93), pp. 4–11.

The authors of this article analyzed published research from recent years on the discoveries of deep and ultra-deep hydrocarbon accumulations in the Tarim oil and gas basin, including studies conducted prior to drilling ultra-deep wells. The classical understanding of hydrocarbon formation, accumulation, and preservation is described. The article presents data on the reservoirs and oil and gas source rocks associated with deposits in ultra-deep horizons. Selected results from ultra-deep well drilling where liquid hydrocarbons were encountered are presented. The results of geochemical studies conducted in the region are presented, along with the results on the main oil source strata. The results of reconstructing the subsidence model, paleoheat flow history, and heating of the Tabei uplift strata based on well RP7 data are presented. The geothermal regime of the basin is described as one of the most important factors in the formation of hydrocarbons of various phase compositions. The main conclusion from the analysis is that the sedimentary basin began intensive subsidence approximately 10 Ma, and only in the last 5 Ma the oil source rocks subsided more than 2 km and exited the oil window. Nowadays, temperatures at depths of approximately 10000 m do not exceed 190 °C, which contributes to the preservation of liquid hydrocarbons at extremely deep depths.

References

1. Guangyou Zhu, Feiran Chen, Meng Wang et al., Discovery of the Lower Cambrian high-quality source rocks and deep oil and gas exploration potential in the Tarim Basin, China, AAPG Bulletin, 2018, V. 102(10), pp. 1–29, DOI: https://doi.org/10.1306/03141817183

2. Zhu Guangyou, Feiran Chen, Zhiyong Chen et al., Discovery and basic characteristics of the high-quality source rocks of the Cambrian Yuertusi Formation in Tarim Basin, Journal of Natural Gas Geoscience, 2016, No. 27(1), pp. 8–21, DOI: https://doi.org/10.1016/j.jnggs.2016.05.002

2. 3. Guang-You Zhu, Rong Ren, Fei-Ran Che et al., Neoproterozoic rift basins and their control on the development of hydrocarbon source rocks in the Tarim Basin,

NW China, Journal of Asian Earth Sciences, 2017, V. 150, pp. 63–72, DOI: https://doi.org/10.1016/j.jseaes.2017.09.018

4. Yang Zh., Duan Zh., Huang Zh., Section measurement and petroleum geologic evaluation of the Cambrian in the Margin of the Tarim Basin, Kuerle: Research Report of the Petro China Tarim Branch, 2016, pp. 1-332.

5. Zhu Guangyou, Yinghui Cao, Yan Lei et al., Potential and favorable areas of petroleum exploration of ultra-deep marine strata more than 8000 m deep in the Tarim Basin, Northwest China, Journal of Natural Gas Geoscience, 2018, No. 3, pp. 321-337, DOI: https://doi.org/10.1016/j.jnggs.2018.12.002

6. Sun Chonghao, Zhu Guangyou, Zheng Duoming et al., Characteristics and controlling factors of fracture-cavity carbonate reservoirs in the Halahatang area, Tarim Basin (In Chinese), Bulletin of Mineralogy, Petrology and Geochemistry, 2016, V. 35(5), pp. 1028-1036, DOI: https://doi.org/10.3969/j.issn.1007-2802.2016.05.024

7. Li B., Yu M., Wang F. et al., Amorphous nickel hydroxide nanospheres with ultrahigh capacitance and energy density as electrochemical pseudocapacitor materials, Nature Communications, 2013, No. 4(1894), pp. 1-7, DOI: https://doi.org/10.1038/ncomms2932

8. Zhongyao Xiao, Meijun Li, Shaoying Huang et al., Source, oil charging history and filling pathways of the Ordovician carbonate reservoir in the Halahatang Oilfield, Tarim Basin, NW China, Marine and Petroleum Geology, 2016, V. 73, pp. 59–71, DOI: https://doi.org/10.1016/j.marpetgeo.2016.02.026

9. Yang Haijun, Chen Yongquan, Tian Jun et al., Great discovery and its significance of ultra-deep oil and gas exploration in well Luntan-1 of the Tarim Basin, China Petroleum Exploration, 2020, V. 25(02), pp. 62–72, DOI: https://doi.org/10.3969/j.issn.1672-7703.2020.02.007 2020a

10. Yang Haijun, Yu Shuang, Zhang Haizu et al., Geochemical characteristics of Lower Cambrian sources rocks from the deepest drilling of well LT-1 and their significance to deep oil gas exploration of the lower Paleozoic system in the Tarim Basin (In Chinese), Geochimica, 2020, V. 49, pp. 666–682, DOI: https://doi.org/10.19700/j.0379-1726.2021.01.017

11. Jin Z., Cai L., Exploration propects problems and strategies of marine oil and gas in China (In Chinese), Oil and Gas Geology, 2006, V. 27, pp. 722–730.

12. Zhang S., Liang D., Zhu G. et al., Geological foundation of the formation of China’s marine oil and gas fields (In Chinese), Chinese Science Bulletin, 2007, V. 52,

pp. 19–31.

13. Zhi‐Yong Ni, Tie-Guan Wang, Meijun Li et al., An examination of the fluid inclusions of the well RP3-1 at the Halahatang Sag in Tarim Basin, northwest China: Implications for hydrocarbon charging time and fluid evolution, Journal of Petroleum Science and Engineering, 2016, V. 146, pp. 326–339, DOI: https://doi.org/10.1016/j.petrol.2016.04.038

14. Zhu Guangyou et al., Reservoir types of marine carbonates and their accumulation model in western and central China (In Chinese), Shiyou Xuebao = Acta Petrologica Sinica, 2010, V. 31, pp. 871–878.

15. Zhu Guangyou, Zhiyao Zhang, Xiaoxiao Zhou et al., The complexity, secondary geochemical process, genetic mechanism and distribution prediction of deep marine oil and gas in the Tarim Basin, China, Earth-Science Reviews, 2011, V. 198(1-2), DOI: https://doi.org/10.1016/j.earscirev.2019.102930

The Shiranish formation within the central Euphrates graben consists of thick successions of argillites and wackestones enriched in organic carbon. Comprehensive mineralogical, geochemical, and kinetic investigations made it possible to specify the stratigraphic subdivision and to identify the factors controlling the generative potential of these rocks. Based on variations in hydrogen (HI) and oxygen (OI) indices, total organic carbon (TOC) content, and activation energy distributions, the Shiranish formation was divided into lower (LSF) and upper (USF) formations, with the upper member further subdivided into two intervals (USF-1 and USF-2). The USF exhibits higher oil-generating potential (TOC up to 4 %, HI up to 500 mg HC/g TOC) with relatively narrow activation energy distributions, whereas the LSF is characterized by broader activation energy spectra and predominantly gas-generating potential. Mineralogical features, including the presence of ankerite and pyrite, indicate the influence of clay-rich material and significant methanogenesis during early diagenesis. Kinetic modeling revealed differences in predicted maturity temperatures: 136 °C for the USF and 144 °C for the LSF, reflecting facies variations and heterogeneity of the organic matter. These findings provide new insights into the petroleum source rock potential of the Shiranish formation and highlight prospective intervals for future hydrocarbon exploration in the central Euphrates graben.

References

1. Aldahik A., Schulz H.-M., Horsfield B. et al., Crude oil families in the Euphrates Graben (Syria), Marine and Petroleum Geology, 2017, V. 86, pp. 325–342,

DOI: https://doi.org/10.1016/j.marpetgeo.2017.05.030

2. Yousef I., Morozov V.P., El Kadi M., Alaa A., Tectonic and erosion features, and their influence on zonal distribution of the Upper Triassic and the Lower Cretaceous sediments in the Euphrates Graben area, Syria, Journal of Earth Science (China), 2021, V. 32, No. 9, pp. 1500–1515, DOI: https://doi.org/10.5800/GT-2021-12-3-0541

3. Eremin N.A., Zinovkina I.S., Shabalin N.A., Eremin A.N., Oil and gas possibilities of Syria (In Russ.), Geologiya nefti i gaza, 2017, No. 2, pp. 76–82.

4. Yusef I., Morozov V.P., Kadi M.E., Alaa A., Tectonic and erosion features, and their influence on zonal distribution of the Upper Triassic and the lower cretaceous sediments in the Euphrates graben area, Syria (In Russ.), Geodinamika i tektonofizika = Geodynamics & Tectonophysics, 2021, V. 12, No. 3, pp. 608–627,

DOI: https://doi.org/10.5800/GT-2021-12-3-0541

5. Abboud M.S., Philp R.P., Allen J., Geochemical correlation of oils and source rocks from central and NE Syria, Petroleum Geology, 2005, V. 28, pp. 203–218,

DOI: https://doi.org/10.1111/j.1747-5457.2005.tb00080.x

6. Alyaseen, M. Kh., Aani Ya., Oil and gas potential of the Euphrates graben in Syria (In Russ.), Neftegazovoe delo, 2019, V. 17, No. 6, pp. 6–14,

DOI: https://doi.org/10.17122/ngdelo-2019-6-6-14

7. Barrier E., Machhour L., Blaizot M., Petroleum systems of Syria, In: Petroleum Systems of the Tethyan Region, edited by Robertson A., Searle R., AAPG Special Volumes, 2014, pp. 335–378, DOI: https://doi.org/10.1036/13431862M1063612

8. Tucker M., Wright V., Carbonate sedimentology, Oxford: Blackwell Science, 1990, 308 p.

9. Stephen N.E., Svånå T.A., Swart P.K., Uranium depletion across the Permian–Triassic boundary in Middle East carbonates: Signature of oceanic anoxia, AAPG Bulletin, 2008, V. 92, No. 6, pp. 691–707, DOI: https://doi.org/10.1306/02140807095

10. Hallam A., Grose J. A., Ruffell A., Paleoclimatic significance of changes in clay mineralogy across the Jurassic–Cretaceous boundary in England and France, Palaeogeography, Palaeoclimatology, Palaeoecology, 1991, V. 81, pp. 173–187.

11. Espitalie J., Laporte J., Madec M., Marquis F., Rapid method for source rock characterization and for evaluating their petroleum potential and their degree of evolution, Oil & Gas Science and Technology, 1977, V. 32, pp. 23–42.

12. Katz B.J., Elrod L.W., Organic geochemistry of DSDP Site 467, offshore California, Middle Miocene to Lower Pliocene strata, Geochimica et Cosmochimica Acta, 1983, V. 47, pp. 389–396, DOI: https://doi.org/10.1016/0016-7037(83)90261-2

13. Tissot B.P., Welte D.H., Petroleum formation and occurrence, Berlin: Springer, 1984, 699 p.

14. Schenk H.J., Di Primio R., Horsfield B., The conversion of oil into gas in petroleum reservoirs. Part I: comparative kinetic investigation of gas generation from crude oils of lacustrine, marine and fluviodeltaic origin by programmed-temperature closed system pyrolysis, Organic Geochemistry, 1997, V. 26, No. 7–8, pp. 467–481,

DOI: https://doi.org/10.1016/S0146-6380(97)00024-7

Probabilistic assessment of the resource base occupies a central place in the decision-making process at the stages of prospecting and exploration of hydrocarbon deposits. The accuracy of the results of such an assessment directly correlates with the reliability of identifying uncertainty intervals for the calculation parameters and the probability of discovering new deposits, and also affects the determination of the further program of geological exploration work and the calculation of predicted production profiles. In addition to the standard procedures for geological uncertainties evaluation, for example structural framework construction errors (stratigraphic boundaries positions) and fluid contacts, 2D/3D geological models multivariate calculations require accounting variation of lithological boundaries as well as setting trends based on conceptual understanding. This article presents approaches to net pay volume multivariate modeling of lithologically screened deposits confined to the Lower Cretaceous deposits of the Achimov formation and the Middle Jurassic deposits of the Tyumen formation. The developed methods enable taking into account the uncertainties associated with variations in the shape and size of the sedimentary bodies and associated lithological barriers as well as the resolution limitations of geophysical research methods - at the level of parameter map sets. The level of detail of the final maps is comparable to the results of full-scale multivariate calculations based on 3D geological models, but the calculation speed is significantly higher, which is relevant for large-scale exploration projects under tight deadlines.

References

1. Dymochkina M.G., Lezhneva V.A., The impact of assessing the probability of geological success on investment decisions (In Russ.), PRONEFT’’. Professional’no o nefti, 2019, No. 4, pp. 14–19, DOI: https://doi.org/10.24887/2587-7399-2019-4-14-19

2. Esiri A., Jambol D., Ozowe C., Enhancing reservoir characterization with integrated analysis and geostatistical methods, Journal of Multidisciplinary sciences, 2024,

No. 7(2), pp. 168-179, DOI: https://doi.org/10.53022/oarjms.2024.7.2.0038

3. Modelling and Management Course Manual, Edinburgh: Heriot-Watt-University, 2017, 398 p.

4. Perepletkin I.A., Adaptive algorithm for non-structural traps multivariant calculations while net pay volume probabilistic assessment (In Russ.), PRONEFT’’. Professional’no o nefti, 2025, No. 10(4), pp. 40–51, DOI: https://doi.org/10.51890/2587-7399-2025-10-4-40-51

5. Nezhdanov A.A., Seysmogeologicheskiy analiz neftegazonosnykh otlozheniy Zapadnoy Sibiri dlya tseley prognoza i kartirovaniya neantiklinal’nykh lovushek i zalezhey UV (Seismogeological analysis of oil and gas bearing deposits in Western Siberia for the forecasting and mapping of non-anticlinal traps and hydrocarbon deposits): thesis of doctor of geological and mineralogical science, Tyumen’, 2004.

6. Zavala C., Arcuri M., Intrabasinal and extrabasinal turbidites: origin and distinctive characteristics, Sedimentary Geology, 2016, V. 337, pp. 36–54,

DOI: https://doi.org/10.1016/j.sedgeo.2016.03.008

7. Prelat A., Covault J.A., Hodson D.M. et al., Intrinsic controls on the range of volumes, morphologies, and dimensions of submarine lobes, Sedimentary Geology, 2010, V. 232, pp. 66–76, DOI: https://doi.org/10.1016/j.sedgeo.2010.09.010

8. Shanmugam G., Submarine fans: A critical retrospective (1950–2015), Journal of Paleogeography, 2016, V. 5, No. 2, pp. 110–184, DOI: https://doi.org/10.1016/j.jop.2015.08.011

9. Alekhin I.I., Perepletkin I.A., Meshcheryakova A.S., A method for structural framework variation of a multilayer field associated with complicated geology (In Russ.), Aktual’nye problemy nefti i gaza, 2024, V. 15, No. 2, pp. 122–140, DOI: https://doi.org/10.29222/ipng.2078-5712.2024-15-2.art2

10. Perepletkin I.A., Zaboeva A.A., Muzraeva B.Yu., Net pay volume probabilistic assessment technique for lithologically screened traps using the example of Achimov deposits in the northern part of Yamalo-Nenets Autonomous District (In Russ.), Izvestiya Tomskogo politekhnicheskogo universiteta. Inzhiniring georesursov = Bulletin of the Tomsk Polytechnic University. Geo Assets Engineering, 2026, V. 337, No. 6, рр. 7 -24.

11. Dubrule O., Geostatistics in petroleum geology, AAPG Continuing Education Course, 1998, 138 p.

12. Devyat’yarov S.S., Bastrakov A.A., Korepanov A.A. et al., Theoretical basis of frac width increasing for the Achimov tight-oil reserves (In Russ.), PRONEFT’’. Professional’no o nefti, 2023, No. 8(4), pp. 160–168, DOI: https://doi.org/10.51890/2587-7399-2023-8-4-160-168

13. Rose P.R., Risk analysis and management of petroleum exploration ventures, AAPG Methods in Exploration Series, 2001, V. 12, 46 p.,

DOI: https://doi.org/10.1306/Mth12792

14. Jun-Long Liu, Wei Yin, You-Liang Ji et al., Sequence architecture and sedimentary characteristics of a Middle Jurassic incised valley, Western Sichuan depression, China, Petroleum Science, 2018, V. 15, pp. 250–251, DOI: https://doi.org/10.1007/s12182-017-0211-0

15. Viktorova E.M., Zhigulina D.I., Kiselev P.Yu., Klimov V.Yu., New approach to appraise non-structural Tyumen formation traps in the absence of high quality of data

(In Russ.), PRONEFT’’. Professional’no o nefti, 2021, No. 6(3), pp. 43–51, DOI: https://doi.org/10.51890/2587-7399-2021-6-3-43-51

16. Abreu V., Sullivan M., Pirmez C., Mohrig D., Lateral accretion packages (LAPs): an important reservoir element in deep-water sinuous channels, Marine and Petroleum Geology, 2003, V. 20, pp. 631–648, DOI: https://doi.org/10.1016/j.marpetgeo.2003.08.003

The article addresses the challenge of accurate effective thicknesses allocation of thin-layered reservoirs using the example of the PK1 formation within the Pokur deposits of a major field operated by Rosneft Oil Company in Western Siberia. The thin layering and high textural heterogeneity complicate well logging data interpretation, causing persistent discrepancies between intervals classified as non-reservoirs by conventional geophysical logging and observed hydrocarbon inflows during reservoir testing. The key difficulty is that productive layer thicknesses are often below the vertical resolution of standard log measurements, leading to signal averaging and loss of reservoir characteristics. To overcome this problem, the hypothesis proposes enhancing the vertical resolution of geophysical logging methods while maintaining standard reservoir identification criteria. This is achieved by applying deconvolution techniques to processed porosity logs to compensate for instrument blurring and recover high-frequency details. This method enables the identification of thin productive zones within intervals previously classified as non-reservoirs and more accurate characterization of reservoir heterogeneity. Results demonstrate that the improved resolution approach explains hydrocarbon inflows in intervals formerly deemed non-reservoirs, reduces geological risks, and refines reserve estimates. When combined with detailed petrophysical modeling of textural heterogeneity, this methodology offers a robust tool for reservoir characterization and more effective field development planning in complex thin-layered reservoirs.

References

1. Markushina O.S., Model of the geological structure of the Cenomanian hydrocarbon deposit (layers PK1-6) of the North-Komsomolskoye field (In Russ.), Gornye vedomosti, 2006, No. 5(24), pp. 40–46.

2. Akin’shin A.V., A method for determining the area of texture components on photos of core samples of textural inhomogeneous rocks (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2016, No. 1, pp. 28–31.

3. Akin’shin A.V. Efa L.L., Shul’ga R.S., Study of the reservoir potential of texturally heterogeneous reservoirs (In Russ.), Ekspozitsiya Neft’ Gaz, 2024, No. 7(108),

pp. 56–60, DOI: https://doi.org/10.24412/2076-6785-2024-7-56-60

4. Akin’shin A.V., Rodivilov D.B., Vasyutinskiy E.V., Improving the method for the estimation of the portion of clayed interlayers in the heterogeneous-texture reservoirs from well logs (In Russ.), Karotazhnik, 2022, No. 6(320), pp. 30–37.

5. Khabarov A.V., Volokitin Ya.E., Borkent E.Ya., Method for thin-layered reservoir bed porosity evaluation (In Russ.), Karotazhnik, 2009, No. 12(189), pp. 129–142.

6. Flaum C., Galford J. E. Hastings A., Enhanced vertical resolution processing of dual detector gamma-gamma density logs, SPWLA 28th Annual Logging Symposium, June 29–July 2, 1987.

An applied typification of oil and gas accumulation zones (hydrocarbon traps) is proposed based on their location relative to the structural components of Upper Devonian – Lower Carboniferous organogenic buildups in the Kama-Kinel trough system (KKTS) of the Volga-Ural petroleum and gas province (on the example of the Nizhnekamsk trough and its junction zones with the Sarapul and Aktanysh-Chishminsky troughs). The classification is intended for practical identification of productive intervals and cap rocks within organogenic massifs and related facies. Interpretation of seismic surveys, well logging data, test results, and field information, combined with comparison with regional schemes for the typification of organogenic buildups and reef reservoirs, enabled linking morphogenetic type and stratigraphic position of buildups with the components of the petroleum system: reservoir rocks and sealing rocks. Five types of oil and gas accumulation zones (hydrocarbon traps) were determined for the various components of organogenic buildup: intra-reef, supra-reef, sub-reef, peri-reef and mixed. It was found that within the Nizhnekamsk trough, supra-reef and multilayer cases are predominantly identified, whereas intra-reef productivity is localized and requires separate verification based on reservoir properties and sealing rock characterization. Peri-reef bodies are generally the targets for seismic facies prediction and can form reservoirs as well as lateral barriers (facies change zones). The proposed typification scheme sets unified criteria for the comparison of Late Devonian – Early Carboniferous organogenic buildups (reefs, bioherms, carbonate mounds, pinnacles, etc.) and related carbonate and organogenic carbonate systems, and can be used for ranking of prospective targets and exploration planning within the KKTS.

References

1. Kuznetsov V.G., Geologiya rifov i ikh neftegazonosnost’ (Geology of reefs and its oil and gas potential), Moscow: Nedra Publ., 1978, 304 p.

2. Mirchink M.F., Mkrtchyan O.M., Khat’yanov F.I. et al., Rify Uralo-Povolzh’ya, ikh rol’ v razmeshchenii zalezhey nefti i gaza i metodika poiska (Reefs of the Ural-Volga region, its role in the location of oil and gas deposits and search methods), Moscow: Nedra Publ., 1974, 152 p.

3. Mkrtchyan O.M., Verkhnedevonskie rify i ikh rol’ v formirovanii neftenosnykh struktur vostoka Uralo-Povolzh’ya (Upper Devonian reefs and their role in the formation of oil-bearing structures in the east of the Ural-Volga region), Moscow: Nauka Publ., 1964, 118 p.

4. Belyaeva G.V., Volkova K.N., Zhuravleva I.T. et al., Sovremennye i iskopaemye rify. Terminy i opredeleniya: spravochnik (Modern and fossil reefs. Terms and definitions: A handbook), Moscow: Nedra Publ., 1990, 184 p.

5. Larochkina I.A., Kontseptsiya sistemnogo geologicheskogo analiza pri poiskakh i razvedke mestorozhdeniy nefti na territorii Tatarstana (Concept of systematic geological analysis in prospecting and exploration of oil deposits in Tatarstan), Kazan’: FEN Publ., 2013, 232 p.

6. Volkov D.S., Osobennosti i metody izucheniya geologicheskogo stroeniya verkhnedevonsko-kamennougol’nykh otlozheniy severo-vostoka Respubliki Tatarstan i poisk organogennykh postroek v osevoy zone Kamsko-Kinel’skoy sistemy progibov (Features and methods of studying the geological structure of the Upper Devonian-Carboniferous deposits of the northeast of the Republic of Tatarstan and the search for organogenic structures in the axial zone of the Kama-Kinel system of troughs): thesis of candidate of geological and mineralogical science, Moscow, 2008.

7. Nikitin Yu.I., Paleogeographic reconstructions of the Late Devonian sediments deposition in the south of the Volgo-Ural province caused by prospecting for reef oil deposits (In Russ.), Geologiya, geofizika i razrabotka neftyanykh i gazovykh mestorozhdeniy, 2020, no. 8, pp. 4–18, DOI: https://doi.org/10.30713/2413-5011-2018-5-4-11

8. Ahr W.M., Geology of carbonate reservoirs: The identification, description, and characterization of hydrocarbon reservoirs in carbonate rocks, Hoboken: Wiley, 2008, 295 p.

9. Brown R.J. et al., A seismic analysis of differential compaction in a Leduc reef, CREWES Research Report, 1995, V. 7, No. 20, 14 p.

10. Chopra S., Marfurt K.J., Seismic attribute expression of differential compaction, The Leading Edge, 2012, V. 31, No. 12, pp. 1418–1422, DOI: https://doi.org/10.1190/tle31121418.1

11. Lines L.R., Newrick R.T., Carbonate reef interpretation, Fundamentals of Geophysical Interpretation, Tulsa: Society of Exploration Geophysicists, 2004, Ch. 13,

DOI: https://doi.org/10.1190/1.9781560801726.ch13.12

12. Kuznetsov V.G. Zhuravleva L.M., Lithological, biological, and tectonic factors determining the structure of oil-and-gas reservoirs (In Russ.), Litologiya i poleznye iskopaemye = Lithology and Mineral Resources, 2021, No. 4, pp. 349–363, DOI: https://doi.org/10.31857/S0024497X21040042

13. Fortunatova N.K., Shvets-Teneta-Gurii A.G., BushuevaM.A. et al., Methodology of lithologically screened and lithological oil and gas traps prediction in Upper Devonian-Tournaisian and Lower Permian carbonate plays of Eastern Volga-Urals Petroleum Province (In Russ.), Geologiya nefti i gaza, 2019, no. 3, pp. 23–38,

DOI: https://doi.org/10.31087/0016-7894-2019-3-23-38

14. Chikhirin A.A., Sannikov E.O., Vasil’ev D.M. et al., Paleogeographic conditions of formation and search criteria for the oil-bearing capacity of organogenic structures within the Kama-Kinel system of troughs (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2021, No. 9, pp. 28–33, DOI: https://doi.org/10.24887/0028-2448-2021-9-28-33

15. Muslimov R.Kh., Larochkina I.A., Abdullin N.G. et al., Osobennosti geologicheskogo stroeniya, rezul’taty i napravleniya poiskov nefti v Kamsko-Kinel’skoy sisteme progibov na territorii Tatarii (Features of the geological structure, results and directions of oil exploration in the Kama-Kinel trough system in Tatarstan), In: Geologiya i osvoenie resursov nefti v Kamsko-Kinel’skoy sisteme progibov (Geology and development of oil resources in the Kama-Kinel trough system), Moscow: Nauka Publ., 1991, pp. 51–58.

16. Nefedov N.V., Karpov V.B., Aref’ev Yu.M. et al., Geological structure features of Menzelinsky, Timerovsky and Olginsky fields of the Republic of Tatarstan as a result of their genetic nature (In Russ.), Georesursy = Georesources, 2018, V. 20(2), pp. 88–101, DOI: https://doi.org/10.18599/grs.2018.2.88-101

A significant volume of hydrocarbon reserves identified in the pre-Jurassic basement of the Krasnoleninsky arch in Western Siberia is associated with volcanic deposits, which are characterized by a variety of rock types. The petrographic and petrophysical features of these rocks determine their ability to host reservoir fluids. Structural and textural features are determined both by the surface conditions of origin of their formation and secondary alterations. Petrophysical parameters are determined by the material composition and structural-textural features of petrotypes. The average mineralogical density of acidic volcanites is 2,64 g/cm3, with a range of 2,58-2,69 g/cm3. Mineralogical density increases from acidic volcanites to basic volcanites up to 2,79 g/cm3. Porosity and permeability coefficients decrease in this direction, except for a few samples of volcanogenic-sedimentary rocks and medium-composition volcanites. Basic volcanites and terrigenous rocks are non-reservoirs. Porosity and permeability of volcanites increase from lavas to volcanic rocks. At the same time, decompacted lavas have greater porosity and permeability than massive-textured lavas. The conditional boundary between lavas and volcanic rocks in terms of porosity and permeability corresponds to: porosity – 0,12 units, permeability – 0,15·10-3 mkm2. Transformed volcanites occupy an intermediate position between lavas and volcanic rocks. The analysis of petrographic features and petrophysical properties showed that lavas (decompressed varieties), volcanic rocks and transformed volcanites of acidic composition, and much less frequently, volcanogenic-sedimentary rocks and volcanites of intermediate composition are promising in the prospect of their reservoir properties.

References

1. Maleev E.F., Vulkanity (Volcanics), Moscow: Nedra Publ., 1980, 240 p.

2. Kos I.M., Belkin N.M., Kurysheva N.K., Seysmogeologicheskoe stroenie doyurskikh obrazovaniy Rogozhnikovskogo litsenzionnogo uchastka (Seismogeological structure of pre-Jurassic formations of the Rogozhnikovsky license area), Proceedings of VII scientific and practical conference “Puti realizatsii neftegazovogo potentsiala KhMAO” (Ways of realization of oil and gas potential of KhMAO), Khanty-Mansiysk, 02–05 December 2003, Ekaterinburg: IzdatNaukaServis Publ., 2004,

pp. 153–163.

3. Kropotova E.P., Korovina T.A., N Gil’manova.V., Shadrina S.V., Usloviya formirovaniya zalezhey uglevodorodov v doyurskikh otlozheniyakh na Rogozhnikovskom litsenzionnom uchastke (Conditions for the formation of hydrocarbon deposits in pre-Jurassic sediments at the Rogozhnikovsky license area), Proceedings of X scientific and practical conference “Puti realizatsii neftegazovogo potentsiala KhMAO” (Ways of realization of oil and gas potential of KhMAO), Khanty-Mansiysk 13–17 November 2007, Ekaterinburg: IzdatNaukaServis Publ., 2007, pp. 372–383.

4. Kondakov A.P., Efimov V.A., Dobryden' S.V., Reservoirs identifying in the volcanogenic-sedimentary rocks of the northeast edge of Krasnoleninskiy arch based on logging, core study and well testing (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2020, No. 1, pp. 29–34, DOI: https://doi.org/10.24887/0028-2448-2020-1-29-34

5. Dobryden' S.V., Turenko S.K., Semenova T.V., Features of geological interpretation of well logging in volcanogenic deposits (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2024, No. 6, pp. 20–24. – https://doi.org/10.24887/0028-2448-2024-6-20-24

6. Shadrina S.V., Kondakov A.P., New data on the basement of the north-eastern framing of Krasnoleninskiy arch (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2014, no. 11, pp. 94-99.

7. Petrograficheskiy kodeks Rossii. Magmaticheskie, metamorficheskie, metasomaticheskie, impaktnye obrazovaniya (Petrographic Code of Russia. Igneous, metamorphic, metasomatic, impact formations), St. Petersburg, Publ. of VSEGEI, 2008, 200 p.

8. Winchester J.A., Floyd P.A. Geochemical discrimination of diferent magma series and their differentiation products using immobile elements, Chemical Geology, 1977, No. 20, pp. 325–343, DOI: https://doi.org/10.1016/0009-2541(77)90057-2

9. Trusova I.F., Chernov V.I., Petrografiya magmaticheskikh i metamorficheskikh gornykh porod (Petrography of igneous and metamorphic rocks), Moscow: Nedra Publ., 1982, 272 p.

This article is devoted to the multivariate calculation performance analysis as well as practical recommendations development for the use of specific computer configurations depending on a range of factors. The analyzed parameters include the type of calculation (multivariate forecast of a fluid-saturated volume of varying scales in two- and three-dimensional formats during mapping and modeling, as well as various auxiliary calculations, such as dynamic attributes calculation base on seismic data and extracting statistics from a large array of maps) and a number of implementations. Each process was repeatedly calculated on all computer configurations, after which the best, average, and worst results were determined to obtain indicative statistics. The advantages and disadvantages of specific computer configurations based on benchmarking results are presented, trends and dependencies for each type of calculation are identified, and recommendations for selecting optimal workstation parameters are provided. In the vast majority of disciplines, the determining factor for fast calculations is central processing unit performance per 1 core/thread. The amount of random access memory has a lesser impact on calculation speed, but if the maximum allowed amount is exceeded, the calculation process may be interrupted. In addition to selecting the most suitable hardware for geological modeling, software optimization by developers is equally important. Improving algorithms to maximize the efficiency of multiple central processing unit cores and threads and thus significantly increase task performance should be a top priority.

References

1. Zakrevskiy K.E., Geologicheskoe 3D modelirovanie (3D geological modeling), Moscow: Publ of IPTs Maska, 2009, 376 p.

2. Bukatov M.V., Peskova D.N., Nenasheva M.G. et al., Key problems of Achimov deposits development on the different scales of studying (In Russ.), Proneft’. Professional’no o nefti, 2018, no. 2, pp. 16–21, DOI: https://doi.org/10.24887/2587-7399-2018-2-16-21

3. Alekhin I.I. et al., Reserves probabilistic assessment approach involving quantitative geological risks accounting for Achimov deposits with low exploration maturity

(In Russ.), PRONEFT’’. Professional’no o nefti, 2024, No. 9(3), pp. 6–16, DOI: https://doi.org/10.51890/2587-7399-2024-9-3-6-16

4. Perepletkin I.A., Tekhnicheskie resheniya dlya ucheta vertikal’nykh neodnorodnostey razreza v algoritmakh 2D modelirovaniya pri provedenii veroyatnostnoy otsenki (Technical solutions for accounting vertical inhomogeneities in 2D-modeling algorithms during reserves probabilistic estimation), Collected papers “Geologiya v razvivayushchemsya mire” (Geology in the developing world), Proceedings of XVIII International scientific and practical conference of students, postgraduates and young scientists, Perm’: Publ. of Perm State National Research University, 2025, pp. 313–317.

5. Perepletkin I.A. Zakharova O.A., Baza algoritmov veroyatnostnoy otsenki ob»ektov razlichnogo genezisa (A database of algorithms for probabilistic assessment of objects of various origins), Collected papers “Aktual’nye problemy geologii, geofiziki i geoekologii” (Current issues in geology, geophysics and geoecology), Proceedings of XXXVI youth scientific school-conference dedicated to the memory of Corresponding Member of the USSR Academy of Sciences K.O. Kratz and Academician of the Russian Academy of Sciences F.P. Mitrofanov, Publ. of Perm State National Research University, 2025, pp. 61–65.

6. Alekhin I.I. et al., Reserves probabilistic assessment approach for fluvial Upper-Middle Jurassic deposits in the northern part of Tazovsky Peninsula (In Russ.), PRONEFT’’. Professional’no o nefti, 2024, No. 9(4), pp. 15–29, DOI: https://doi.org/10.51890/2587-7399-2024-9-4-15-29

7. Zakrevskiy K.E., Popov V.L., The history of development of 3D geology modeling as a method for studying oil and gas reservoirs (In Russ.), Izvestiya Tomskogo politekhnicheskogo universiteta. Inzhiniring georesursov = Bulletin of the Tomsk Polytechnic University. Geo Assets Engineering, 2021, V. 332, No. 5, pp. 89–100,

DOI: https://doi.org/10.18799/24131830/2021/5/3188

8. Swanson D.C., A new geological volume computer modeling system for reservoir description, SPE-17579-MS, 1988, DOI: https://doi.org/10.2118/17579-MS

9. Istoriya kompanii Roxar (History of Roxar), URL: http://roxar.ru/about-us/history

10. Schlumberger Petrel Deployment guide, 2007, 518 p.

11. IRM. Rukovodstvo pol’zovatelya. TNavigator 25.1. Dizayner Geologii i Modeley (IRM. User’s Guide. TNavigator 25.1. Geology and Model Designer), 2025, 3209 p.

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. Informatsionnaya geologicheskaya sistema GeoMate (GeoMate Geological Information System), URL: https://neftegaz.ru/news/Geological-exploration/236562-gazprom-neft-vnedryaet-informatsionnuyu-geolo...

14. Zinchenko I.A., Analysis of the parallel computing implementation and practical advice to reduce the calculation time of basin models in the PetroMod® software

(In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2023, No. 7, pp. 76–82, DOI: https://doi.org/10.24887/0028-2448-2023-7-76-82

15. Kovalevskiy E.V., Geologicheskoe modelirovanie na osnove geostatistiki (Geological modeling based on geostatistics), Moscow: Publ. of TsGE, 2011, 100 p.

16. Perepletkin I.A., Kosmacheva M.S., Dynamic analysis capabilities for predicting reservoir propagation with a low seismic data maturity (In Russ.), PRONEFT’’. Professional’no o nefti, 2025, No. 10(3), pp. 14–27, DOI: https://doi.org/10.51890/2587-7399-2025-10-3-14-27

The article presents an algorithm for calculating the production profile of an oil well drilled in the Bazhenov formation. In the situation under consideration, direct production profile calculation is complicated due to the following reasons: firstly, there is a lack of long-term historical production that can be used to adjust a production decline curve; secondly, the formation lithology, represented by a subreservoir with permeability less 10-5 μm2, makes calculations based on conventional hydrodynamic simulators highly volatile and unreliable; thirdly, there is a significant difference in the drilling and hydraulic fracturing technologies that were used in the test well and those planned for the further implementation. The calculation presented in this article is based on a short-term production forecast in Kappa software, which subsequently was adjusted for changes in well completion technology and production extrapolation over the entire development period. Data from analogous formations of Russian and American shale oil fields were used for the adjustment. To improve the reliability of the assessment, multiple calculations were performed based on a combination of metrics from the tested well and data from analogous reservoirs. The obtained results were grouped according to the assessment of reliability and, after averaging, were used to form production profiles, conventionally called optimistic, base and pessimistic.

References

1. Calvin J., Pinkerton H., Practical methods for completing the SCOOP Woodford and Sycamore, SPE-223556-MS, 2025, DOI: https://doi.org/10.2118/223556-MS

2. Zhang K., Analyzing impact of fracturing revolution on shale oil well performance in Permian Basin: A review from over 10,000 wells, SPE-220875-MS, 2024,

DOI: https://doi.org/10.2118/220875-MS

3. Gilardone C.R., Canel C.A., Albuquerque L. et al., Vaca Muerta’s productivity and economic performance. 7 years in review, SPE-206344-MS, 2021,

DOI: https://doi.org/10.2118/206344-MS

4. Yu Liang, Lulu Liao, Ye Guo, A Big Data study: Correlations between EUR and petrophysics/engineering/production parameters in shale formations by data regression and interpolation analysis, SPE-194381-MS, 2019, DOI: https://doi.org/10.2118/194381-MS

The article is devoted to evaluating the surfactant polymer flooding technology effectiveness using single-well chemical tracer test technology (SWCTT). Currently, one of the main tasks in the oil industry is the development of enhanced oil recovery (EOR) methods to increase the period of profitable development of fields at a late stage of exploitation of carbonate reservoirs. Surfactant polymer flooding technology is being implemented at the field of RUSVIETPETRO JV LLC in order to increase oil displacement coefficient. This field is characterized by high reservoir temperatures (70 °С), high salinity formation water (209 g/l), and a hydrophobic carbonate rock. The pilot program stage enables to test the selected compositions in the real conditions of the field, to remove existing uncertainties and decide whether to switch to a pilot project or full-scale implementation. To preliminarily assess the effect of injecting a surfactant-polymer composition, a SWCTT is carried out, which enables to estimate the displacement coefficient in the near-wellbore zone by comparing the residual oil saturation before and after injecting the EOR agent. This paper describes an approach to planning and interpretation of SWCTT: well selection, design features, evaluating the effectiveness of injection of a surfactant polymer composition and the description of parameters that affect the correctness of residual oil saturation evaluation. The SWCTT design and interpretation are made using hydrodynamic model. The selected surfactant-polymer composition showed high efficiency, providing an increase in the oil displacement coefficient by 16 %.

References

1. Kruglov D.S., Smirnov A.E., Tkachev I.V. et al., Design of pilot test to evaluating the efficiency of surfactant-polymer flooding in field conditions using single well chemical tracer test (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2021, no. 12, pp. 102–106, DOI: https://doi.org/10.24887/0028-2448-2021-12-102-106. –

EDN: WSNPUN

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. Altynbaeva D.R., Kolosova A.I., Tkachev I.V., et al., Approach to designing and feasibility study of surfactant-polymer flooding implementation at the oil field (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2026, No. 3, pp. 50-55, DOI: https://doi.org/10.24887/0028-2448-2026-3-50-55

4. Patent US3590923A. Method of determining fluid saturations in reservoirs, Inventor: Cooke C.E. Jr.

5. Bolotov A.V., Anikin O.V., Bondar’ M.Yu. et al., Faktory, vliyayushchie na podbor i primenimost’ trasserov v odnoskvazhinnom khimicheskom trassernom teste (Factors affecting the selection and applicability of tracers in a single-hole chemical tracer test), Kazan: Publ. of KFU, 2024, 206 p.

6. AlAbbad M., Balasubramanian S., Sanni M. et al., Single-well chemical tracer test for residual oil measurement: Field trial and case study, SPE-182811-MS, 2016,

DOI: https://doi.org/10.2118/182811-MS

Periodic operation modes of oil producing wells equipped with electric submersible pumps (ESPs) are widely used at Russian oilfields to ensure efficient oil production from low-flow wells, including fields with hard-to-recover reserves. To date, the impact of periodic operation on the reliability of various types of downhole pumping equipment (DPE) remains insufficiently studied. Consequently, there is a need to analyze field data containing information on DPE failures and operating characteristics under different operational modes (continuous and periodic modes) in order to develop evidence-based recommendations for predicting the reliability of ESP systems. This study presents the results of the analysis of operating parameters, daily production metrics, and data of the DPE failure records for ESP-equipped wells at one of the large Western Siberian oilfields over the period from 2020 to 2025 to assess the impact of operational parameters and operating modes of production wells on the reliability of DPE. A new approach was proposed to evaluate various reliability metrics for DPE operated in periodic modes, taking into account the actual rotation time of the ESP in a periodic cycle. Using this approach to field data analysis, survival curves were constructed for a sample of failed ESPs characterized by different periodic cycle parameters. Conclusions and recommendations regarding the analysis of field data for producing wells operating in periodic modes are provided.

References

1. Yakimov S.B., Shportko A.A., Sabirov A.A., Bulat A.V., The influence of concentration of abrasive particles in the produced fluid to the reliability of electric centrifugal submersible pumps (In Russ.), Territoriya Neftegaz, 2017, No. 6, pp. 50–53.

2. Timashev E.O., Khalfin R.S., Volkov M.G., Statistical analysis of the failure times and feed rates of downhole pumping equipment in operating parameter ranges

(In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2020, No. 2, pp. 46–49, DOI: https://doi.org/10.24887/0028-2448-2020-2-46-49

3. Volkov M.G., Smolyanets E.F., Specifics of oil well operation in the conditions of high free gas content in the production stream (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2018, No. 11, pp. 120–124, DOI: https://doi.org/10.24887/0028-2448-2018-11-120-124

4. Mel’nichenko V.E., Otsenka vliyaniya osnovnykh tekhnologicheskikh kharakteristik dobyvayushchikh skvazhin na resurs pogruzhnykh elektrotsentrobezhnykh nasosov (Assessment of the impact of the main technological characteristics of producing wells on the resource of submersible electric centrifugal pumps): thesis of candidate of technical science, Moscow, 2017.

5. Vidineev A.S., Nikiforov O.V., The feasibility of operating the ESP in frequency alternation mode (In Russ.), Neftegaz.RU, 2021, no. 6, pp. 76–78.

6. Likhacheva E.A., Ostrovskiy V.G., Lykova N.A. et al., Oil submersible pumps reliability during cyclic operation (In Russ.), PRONeft. Professional’no o nefti, 2021, V. 6, no. 1, pp. 54–58, DOI: https://doi.org/10.51890/2587-7399-2021-6-1-54-58

7. Makeev A.A., Mishagin S.G., Yur’ev A.N. et al., Investigation of the periodic mode influence of electric centrifugal pumps operation on the underground equipment lifetime (In Russ.), Neftepromyslovoe delo, 2024, no. 7(667), pp. 37–42.

8. Gorid’ko K.A., Fedorov A.E., Khabibullin R.A. et al., The approach to estimating gas separation in a periodic operation mode of a well equipped by an electric submersible pump. Part 1 (In Russ.), Neftepromyslovoe delo, 2025, No. 6(678), pp. 36–47.

9. Yudin E.V., Moiseev K.V., Latypov B.M. et al., The assessment of well modeling quality for wells equipped with electrical submersible pumps operating in periodic short-term operation mode in the OLGA transient flow simulator under limited verified data and restricted telemetry availability (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2025, No. 9, pp. 66–72, DOI: https://doi.org/10.24887/0028-2448-2025-9-66-72

10. Yudin E.V., Shishulin V.A., Grigor’ev I.V. et al., Methodology for calculating the optimal operating cycles of an oil well under intermittent mode taking into account the acceleration and shutdown phases of the electric submersible pump (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2025, No. 12, pp. 92–96,

DOI: https://doi.org/10.24887/0028-2448-2025-12-92-96

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

12. Perel’man O.M., Peshcherenko S.N., Rabinovich A.I., Slepchenko S.D., Metodika opredeleniya nadezhnosti pogruzhnogo oborudovaniya i opyt ee primeneniya (Methodology for determining the reliability of submersible equipment and experience of its application), URL: https://www.novomet.ru/science_files/452610572005.pdf

13. Slepchenko S.D., Otsenka nadezhnosti UETsN i ikh otdel’nykh uzlov po rezul’tatam promyslovoy ekspluatatsii (Evaluation of the ESP reliability and their individual nodes according to the exploitation results of oil fields): thesis of candidate of technical science, Perm’, 2011.

14. M-01.02.01.01-02. Metodicheskie ukazaniya po raschetu MRP, SNO i rassledovaniyu prichin otkazov pogruzhnogo oborudovaniya (Guidelines for calculating the periods between repairs, mean time between failures and investigating the causes of failures of submersible equipment), St. Petersburg, 2021.

15. Lifelines. Survival Analysis, URL: https://lifelines.readthedocs.io/en/latest/Survival%20Analysis%20intro.html#introduction-tosurvival-...

16. Davidson-Pilon C., Lifelines: survival analysis in Python, The Journal of Open Source Software, 2019, V. 4(40), DOI: https://doi.org/10.21105/joss.01317

17. Kaplan E.L., Meier P., Nonparametric estimation from incomplete observations, Journal of the American Statistical Association, 1958, V. 53(282), pp. 457–481,

DOI: https://doi.org/10.2307/2281868

18. Weibull W., A statistical theory of the strength of materials, Generalstabens litografiska anstalts förlag, 1939, 45 p.

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

Integrated oil field modeling necessitates development of an accurate thermodynamic (PVT) reservoir fluid model. The main challenge is associated with handling mixed laboratory data, which requires careful data organization and processing. To address this challenge, a step-wise approach is proposed, that consists of fluid sampling based on quality criteria, multivariate statistical analysis, history match of compositional model based on representative composition, and its further conversion to «Black Oil» model. Special focus is on application of machine learning methods to reveal undetected anomalies in multivariate data to substantially improve model accuracy and minimize the risk of errors. The developed method comprises conventional approaches to data verification (material balance) and advanced methods for analysis and correction of experimental data. Application of the proposed method enabled the creation of PVT model that showed excellent convergence with experimental data obtained using real downhole samples. Implementation of the proposed approach ensures required continuity and consistency of data in the geology – fluid mechanics – borehole – network chain. The proposed method minimizes personal errors during data selection and evaluation, thus significantly improving the quality of input information and ensuring its representativeness. This facilitates more accurate and efficient computing to improve forecast quality at various stages of field development. Hence, development of a reliable PVT model is an important step to improve the efficiency of oil field management process, especially for fields at late stages of development.

References

1. Coats K.H., Coats K.H., Thomas L.K., Pierson R.G., Compositional and Black Oil Reservoir Simulation, SPE-29111-MS, 2013, DOI: https://doi.org/10.2118/29111-MS

2. Watanasiri S., Brule M.R., Starling K.E., Correlation of Phase-Separation Data for Coal-Conversion Systems, AlChE Journal, 1982, V. 28, No. 4, pp. 626–637,

DOI: https://doi.org/10.1002/aic.690280415

3. Ishmuratov T.A., Islamov R.R., Khisamov A.A. et al., Compositional modeling of gas condensate systems of RN-Purneftegaz LLC field (In Russ.), Vestnik Akademii nauk Respubliki Bashkortostan, 2022, V. 45, No. 4(108), pp. 68–82, DOI: https://doi.org/10.24412/1728-5283_2022_4_68_82

4. Ahmed T., Reservoir Engineering Handbook, Houston: Gulf Professional Publishing, 2018, 1650 p.

5. Danesh A., PVT and Phase Behaviour of Petroleum Reservoir Fluids, Amsterdam: Elsevier Science & Technology Books, 1998, 400 p.

6. Whitson C.H., Brule M.R., Phase Behavior, Richardson: Henry L. Doherty Memorial Fund of AIME; Society of Petroleum Engineers, 2000, V. 20, 320 p.

7. Petroleum Resources Management System (PRMS), SPE, 2018, URL: https://millerandlents.com/wp-content/uploads/2020/03/2018-Petroleum-Resources-Management-System-V1.01.pdf

This paper presents the results of a comprehensive experimental study on the influence of wellbore fluids (degassed oil and mineralized water) and asphaltene-resin-paraffin deposit (ARPD) samples on the efficiency of a solvent reagent. In the course of solubility studies, 315 experiments were performed with variations in water cut, solvent/wellbore fluid ratio, and exposure time for ARPD samples taken from nine wells. The solvent efficiency was evaluated using gravimetric analysis and infrared spectroscopy with calculation of aromaticity, aliphaticity, branching, oxidation, and sulfur content coefficients. It was established that solvent efficiency is not a constant characteristic but critically depends on application conditions. Mixing the solvent with degassed oil has a depressive effect on solvent efficiency due to saturation with high-molecular-weight components and asphaltene aggregation. The hypothesis concerning the significant influence of the individual nature of ARPD samples on result variability was confirmed. Under identical treatment parameters, the range of solvent efficiency can be substantial. Water cut acts as a factor stabilizing the ARPD removal process, reducing the negative effect of mixing with oil and decreasing data scatter. The minimum effective contact time between the solvent and deposits was established. To improve the efficiency of reagents for ARPD removal and increase the success rate of well treatments, an improved methodology is proposed that takes into account the effects of three-component interaction: solvent – wellbore fluid – ARPD.

References

1. Sousa A.L., Matos H.A., Guerreiro L.P., Preventing and removing wax deposition inside vertical wells: a review // Journal of Petroleum Exploration and Production Technology, 2019, No. 9, pp. 2091–2107, DOI: https://doi.org/10.1007/s13202-019-0609-x

2. Akhmetov A.F., Nuriazdanova V.F., Gerasimova E.V., Laboratory technique for determination of solvents efficiency of heavy organics depositions, its features and reproducibility evaluation (In Russ.), Bashkirskiy khimicheskiy zhurnal, 2008, V. 15, No. 2, pp. 161–163.

3. Gerasimova E.V., Akhmetov A.F., Desyatkin A.A., Krasil’nikova Yu.V., A laboratory method to estimate the efficiency of solvents of asphalt,, resin and paraffin deposits (In Russ.), Neftegazovoe delo, 2010, No. 1.

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

5. Rogachev M.K., Strizhnev K.V., Bor’ba s oslozhneniyami pri dobyche nefti (Solution of oil production problems), Moscow: Nedra-Biznestsentr Publ., 2006, 295 p.

6. Norouzpour M., Azdarpour A., Santos R.M. et al., Comparative static and dynamic analyses of solvents for removal of asphaltene and wax deposits above- and below-surface at an Iranian carbonate oil field, ACS Omega, 2023, V. 8, No. 28, pp. 25525–25537, DOI: https://doi.org/10.1021/acsomega.3c03149

7. Schramm L.L., Surfactants: Fundamentals and applications in the petroleum industry, N.Y.: Cambridge University Press, 2010, DOI: http://doi.org/10.2307/3515635

8. Ganeeva Yu.M., Nadmolekulyarnaya struktura vysokomolekulyarnykh komponentov nefti i ee vliyanie na svoystva neftyanykh sistem (Supramolecular structure of high-molecular components of oil and its influence on the properties of oil systems): thesis of doctor of chemical science, Kazan’, 2013.

9. Gayfullin T.L., Forecasting the composition and properties of asphaltene-resin-paraffin deposits based on experimental studies (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2026, No. 3, pp. 71–74, DOI: https://doi.org/10.24887/0028-2448-2026-3-71-75

10. Andrea K., Shevlyakov G.L., Outlier detection with boxplots based on new highly efficient robust estimates of scale (In Russ.), Nauchno-tekhnicheskie vedomosti Sankt-Peterburgskogo gosudarstvennogo politekhnicheskogo universiteta. Informatika. Telekommunikatsii. Upravlenie, 2013, No. 5 (181), pp. 39-45.

11. Patent RU2842434C1, ARPD solvent efficiency evaluation method, Inventors: Gus’kova I.A., Akhmadiev R.N., Timerzyanov M.G. et al.

12. Safieva R.Z., Koshelev V.N., Ivanova L.V., IR spectrometry in the analysis of oil and petroleum products (In Russ.), Vestnik Bashkirskogo universiteta, 2008, V. 13,

No. 4, pp. 869–874.

13. Kayukova G.P., Romanov G.V., Lukyanova R.G., Sharipova N.S., Organicheskaya geokhimiya osadochnoy tolshchi i fundamenta territorii Tatarstana (Organic geochemistry of sedimentary strata and basement of the territory of Tatarstan), Moscow: GEOS Publ., 2009, 488 p.

14. Petrova Yu.Yu., Tanykova N.G., Spasennykh M.Yu., Kozlova E.V., The possibility of using IR spectroscopy in the estimation of oil-generating potential of oil shales

(In Russ.), Vestnik Moskovskogo universiteta. Ser. 2 Khimiya = Moscow University Chemistry Bulletin, 2020, V. 61, no. 1, pp. 34–42.

15. Syunyaev Z.I., Safieva R.Z., Syunyaev R.Z., Neftyanye dispersnye sistemy (Oil dispersed systems), Moscow: Khimiya Publ., 1990, 226 p.

16. Tronov V.P., Mekhanizm obrazovaniya smolo-parafinovykh otlozheniy (Mechanism of formation of resin-paraffin deposits), Moscow: Nedra Publ., 1970, 192 p.

17. Ivanova I.K., Shits E.Yu., Kinetic characteristics of dissolution of asphaltene-resin-paraffin deposit (ARPD) components in an aliphatic-aromatic solvent (In Russ.),

Aktual’nye problemy gumanitarnykh i estestvennykh nauk, 2009, No. 6, pp. 24–29.

18. Petrova L.M., Formirovanie sostava ostatochnykh neftey (Formation of the composition of residual oils), Kazan: Fen Publ., 2008, 203 p.

19. Dolomatov M.Yu., Telin A.G., Silin M.A., Neftepromyslovaya khimiya. Fiziko-khimicheskie osnovy napravlennogo podbora rastvoriteley asfal’tosmoloparafinovykh otlozheniy (Oilfield chemistry. Physicochemical principles of targeted selection of solvents for asphalt-resin-paraffin deposits), Moscow: Publ. of Gubkin University,

2011, 67 p.

20. Hofmann I.C., Hutchison J., Robson J.N. et al., Evidence for sulphide links in a crude oil asphaltene and kerogens from reductive cleavage by lithium in ethylamine, Organic Geochemistry, 1992, V. 19, No. 4–6, pp. 371–387, DOI: https://doi.org/10.1016/0146-6380(92)90006-J

21. Taheri-Shakib J., Rajabi-Kochi M., Kazemzadeh E., A comprehensive study of asphaltene fractionation based on adsorption onto calcite, dolomite and sandstone, Journal of Petroleum Science and Engineering, 2018, V. 171, pp. 863–878, DOI: https://doi.org/10.1016/j.petrol.2018.08.024

22. Barré L., Espinat D., Rosenberg E., Scarsella M., Colloidal structure of heavy crudes and asphaltene solutions, Revue de l Institut Français du Pétrole, 1997, V. 52,

No. 2, pp. 161-175, DOI: https://doi.org/10.2516/ogst:1997015

23. Safieva J., Likhatsky V., Filatov V., Syunyaev R., Composition of asphaltene solvate shell at precipitation onset conditions and estimation of average aggregate sizes in model oils, Energy & Fuels, 2010, V. 24, No. 4, DOI: https://doi.org/10.1021/ef900901w

24. Korolev V.K., Iskandarova E.S., Kosach A.V., Safieva R.Z., The effects of different types of dispersants on asphaltene aggregation and on the stability of asphaltene dispersions (In Russ.), Petroleomika = Petroleum Chemistry, 2025, V. 5, No. 1, pp. 130–137, DOI: https://doi.org/10.53392/27823857-2025-5-1-130

Designing foundations for buildings and structures requires a wide range of soil properties defined by the requirements of Set of Rules (SR) 22.13330.2016 and SR 446.1325800.2019. Technical regulations for engineering surveys and design mandate determining soil characteristics through both laboratory methods and field testing directly in the field. Laboratory testing involves modeling natural and man-made processes in a different environment, within a confined space, and with several assumptions. When studying soil properties from borehole samples, it is crucial to consider that drilling and transportation cause core disturbance and decompression, which can distort the real characteristics. Even perfectly extracted samples cannot provide an exact representation of rock strength in its natural state. This is particularly evident when studying soils in Russia's remote regions. Field testing is a complex of operations that includes studying soils in their natural state using specialized instruments and rigs. Consequently, field methods provide more accurate results and more closely model the behavior of loaded foundations within the soil massif. The development and implementation of new field equipment is a vital contribution to the advancement of engineering surveys. Their importance in solving various engineering tasks cannot be overstated, as they provide the most reliable and accurate quantitative characteristics of rock properties in their natural formation and bedding.

References

1. Patent for utility model No. 219786 U1 RF, MPK G01N 3/02, Sharovyy shtamp 1205 sm2 (Ball stamp 1205 cm2), Inventors: Tadzhiev A.P., Aleksandrov A.V.

2. Tsytovich N.A., Mekhanika merzlykh gruntov (Mechanics of frozen soils), Moscow: Vysshaya shkola Publ., 1973, 448 p.

3. Tsytovich N.A., Mekhanika merzlykh gruntov (kratkiy kurs) (Mechanics of frozen soils (short course)), Moscow: Vysshaya shkola Publ., 1983, 288 p.

4. GOST 12248.7-2020. Soils. Determination of the characteristics of strength and deformability of frozen soils by the method of ball stamping.

All technological processes: production, gathering, and treatment of oil, gas, and water necessitate evaluation of the properties of water-oil emulsions that enter oil treatment facilities. As water cut increases and chemical oil production stimulation methods are applied, produced fluids exhibit higher content of stabilizers and solids in water-oil emulsions. This results in formation of highly stable emulsions (intermediate rag layers) characterized by higher resistance to breakdown which hinders oil and water treatment processes. Stabilization of oil treatment operations demands their removal from process facilities to a separate unit or tank for further treatment. Separation of oil field treatment wastes (rag layers) in oil and water requires increased dosages of demulsifiers and special chemicals, higher heating temperatures, addition of other chemical agents as required, and longer settling times. High initial viscosity, multi-component composition of oil field treatment wastes and their property variations are the factors that impede transportation and preparation processes. Opportunities for beneficial applications of such wastes are currently explored. For this purpose, laboratory studies of physical and chemical parameters and rheological properties of oil field treatment wastes from three different sites were conducted. Hydrophobic properties of oil field treatment wastes from these sites were also tested. Based on the results, all three waste samples exhibit good hydrophobic properties.

References

1. Borisov S.I., Petrov A.A., The role of individual components of the high-molecular part of oil in the stabilization of oil emulsions (In Russ.), Neftepromyslovoye delo, 1975, V. 26, pp. 102–112.

2. Petrov A.A., Pozdnyshev G.N., Kolloidnyye stabilizatory neftyanykh emul′siy (Colloidal stabilizers for oil emulsions), Collected papers “Obezvozhivaniye nefti i ochistka stochnykh vod” (Oil dehydration and wastewater treatment), Proceedings of Giprovostokneft, 1971, V. 13, pp. 3–8.

3. Tronov V.P., Vzaimovliyaniye smezhnykh tekhnologiy pri razrabotke neftyanykh mestorozhdeniy (Interaction of related technologies in oil field development), Kazan: Fen Publ., 2006, 735 p.

4. Gubaydulin F.R., Issledovaniye osobennostey formirovaniya vodoneftyanykh emul′siy na pozdney stadii razrabotki neftyanykh mestorozhdeniy i razrabotka tekhnologiy ikh razdeleniya (Study of the formation features of water-oil emulsions at a late stage of oil field development and development of technologies for their separation): thesis of candidate of technical science, Bugul′ma, 2004.

5. Sakhabutdinov R.Z., Kosmacheva T.F., Gubaydulin F.R., Makhmutova G.R., Peculiarities of intermediate layers formation while oil dehydration (In Russ.), Neftepromyslovoye delo, 2009, No. 10, pp. 42–46.

6. Buryukin F.A., Kositsyna A.S., Koval′chuk A.A., Shapovalov P.L., Combating complications: water-oil emulsions, a study of the composition and causes of the formation of stable water-oil emulsions of the intermediate layer in oil treatment plants (In Russ.), Neftegaz.RU, 2020, No. 9, pp. 156–161.

7. Shireyev A.I., Tronov V.P., Ismagilov I.KH., Sakhabutdinov R.Z., Osnovnyye prichiny povysheniya ustoychivosti neftyanykh emul′siy v protsesse dobychi, sbora i vnutripromyslovogo transporta (The main reasons for increasing the stability of oil emulsions during production, collection and in-field transport), Collected papers “Razrabotka i ekspluatatsiya neftyanykh mestorozhdeniy Tatarstana” (Development and exploitation of oil fields in Tatarstan), Proceedings of TatNIPInefti, 2000,

pp. 234–238.

8. Gubaydulin F.R., Kosmacheva T.F., Tronov V.P. et al., Methods of stabilization of oil treating units work (In Russ.), Neftyanoye khozyaystvo = Oil Industry, 2003,

No. 2, pp. 66–69.

9. Fatykhova A.A., Yamaliyev V.U., Problems of intermediate layer in oil reservoir (In Russ.), Neftegazovoye delo, 2019, No. 4, pp. 228–242,

DOI: https://doi.org/10.17122/ogbus-2019-4-228-242

10. Trofimova E.P., Sorokina E.S., Pappel K.KH., Problems of formation and separation of abnormally stable oil emulsions at oil treatment facilities (In Russ.),

Mir nefteproduktov, 2019, No. 7, pp. 6–9.

11. Sakhabutdinov R.Z., Gubaydulin F.R., Ismagilov I.Kh., Kosmacheva T.F., Osobennosti formirovaniya i razrusheniya vodoneftyanykh emul’siy na pozdney stadii razrabotki neftyanykh mestorozhdeniy (Features of formation and destruction of oil-water emulsions at a late stage of oil field development), Moscow: Publ. of

VNIIOENG, 2005, 322 p.

12. Zabbarov R.R., Goncharova I.N., Destruction of highly stable emulsions by a combined method (In Russ.), Vestnik Kazanskogo tekhnologicheskogo universiteta, 2012, V. 15, No. 11, pp. 199–200.

13. Tsyganov D.G., Kompozitsionnyye sostavy dlya protsessov podgotovki ustoychivykh promyslovykh emul′siy (Composite compositions for the processes of preparing stable industrial emulsions): thesis of candidate of technical science, Kazan, 2021.

The following article discusses the design features of a smart decision support system (DSS) for restoring compliance of main pipeline (MP) facilities. At the present time an analysis and assessment of geotechnical survey results for main pipeline facilities, along with decisions on the need for remedial measures to bring them into compliance, are carried out by experts using applicable state and industry standards, specialized software, and geographic information systems. Therefore this process is time-consuming, and the results of such process largely depend on the expert’s qualification. Due to the reasons described above smart DSSs are used to determine the actual and predicted state of MP facilities in geotechnical monitoring tasks and to improve the efficiency of analyzing large datasets on the condition of MP facilities and external factors, as well as forecasting their changes under complex ambient conditions. Based on the requirements for the intended use and operating conditions of artificial intelligence methods together with the classical theory of sets, and after removing restrictions on their application, a generalized structural architecture was developed for a smart, specialized, hybrid DSS, which is operating on the basis of hybrid methods for studying decision-making processes which is aimed at bringing MP facilities into compliance.

References

1. Andreychik A.V., Andreychikova O.N., Prinyatie resheniy v usloviyakh neopredelennosti. Ot metoda analiza ierarkhiy do nechetkikh modeley (Decision making under uncertainty: From analytic hierarchy processing to fuzzy models), Moscow: Lenand Publ., 2021, 800 p.

2. Larichev O.I., Teoriya i metody prinyatiya resheniy (Theory and methods of decision making), Moscow: Logos Publ., 2000, 296 p.

3. L'vovskiy S.M., Printsipy kompleksnogo analiza (Principles of complex analysis), Moscow: Publ. of MTsNMO, 2017, 304 p.

4. Shannon C.E., Raboty po teorii informatsii i kibernetike (Works on information theory and cybernetics): Translation into Russian, Moscow: Izdatel'stvo inostrannoy literatury Publ., 1963, 824 p.

Since 2018, hydrogen energy has been a priority area of scientific and technical development of the State Corporation Rosatom. The Russian nuclear industry has significant technological and research potential for the development of basic methods of hydrogen production. Taking into account the fact that the State Corporation Rosatom is a consistent participant in the climate agenda, the issue of utilization of greenhouse gases generated during hydrogen generation is being considered within the framework of hydrogen projects. One of the most effective ways for CO2 utilization is its injection into deep aquifers. In this study, for the first time the identification of promising territories for the geological placement of CO2 was carried out for the territory of the Central and Volga Federal Districts. The key objectives in the framework of the conducted research were the following: substantiation of the basic criteria for the selection of promising territories and the implementation of zoning based on them. The basic criteria were developed through the analysis of international experience and relevant scientific research in the field of geological CO2 deposition in deep aquifers, consistent with international standards. The work resulted in maps of promising CO2 storage areas with a selection of 12 territories in the Central and Volga Federal Districts.

References

1. IPCC. Climate Change 2022: Mitigation of Climate Change, Contribution of Working Group III to the Sixth Assessment Report of the Intergovernmental Panel on Climate Change, Cambridge University Press, URL: https://esg-library.mgimo.ru/publications/climate-change-2022-mitigation-of-climate-change-summary-f...

2. Global CCS Institute. Global Status of CCS 2024, Melbourne, URL: https://www.globalccsinstitute.com/publications/global-status-of-ccs-2024/

3. CSLF Technology Roadmap 2021, URL: https://www.cslforum.org/cslf/sites/default/files/CSLF_Tech_Roadmap_2021_final_0.pdf

4. Ryabov G.A., Petelin S.A., Vivchar A.N. et al., Technologies for capturing carbon dioxide at thermal power plants, its transportation, beneficial use and disposal

(In Russ.), Ekologiya, energetika, energosberezhenie, 2022, No. 3, URL: https://mosenergo.gazprom.ru/d/textpage/45/837/03-uglekislyj-gaz.pdf

5. Korzun A.V., Stupakova A.V., Kharitonova N.A. et al., Applicability of natural geological objects for storage, disposal and utilization of carbon dioxide (Review)

(In Russ.), Georesursy, 2023, No. 2, pp. 22–35, DOI: https://doi.org/10.18599/grs.2023.2.2

6. Aminu M.D., Ali Nabavi S., Rochelleb Ch.A., Manovic V., A review of developments in carbon dioxide storage, Applied Energy, 2017, V. 208, pp. 1389–1419,

DOI: https://doi.org/10.1016/j.apenergy.2017.09.015

7. Stupakova A.V., Karpushin M.Yu., Korzun A.V., Natural objects for the storage and disposal of carbon dioxide (In Russ.), Nauchnyy zhurnal Rossiyskogo gazovogo obshchestva, 2023, No. 2(38), pp. 42–49, DOI: https://doi.org/10.55557/2412-6497-2023-2-42-49

8. Chadwick A., Arts R., Bernstone C. et al., Best practice for the storage of CO2 in saline aquifers: observations and guidelines from the SACS and CO2STORE projects, Petroleum Geoscience, 2008, V. 14, pp. 197–211.

9. Bachu S., Screening and ranking of sedimentary basins for. sequestration of CO2 in geological media, Environmental Geology, 2003, V. 44(3), pp. 277–289,

DOI: https://doi.org/10.1007/s00254-003-0762-9

10. Sayegh S.G. et al., Rock/Fluid interactions of carbonated brines in a sandstone reservoir: Pembina Cardium, Alberta, Canada, SPE-19392-PA, 1990,

DOI: https://doi.org/10.2118/19392-PA