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You are holding in your hands the first issue of the magazine, published in 2025, a unique year for our magazine. The magazine turns 105 years old. We will celebrate this date on its pages together with you, dear readers. Along with new scientific and technical articles that are traditionally relevant and have undergone strict editorial selection, we have prepared for you a special series of articles dedicated to the innovative development of the industry over the past 100 years. Step by step, we will recall how ideas were born, important technological solutions were developed and implemented, and what difficulties and mistakes representatives of previous generations of oil workers, geologists, engineers, gas workers, and other industry specialists had to overcome. Thanks to such materials, one can see how scientific and technical progress has developed and scientific thought has been improved, and what achievements and discoveries are in demand today, which our authors have written about and are writing about in articles, serve as the basis for the development of the Russian fuel and energy complex.
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Editor-in-chief V.N. Zvereva

The article presents the results of the structural uncertainties assessment of sector geological models of the VK1 reservoir of the Kamennoe license area (Krasnoleninsky field, Krasnoleninsky arch, Western Siberia) according to production drilling data. The depth uncertainty of the reservoir top is the critical uncertainty of geological modeling. It is determined that it is described by a normal distribution with estimated parameters. The obtained distribution is of significant practical importance, since it enables to estimate the probability of the reservoir top to be above a certain depth in the oil-water zone. The uncertainty of the reservoir top angle significantly affects the selection of angles for horizontal wells drilling. To solve this problem, the authors formulated the concept of the critical zenith angle (CZA), which defines the corridor of the drilling angles. As a result, it was found that outside the fault zones, the CZA can be assumed to be equal to 1,1 degrees, and in the fault zones – 3,3 degrees. Erroneous definitions of the fault amplitudes lead to a decrease of a horizontal well drilling through the reservoir. Non-confirmation of the amplitude even at 2 m is critical. The probability of getting such an error is 33 %. Thus, comparing the results of geological modeling based on prospecting and exploration wells with the results of production drilling is a reliable source of information about the structural uncertainties of the initial geological model. The results obtained are recommended to be taken into account when setting up production drilling in neighboring areas.

References

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

2. Kazanskaya D.A., Aleksandrov V.M., Belkina V.A., Geological modelling of vikulovskaya suite production deposits (In Russ.), Izvestiya Tomskogo politekhnicheskogo universiteta. Inzhiniring georesursov = Bulletin of the Tomsk Polytechnic University, 2019, V. 330, no. 7, pp. 195–207,

DOI: https://doi.org/10.18799/24131830/2019/7/2195

3. Likhoded I.A., Avdonin Yu.E., Reshetnikova D.S. et al., Efficient involvement in the development of remaining oil of the edge zones of the Vikulovskaya formation of the Krasnoleninskoye oil and gas condensate field (In Russ.), Territoriya Neftegaz, 2021, no. 3–4, pp. 66–74.

4. Ovcharova L.P., Justification of optimal parameters of development systems for horizontal wells in the Vikulov formation of the «K» field, Meridian, 2020, no. 12 (46), pp. 174–176.

5. Tsvetkova P.A., Fedulov V.V., Sautkin R.S., New approaches to the development of thin-layered undersaturated reservoirs (Vikulovskaya series of the Krasnoleninskiy dome of the Frolovskaya petroleum area) (In Russ.), Vestnik Moskovskogo universiteta. Ser. 4, Geologiya = Moscow University Geology Bulletin, 2021, no. 1,

pp. 71–78.

6. Dubrule O., Geostatistics for seismic data integration in Earth models, Tulsa, Society of Exploration Geophysicists & European Association of Geoscientists and Engineers, 2003, 281 p.

7. Yanevits E.A., Lapkovskiy V.V., Lebedev M.V., Stokhasticheskoe modelirovanie strukturnykh neopredelennostey kak osnova veroyatnostnoy otsenki resursov uglevodorodov (Stochastic modeling of structural uncertainties as a basis for probabilistic assessment of hydrocarbon resources), Proceedings of XXV scientific and practical conference “Puti realizatsii neftegazovogo potentsiala KhMAO” (Ways of realization of oil and gas potential of KhMAO), Khanty-Mansiysk, 23–26 November 2021, Khanty-Mansiysk, 2022, pp. 154-164.

The most geologically complex ranges in Western Siberia are the deposits of the Neocomian wedge-formed complex. The Neocomian range is promising in terms of oil and gas and is the main target for the fields being developed in the region. As a result of seismic facies and dynamic analysis of 3D seismic survey materials, with generalization of core and field geophysical data, a presence of large landslide bodies in the wedge-formed part of the Neocomian complex was revealed, due to the growth of local structures and active tectonic processes. The formation of interest is represented by a series of formation members, within the boundaries of which several dozen hydrodynamically isolated hydrocarbon deposits were identified. In the range of target reflecting horizons, spectral decomposition was calculated, the results were used to identify promising objects associated with paleo-flows; maps of effective thicknesses were constructed for individual formation members; areas of clayization and absence of sediments were mapped. The boundaries of structural- lithological deposits and lithological traps were clarified. The results of the geometrization of deposits within each of the identified reservoir bodies and the forecast of the distribution of effective oil-bearing thicknesses enabled to estimate geological oil reserves and refine geological models for the production wells placement. The results of work on the forecasting and geometrization of productive sand bodies in the slope part of the Neocomian complex using 3D seismic materials are the main sources of information for refining geological models, reliable assessment of hydrocarbon reserves and design of production drilling.

References

1. Bembel’ S.R., Geologiya i kartirovanie osobennostey stroeniya mestorozhdeniy nefti i gaza Zapadnoy Sibiri (Geology and mapping of structural features of oil and gas fields in Western Siberia), Tyumen: Publ. of TIU, 2016, 216 p.

2. Atlas mestorozhdeniy nefti i gaza Khanty-Mansiyskogo avtonomnogo okruga – Yugry (Atlas of oil and gas fields of Khanty-Mansi Autonomous District - Yugra): edited by Volkov V.A., Shpil’man A.V., Tyumen’: Publ. of V.I. Shpilman research and analytical Centre for the rational use of the subsoil, 2013, 236 p.

3. Zharkov A.M., Non-anticlinal hydrocarbon traps in the Lower Cretaceous clinoform strata of Western Siberia (In Russ.), Geologiya nefti i gaza, 2001, no. 1, pp. 18-23.

4. Kurasov I.A., Romanov D.V., Khasanova K.A. et al., Geological structure and drilling features of Lower Cretaceous Neocomian landslide mass transport deposits

(In Russ.), Neft’. Gaz. Novatsii, 2023, no. 2(266), pp. 47-52.

5. Zakrevskiy K.E., Nassonova N.V., Geologicheskoe modelirovanie klinoform neokoma Zapadnoy Sibiri (Geologic modeling of the West Siberian Neocomian clinoforms), Tver’: GERS Publ., 2012, 79 p.

6. Bembel’ S.R., Exploration of local hydrocarbons deposits based on their relationship to the geodynamics in the Middle Ob (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2013, no. 12, pp. 90–94.

In recent years, it has become increasingly important to develop hard-to-recover reserves concentrated in reservoirs with complex structures. Such reservoirs cannot be identified by standard open porosity boundary values due to the need to substantiate the pore space model, the porosity estimation model based on well logs and the boundary value for different types of reservoirs. Nuclear magnetic logging enables to identify all reservoir types in a section because its readings depend primarily on the free fluid content of the rock, and it directly estimates the effective porosity in the section. The article proposes a method of effective porosity modeling according to the data of radioactive complex of geophysical surveys of wells using machine learning methods, on the data of actual measurements of nuclear magnetic logging, in the section of the Achimov strata. The application of machine learning methods enables to take into account the variability of initial data and provides a more detailed description of the areas of log curve extrema compared to linear models. The peculiarity of the approach is the use of ensemble of neural network models and decision tree scaffolding. The approach enabled the authors to further identify reservoir intervals, re-evaluate effective thicknesses and consider the prospects of the studied strata.

References

1. Khanin A.A., Porody-kollektory nefti i gaza neftegazonosnykh provintsiy SSSR (Reservoir rocks of oil and gas of the USSR petroliferous provinces), Moscow: Nedra Publ., 1973, 304 p.

2. Bulgakov R.B., Issledovaniya geologicheskogo razreza skvazhin (Geological section studies of wells), Part 2, Ufa: Informreklama Publ., 2010, 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. Coates G.R., Xiao L., Prammer M.G., Nuclear magnetic resonance. Principles and application, Houston: Halliburton Energy Service, 1999, 346 p.

5. Privalova O.R., Gadeleva D.D., Minigalieva G.I. et al., Well logging interpretation for Kashir and Podolsk deposits using neural networks (In Russ.), Neftegazovoe delo, 2021, V. 19, no. 1, pp. 69–76, DOI: http://doi.org/10.17122/ngdelo-2021-1-69-76

6. Mitchell T.M., Machine learning, McGraw-Hill, 1997, 414 p.

7. Hamada G., Ahmed E., Chao N., Artificial neural network (ANN) prediction of porosity and water saturation of shaly sandstone reservoirs, Advances in Applied Science Research, 2018, no. 8, pp. 26-31, URL: https://www.primescholars.com/articles/artificial-neural-network-ann-prediction-of-porosity-and-water-saturation-of-shaly-sandstone-reservoirs.pdf

Features of regional geodynamic conditions for the development of the North-West Caspian Sea territory at the latest stage of geological history and their important role in the hydrocarbon deposits formation (young age of structures and deposits, connection with the fault system) are shown in the article. Modern ideas about the formation of oil and gas deposits in the North-West Caspian Sea due to long-distance lateral migration of hydrocarbons (there are no conditions for the formation of oil and gas at their location) are given. These studies are aimed at establishing the main channels of the newest long-distance lateral hydrocarbons migration through a complex analysis of geochemical and neotectonic (morphometric) data. Within the North-West Caspian Sea a fault system was determined, which experiences neotectonic activity and detailed analyses are given. Five different groups of oils have been established, according to the different isotope composition of carbon oils, indicating five sources of hydrocarbon generation. It was established that in the history of oils there were no cardinal changes in the conditions of their existence, on the basis of homogeneous isotope composition of oil fractions. For the first time, the main channels of long-distance newest lateral hydrocarbons migration have been mapped within the North-West Caspian Sea, according to the established «kinship» of oils and structure of newest fault system.

References

1. Kas’yanova N.A., Sovremennaya prostranstvenno-vremennaya migratsiya tektonicheskoy napryazhennosti v zemnoy kore Kavkaza i Predkavkaz’ya (Modern spatio-temporal migration of tectonic tension in the earth’s crust of the Caucasus and Ciscaucasia), In: Obshchaya i regional’naya geologiya, geologiya morey i okeanov, geologicheskoe kartirovanie (General and regional geology, geology of seas and oceans, geological mapping), Moscow: Geoinformmark Publ., 1994, no. 3, pp. 1–15.

2. Kas’yanova N.A., Abramova M.E., Gayrabekov I.G., Horizontal deformations of the Eastern Caucasus based on high-precision geodetic measurements (In Russ.), Geotektonika, 1995, no. 2, pp. 86–90.

3. Kas’yanova N.A., New concept for the structure and formation of the North Caspian Rakushechno-Shirotnyi swell (In Russ.), Geologiya nefti i gaza = The journal Oil and Gas Geology, 2017, no. 1, pp. 28–35.

4. Agzyamov K.G., Bagov L.S., Makhonin M.V., Paleotektonicheskiy analiz podnyatiy Khvalynskoe i “170 km” (Paleotectonic analysis of Khvalynske and 170 km upheavals), Collected papers “Geologiya, burenie i razrabotka neftyanykh mestorozhdeniy Prikaspiya i Kaspiyskogo morya” (Geology, drilling and development of oil deposits of the Caspian Sea and the Caspian Sea), 2003, V. 61, pp. 132–136.

5. Kas’yanova N.A., The role of young fracturing in the formation and spatial distribution of hydrocarbon deposits in the North-Western Caspian Sea (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2018, no. 5, pp. 36–39, DOI: http://doi.org/10.24887/0028-2448-2018-5-36-39

6. Repey A.M., Kas’yanova N.A., Bagov L.S., O neotektonicheskom kriterii neftegazonosnosti akvatorii Srednego i Severnogo Kaspiya (On the neotectonic criterion of oil and gas potential of the waters of the Middle and Northern Caspian), Collected papers “Geologiya, neftegazonosnost’ i osvoenie resursov Nizhnego Povolzh’ya i akvatorii Kaspiya” (Geology, oil and gas potential and development of resources of the Lower Volga region and the Caspian Sea), 2009, V. 68, pp. 57–59.

7. Ostroukhov S.B., Bochkarev V.A., Vorontsov R.A. et al., Nekotorye aspekty formirovaniya zalezhey uglevodorodov mestorozhdeniya im. V.P. Filanovskogo (Some aspects of the formation of hydrocarbon deposits of the V.P. Filanovsky), Collected papers “Voprosy osvoeniya neftegazonosnykh basseynov” (The issues of development of oil and gas basins), 2008, V. 67, pp. 63–74.

8. Ostroukhov S.B., Bochkarev V.A., Geokhimicheskiy analiz protsessov formirovaniya zalezhey UV Srednekaspiyskogo neftegazonosnogo basseyna (Geochemical analysis of the processes of formation of hydrocarbon deposits of the Middle Caspian oil and gas basin), Proceedings of All-Russian scientific conference “Uspekhi organicheskoy khimii” (Advances in Organic Chemistry), Novosibirsk: Publ. of IPGG SB RAS, 2010, pp. 251–255.

9. Frolov E.B., Kas’yanova N.A., Geochemical indicators of the migration of oil in the Eastern Fore-Caucasus on the basis of the fractionation of carbazoles (In Russ.), Vestnik Moskovskogo universiteta. Ser.4. Geologiya = Moscow University Bulletin. Series 4. Geology, 1997, no. 1, pp. 40–46.

10. Bochkarev A.V., Ostroukhov S.B., Bochkarev V.A., Trudnoizvlekaemye nefti Srednego Kaspiya (Hard-to-recover oils of the Middle Caspian), Collected papers “Voprosy osvoeniya neftegazonosnykh basseynov” (Issues of development of oil and gas basins), 2008, V. 67, pp. 197–199.

The present research was conducted within the scope of study of Lower Carboniferous sediments of southeastern slope of North Tatar Arch in the Republic of Tatarstan. The study area covers the Nizhnekamsk Uncompensated Trough as a part of Kamsko-Kinel Troughs System. In the course of this study, a comprehensive analysis of well logs, seismic and core data was performed. An object of special interest is the interval with uncharacteristic changes in lithology and thickness of Tournaisian sediments, the so-called Saraylin series, identified by well logging and core data. The Saraylin series is a peculiar lithologic interval in the Lower Carboniferous with increased organic matter content, which is confined to sediments from the lower boundary of the Tournaisian Stage to the bottom of overlying Tournaisian carbonate rocks or terrigenous sediments of another (post-Tournaisian) age. Seismic interpretation revealed clinoform complexes in the northern flank structural-facies part of the Trough, while no similar sediments were observed within the southern flank of Nizhnekamsk Uncompensated Trough (within the study area). Sedimentation pattern is proposed to explain the structural differences between two flanks. Then sequential analysis was used to identify cyclites, sequences, and tracts which enabled to reproduce the sedimentation history of Nizhnekamsk Uncompensated Trough flanks and refine the stratigraphic model of this part of the Trough.

References

1. Gutman I.S. et al., Identification of macrostructure features in Lower Carboniferous and Upper Devonian deposits: Kama-Kinel’sky trough system in Samara oblast and Republic of Bashkortostan (In Russ.), Geologiya i nedropol’zovanie, 2021, no. 1, pp. 38-51.

2. Fortunatova N.K. et al., New type of non-traditional hydrocarbon exploration objects in western Tatarstan (In Russ.), Georesursy, 2005, no. 1, pp. 13-14.

3. Юнусов М.А., Валеева Р.Т., Викторов П.Ф., Строение и эволюция Камско-Кинельских прогибов территории Башкирской АССР и основные направления геолого-разведочных работ в них в XII и XIII пятилетках (The structure and evolution of the Kama-Kinel troughs of the territory of the Bashkir ASSR and the main directions of geological exploration work in them in the 12th and 13th five-year plans), Proceedings of ИГиРГИ, Moscow: Наука Publ., 1991, pp. 44–51.

4. Gabdullin R.R., Kopaevich L.F., Ivanov A.V., Sekventnaya stratigrafiya (Sequential stratigraphy), Moscow: MAKS Press Publ., 2008, 113 p.

5. Vail P.R., Mitchum R., Thompson S., Seismic stratigraphy and global changes of sea level, Part 4: Global cycles of relative changes of sea level, In: Seismic stratigraphy – Applications to hydrocarbon exploration: edited by Payton C.E., Tulsa: American Association of Petroleum Geologists, 1977, pp. 83-97

6. Posamentier H.W., Allen G.P., Siliciclastic sequence stratigraphy: Concepts and applications, SEPM, Concepts Sedimentol. Paleontol., 1999, V. 7, 250 p.

7. Van Wagoner J.C., Mitchum R.M., Campion K.M.,
Rahmanian V.D., Siliciclastic sequence stratigraphy in well logs, cores, and
outcrops, Tulsa, Oklahoma, American Association of Petroleum Geologists, 1990.

Based on new geological and geophysical data obtained in recent years, the types of Lower Carboniferous sections were updated, and the boundaries of their distribution were refined within the southeastern slope of the North-Tatarian Arch in the Republic of Tatarstan. A.K. Shelnova identified four typical Lower Carboniferous sections in 1966: Saraylinsky, Aktashsky, Kabyk-Kupersky and Saitovsky types. Using well geophysical survey data and core material studies, reference charts were created for each section type, allowing the identification of new variations: Kabyk-Kupersky type 1, Kabyk-Kupersky type 2, and a transitional type, which were previously included into the Kabyk-Kuper section type. As a result, the definition of the Saraylinsky formation was refined. It represents a complex of carbonate-siliceous-terrigenous rocks with high organic matter content, extending from the lower boundary of the Tournaisian stage to the base of overlying Tournaisian carbonate rocks or terrigenous deposits of a different (post-Tournaisian) age. The stratigraphic position of the Saraylinsky formation within the Lower Carboniferous and its high organic matter content were established through lithological, bio-sedimentological, and paleontological core studies from two wells: one located in the axial part of the Nizhnekamsk Trough and the other on the northern flank of the trough. For the first time, seismic data enabled the stratification and tracking of the reflecting horizon associated with the top of the Saraylinsky formation within the Nizhnekamsky Trough of the Kama-Kinel system. The revision of section types and distribution boundaries of Lower Carboniferous deposits enhances and expands the understanding of the structural-facies zonation of the region.

References

1. Shel’nova A.K., Zheltova A.N., Bludorova E.A., Types of Lower Carboniferous sections developed in the territory of the Tatar ASSR (In Russ.), Doklady AN SSSR, 1966, V. 171, no. 2, pp. 435–438.

2. Fortunatova N.K. et al., Stratigrafiya nizhnego karbona Volgo-Ural’skogo subregiona (materialy k aktualizatsii stratigraficheskoy skhemy) (Lower Carboniferous stratigraphy of the Volga-Ural subregion (a to updating the stratigraphic scheme)), Moscow: Publ. of VNIGNI, 2023, 288 p.

3. Gubareva V.S., Kamennougol’naya sistema (Carboniferous system), In: Geologiya Tatarstana: Stratigrafiya i tektonika (Geology of Tatarstan: Stratigraphy and Tectonics), Moscow: GEOS Publ., 2003, pp. 103–124.

4. Silant’ev V.V. et al., Visean terrigenous sediments of the South Tatar Arch (Volga-Urals oil and gas bearing province) – multifacial filling of the karst surface of the Tournaisian isolated carbonate platform (In Russ.), Georesursy = Georesources, 2023, V. 25, no. 4, pp. 3–28, DOI: https://doi.org/10.18599/grs.2023.4.1

5. Nazimov N.A. et al., Selection of logging suite to identify promising intervals in hard-to-recover reserves (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2024, no. 7, pp. 6–10, DOI: https://doi.org/10.24887/0028-2448-2024-7-6-10

Terrigenous Devonian deposits of the Volga-Ural oil and gas province are characterized by features of geological structure and oil content different from the overlying deposits of the Paleozoic sedimentary cover. By combining new and traditional types of laboratory research in the study of quartz sandy-siltstone reservoir rocks of the Devonian terrigenous strata, new data on the material composition and size of minerals contained in the pelitic fraction were obtained. In addition to clay and other most common minerals of this group, microcrystalline quartz and other non-radioactive minerals of other origins are found in certain lithological-facial and tectonic conditions. They are often indeterminable by standard field geophysical surveys. The percentage of the clay component increases when carrying out particle size distribution. Their account in the general balance of the pelitic fraction distorts the forecast of filtration-capacitive and other properties of reservoirs, pointing to a number of existing limitations in determining petrophysical criteria by laboratory methods. Quartz microcrystals have been identified in sections of the terrigenous Devonian for the first time. Their formation is presumably associated with dynamic movement and the subsequent epigenetic impact of mineralized and hydrothermal waters moving along tectonic faults. Thus, the mineralogical composition of the pelitic fraction, determined from granulometry data using the sieve method, has no relationship with the measured filtration and capacitance properties. In the case of post-sedimentary transformations of sandy reservoirs, in particular the Pashi horizon, methods for determining the granulometric and mineral composition, using X-ray phase analysis equipment and scanning electron microscopy are most effective.

References

1. Frolov V.T., Litologiya (Lithology), Part 1, Moscow: Publ. of MSU, 1992, 336 p.

2. Khusainova A.M., Gubaydullina A.A., Burikova T.V. et al., Reservoir classification based on petrophysical properties of Devonian siliciclastic sediments, Russian Platform, Republic of Bashkortostan (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2018, no. 4, pp. 22–25, DOI: https://doi.org/10.24887/0028-2448-2018-4-22-25

3. Aliev M.M., Batanova G.P., Khachatryan R.O. et al., Devonskie otlozheniya Volgo-Ural’skoy neftegazonosnoy provintsii (Devonian sediments of the Volga-Ural oil and gas province), Moscow: Nedra Publ., 1978, 216 p.

4. Lozin E.V., Geologiya i neftenosnost’ Bashkortostana (Geology and oil content of Bashkortostan), Ufa: Publ. of BashNIPIneft’, 2015, 704 p.

5. Gorozhanina E.N., Pazukhin V.N., Gorozhanin V.M., Voykina Z.A., Biostratigraphy and lithofacies of the Middle-Upper Devonian in the Ayazovo oil field (In Russ.), Litosfera, 2023, V. 23(1), pp. 68–91, DOI: https:// doi.org/10.24930/1681-9004-2023-23-1-68-91

6. Silant’ev V.V., Validov M.F., Miftakhutdinova D.N. et al., Sedimentation model of the middle Devonian clastic succession of the South Tatar Arch, Pashyian Regional stage, Volga-Ural Oil and Gas Province, Russia (In Russ.), Georesursy, 2022, no. 24(4), pp. 12–39, DOI: https://doi.org/10.18599/grs.2022.4.2

7. Tikhiy V.N., Devonskiy period (Devonian period), In: Istoriya geologicheskogo razvitiya Russkoy platformy i ee obramleniya (History of the geological development of the Russian platform and its framework), Moscow: Nedra Publ., 1964, 252 p.

8. Khamzin A.Z., Yurganov Yu.M., Yaushev R.S., Zakonomernosti rasprostraneniya peschanykh porod v terrigennoy tolshche Bashkirskogo svoda (Patterns of distribution of sand rocks in the terrigenous strata of the Bashkir arch), Proceedings of UfNII, 1971, V. 29, pp. 90–106.

9. Nalivkin D.V., Uchenie o fatsiyakh (The doctrine of facies), Moscow: Publ. of USSR AS, 1955, 534 p.

10. Gassanova I.G., Kaleda G.A., O pribrezhnykh akkumulyativnykh peschanykh telakh pashiyskogo gorizonta vostochnogo sklona Tatarskogo svoda (On the coastal accumulative sand bodies of the Pashiysky horizon of the eastern slope of the Tatar arch), Proceedings of VNIGNI, 1972, V. 121, pp. 31–44.

11. Afanas’ev V.S., Nadezhkin A.D., Masagutov R.Kh., On the prospects for identifying non-anticlinal traps in the terrigenous Devonian deposits of the Bashkir arch

(In Russ.), Geologiya nefti i gaza, 1987, no. 4, pp. 16–20.

12. Danilova T.E., Analiz porod neftegazonosnykh gorizontov paleozoya RT. Terrigennye porody devona i karbona (Analysis of oil and gas bearing rocks of the Paleozoic of the Republic of Tatarstan. Terrigenous rocks of the Devonian and Carboniferous), Kazan: Pluton Publ., 2015, 440 p.

13. Masagutov R.Kh., Nikolaev A.A., Komilov D.U., Nigmatzyanova A.M., Connection between tectonic disturbances and oil content and epigenesis of Devonian terrigenous reservoirs in the east of the East European Platform (on the territory of the Republic of Bashkortostan) (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2024, no. 7, pp. 70–74, DOI: https://doi.org/10.24887/0028-2448-2024-7-70-74

14. Worden R.H., French M.W., Mariani E., Amorphous nanofilms result in growth of misoriented microcrystalline quartz cement maintaining porosity in deeply buried sandstones, Geology, 2012, V. 40(2), pp. 179–182, DOI: https://doi.org/10.1130/g32661

Well testing is the most important tool for determining the filtration and capacity properties of formations, studying their geological structure and efficient management of oil field development. Traditional methods (the pressure build-up) require the stop of production, which reduces economic efficiency, especially in mature fields. The article proposes new models for well testing interpretation of wells operating with a variable flow rate. New approaches enable to conduct well testing without stopping wells, which minimize production losses and increase the profitability. A model of a closed rectangular formation with impermeable boundaries and a model of an infinite formation with dual porosity or permeability are considered. Various filtration regimes are described: radial, pseudo-steady-state in a closed formation, and transient processes in reservoirs with dual porosity and permeability. One aspect of the work is the application of the superposition principle to obtain a solution to the piezoconductivity equation under specified conditions and subsequent analysis of bottomhole pressure. This enables to interpret data highly accurate even under changing production rates. The results of such interpretation are compared with the results of classical interpretation using the best fit method. These approaches can be used in mature fields and in new ones, providing increased accuracy of formation property assessment, improved development control, and an increase in the economic efficiency of production due to the absence of losses during well testing and due to obtaining additional information on a larger number of wells. The application of these methods can become the basis for optimizing field operation in the long term.

References

1. Chaudhry A., Oil well testing handbook, Elsevier, 2004, 525 p.

2. Buzinov S.N., Umrikhin I.D., Issledovanie neftyanykh i gazovykh skvazhin i plastov (The study of oil and gas wells and reservoirs), Moscow: Nedra Publ., 1984, 269 p.

3. Kul’pin L.G., Myasnikov Yu.A., Gidrodinamicheskie metody issledovaniya neftegazovodonosnykh plastov (Hydrodynamic study of oil-gas-water-bearing strata), Moscow: Nedra Publ., 1974, 200 p.

4. Bourdet D., Well test analysis: The use of advanced interpretation models, Boston, Elsevier Science, 2002, 436 p.

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

6. Sova E.V., Sova V.E., Efficiency of application of the research technique at two flow rates to reduce the cost of hydrodynamic testing of production wells (In Russ.), Geologiya, 9. Osnovy ispytaniya plastov (Formation testing fundamentals): edited by Zagurenko A.G., Moscow-Izhevsk: Publ. of Institute of Computer Research, 2012, 432 p.

geografiya i global’naya energiya, 2009, no. 2(33), pp. 76-79.

7. Gulyaev D.N., Batmanova O.V., Pulse-code test and multi-well deconvolution algorithms are new technologies for reservoir properties determination between the wells (In Russ.), Vestnik Rossiyskogo novogo universiteta. Seriya: Slozhnye sistemy: modeli, analiz, upravlenie, 2017, no. 4, pp. 26–32.

8. Fundamentals of formation testing, Schlumberger, 2008.

9. Aslanyan A., Kovalenko I., Ilyasov I. et al., Waterflood study of high viscosity saturated reservoir with multiwell retrospective testing and cross-well pressure pulse-code testing, SPE-193712-MS, 2018, DOI: http://doi.org/10.2118/193712-MS

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

11. Houze O., Viturat D., Fjaere O.S. et al., Dynamic data analysis. V 5.42, Kappa Engineering, 2022, 772 p.

12. Von Schroeter T., Hollaender F., Gringarten A.C., Deconvolution of well-test data as a nonlinear total least-squares problem, SPE-71574-MS, 2004,

DOI: http://doi.org/10.2118/71574-MS

13. Kremenetskiy M.I., Ipatov A.I., Gulyaev D.N., Informatsionnoe obespechenie i tekhnologii gidrodinamicheskogo modelirovaniya neftyanykh i gazovykh zalezhey (Information support and technologies of hydrodynamic modeling of oil and gas deposits), Moscow - Izhevsk: Publ. of Izhevsk Institute of Computer Research, 2012, 896 p.

14. Afanaskin I.V., Kolevatov A.A., Glushakov A.A., Mathematic model for well test interpretation in wells producing with altered flow rates in homogeneous reservoir

(In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2023, no. 4, pp. 52–55, DOI: http://doi.org/10.24887/0028-2448-2023-4-52-55

15. Afanaskin I.V., Kolevatov A.A., Glushakov A.A., Mathematic models for well test interpretation in wells producing with altered flow rates in reservoir with strait no-flow boundary and in reservoir with two parallel no-flow boundaries (In Russ.), Neftepromyslovoe delo, 2023, no. 8(656), pp. 12–17, DOI: https://doi.org/10.33285/0207-2351-2023-8(656)-12-17

16. Glushakov A.A., Pivovarov D.E., Afanaskin I.V., Kolevatov A.A., Mathematical model for interpretation of hydrodynamic studies data of wells with variable production in a semi-endless strip (In Russ.), Geologiya, geofizika i razrabotka neftyanykh i gazovykh mestorozhdeniy, 2024, no. 8(392), pp. 34–42.

17. Deeva T.A., Kamartdinov M.R., Kulagina T.E., Mangazeev P.V., Gidrodinamicheskie issledovaniya skvazhin: analiz i interpretatsiya dannykh (Well test: analysis and interpretation of data), Tomsk: Publ. of TPU, 2009, 243 p.

18. Dietz D.N., Determination of average reservoir pressure from build-up surveys, J. Pet. Tech., 1965, Aug., pp. 955–959, DOI: https://doi.org/10.2118/1156-PA

The article examines the use of CO₂ foam injection technology as a promising and innovative approach to enhancing oil recovery. It provides a detailed analysis of the underlying mechanisms, the advantages of this method, and the key parameters influencing its performance. By generating a foam composition with the aid of foaming agents, the mobility of carbon dioxide is reduced, resulting in more uniform sweep efficiency and prevention of premature CO₂ breakthrough. Ultimately, this leads to more effective extraction of residual oil from the reservoir’s pore space. The authors pay particular attention to the factors determining the overall effectiveness of the process: foam stability, concentration of surfactants, reservoir permeability, temperature and pressure conditions, and the mineralization level of formation water. Pilot projects at the Salt Creek oil field (USA) and the Orenburg oil field (Russia) demonstrate cases of increased oil recovery and economic feasibility of this technique. The ecological aspect is also highlighted: CO₂ foam injection technology enables to capture and reuse carbon dioxide, thereby reducing the carbon footprint in the oil and gas sector. Future research directions focus on improving foam stability, optimizing the selection of foaming agents, and refining the modeling of the injection process. Thus, the use of CO₂ foam can be considered an environmentally sound and cost-effective technology capable of significantly increasing oil recovery and playing a vital role in developing fields with hard-to-recover reserves.

References

1. Chang Shih-Hsien, Grigg R.B., Effects of foam quality and flow rate on CO2-foam behavior at reservoir conditions, SPE-39679-MS, 1998,

DOI: https://doi.org/10.2118/39679-MS

2. Nazarova L.N., Razrabotka neftegazovykh mestorozhdenii s trudnoizvlekaemymi zapasami (Development of oil and gas fields with hard-to-recover reserves), Moscow: Publ. of Gubkin University, 2019, 338 p.

3. Farajzadeh R., Andrianov A., Krastev R. et al., Foam-oil interaction in porous media: Implications for foam assisted enhanced oil recovery, Advances in Colloid and Interface Science, 2012, V. 183–184, no.15, pp. 1-13, DOI: https://doi.org/10.1016/j.cis.2012.07.002

4. Ydstebø T., Enhanced oil recovery by CO2 and CO2-foam in fractured carbonates: Master Thesis in Reservoir Physics, University of Bergen, 2013.

5. Mukherjee J., Norris S.O., Nguyen Q.P. et al., CO2 foam pilot in Salt Creek field, Natrona County, WY: Phase I: Laboratory work, reservoir simulation, and initial design, SPE-169166-MS, 2014, DOI: https://doi.org/10.2118/169166-MS

6. Alvarado V., Manrique E., Lake L. Analytical and numerical solutions for fluid injection into naturally fractured reservoirs // Society of Petroleum Engineers. – 2004.

7. Sarma H., Zhang D. CO2-foam-based enhanced oil recovery (EOR) and fracturing // Energy Procedia. – 2015. – V. 74. – P. 68–77.

8. Tsau Jyun-Syung, Grigg R.B., Assessment of foam properties and effectiveness in mobility reduction for CO2-foam floods, SPE-37221-MS, 1997,

DOI: https://doi.org/10.2118/37221-MS

9. Le Linh, Ramanathan Raja, Hisham Nasr-El-Din, Evaluation of an ethoxylated amine surfactant for CO2-foam stability at high salinity conditions, SPE-197515-MS, 2019, DOI: https://doi.org/10.2118/197515-MS

10. Salt Creek Oil Field, URL: https://en.wikipedia.org/wiki/Salt_Creek_Oil_Field

11. Mukherjee J., Nguyen Q.P., Scherlin J., CO2 foam pilot in Salt Creek field, Natrona County, WY: Phase III: Analysis of Pilot Performance, SPE-179635-MS, 2016,

DOI: https://doi.org/10.2118/179635-MS

12. Orenburgskoe neftegazokondensatnoe mestorozhdenie (NGKM) (Orenburg oil and gas condensate field (OGCF)), Neftegaz.ru, URL: https://neftegaz.ru/tech-library/mestorozhdeniya/141624-orenburgskoe-neftegazokondensatnoe-mestorozh...

13. Metz B., Davidson O., Carbon dioxide capture and storage, IPCC special report on carbon dioxide capture and storage,

URL: https://digitallibrary.un.org/record/3892909?v=pdf

The article considers the introduction into development and analysis of the effectiveness of the existing development system for fields with a complex structure and heterogeneous filtration and reservoir characteristics limits the possibility of using classical methods, developed mainly in the middle of the last century. Such methods also include methods for substantiating the oil recovery factor. One of the most common methods is the extrapolation method of displacement characteristics. While paying great attention to the selection of the displacement characteristics based on the accuracy of the description of the actual data of the accumulated technological indicators of development, fundamentally important conditions for the application of these characteristics are often omitted from consideration. In fact the possibility of using the displacement characteristics method is influenced not only by the geological features of new fields, but also by fundamentally different decisions which are taken to form the development system. In particular, this includes the allocation of hydrodynamically connected but independent sections of the development system, the use of multi-stage hydraulic fracturing, well operation modes and others. As a result such conditions for the development of oil fields violate the main fundamentally important conditions for the application of extrapolation methods, leading to incorrect results.

References

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2. Kazakov A.A., Forecasting the indicators of field development on the characteristics of oil displacement by water (In Russ.), Neftepromyslovoe delo, 1976, no. 8,

pp. 5–7.

3. Kazakov A.A., Development of integrated methodic approaches to effectiveness assessment of geological and engineering actions aimed at enhanced oil recovery and oil production intensification (as discussion) (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2003, no. 4, pp. 26–29.

4. Kazakov A.A., Efficiency forecasting of hydrodynamic methods oil recovery for enhancement (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2006, no. 12,

pp. 110–112.

5. Davydov A.V., Analiz i prognoz razrabotki neftyanykh zalezhey (Analysis and forecast of the development of oil deposits), Moscow: Publ. of VNIIOENG, 2008, 316 p.

6. Ivanova M.M., Cholovskiy I.P., Bragin Yu.I., Neftegazopromyslovaya geologiya (Oil and gas geology), Moscow: Nedra Publ., 2000, 414 p.

7. Khamzin R.G., Razrabotka i sostavlenie metodicheskogo rukovodstva po primeneniyu traditsionnykh metodov kharakteristik vytesneniya dlya otsenki effektivnosti razrabotki ekspluatatsionnykh ob»ektov i krupnomasshtabnykh tekhnologicheskikh meropriyatiy (Development and compilation of a methodological guide for the application of traditional methods of displacement characteristics to assess the efficiency of development of operational facilities and large-scale technological measures), Bugul’ma: Publ. of TatNIPIneft’, 2000, 43 p.

8. Gutman I.S., Saakyan M.I., Metody podscheta zapasov i otsenki resursov nefti i gaza (Methods for calculating reserves and assessing resources of oil and gas), Moscow: Nedra Publ., 2017, 366 p.

9. Muslimov R.Kh., Sovremennye metody povysheniya nefteizvlecheniya: proektirovanie, optimizatsiya i otsenka effektivnosti (Modern methods of enhanced oil recovery: the design, optimization and assessment of efficiency), Kazan’: Fen Publ., 2005, 688 p.

10. Vakhrusheva I.A. et al., Results of applying various flooding systems based on the case study of Vikulov suite, Kamennaya area (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2010, no. 11, pp. 62–65.

11. Amelin I.D., Surguchev M.L., Davydov A.V., Prognoz razrabotki neftyanykh zalezhey na pozdney stadii (The forecast of oil deposits development at a late stage), Moscow: Nedra Publ., 1994, 308 p.

12. Nazarova L.N., Shelyago E.V., Yazynina I.V., Definition of oil-water displacement ratio from experimental data (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2024, no. 2, pp. 58–61, DOI: http://doi.org/10.24887/0028-2448-2024-2-58-61

The current stage of oil industry development is taking place in conditions of competition between various sources of energy production. Reducing the cost of oil production is a determining factor in the competitive struggle. Therefore, the priority task in oil production is the introduction of new technology. Reducing the number of well repairs by reducing the number of repairs due to the failure of the electrical part of the cable line, which account for a third of all failures, will significantly reduce production costs. According to theoretical studies and the study of the condition of failed electrical submersible centrifugal pumps (ESPs), equipment failure is associated with the thermal condition of ESP. Solving problems related to failures due to overheating of the cable line necessarily requires studying the thermodynamics of a ESP when pumping gas-liquid mixtures under high pressure and temperature. To date, such problems have not been posed or solved in classical thermodynamics. The author set a similar task for the first time and received an analytical solution. Field tests were conducted. The results obtained at the oil fields in Western Siberia showed the correctness of the chosen method for solving the problem of the thermal state of an ESP. Failures of the ESP along the cable line are the result of high temperature generation in the pump. By excluding the conditions of high temperature formation in the pump from the operating mode, failures due to the cable line can be avoided, which will reduce the cost of oil production.

References

1. Alekseev G.N., Obshchaya teplotekhnika (General heating engineering), Moscow: Vysshaya shkola Publ., 1980, 550 p.

2. Gareev A.A., On the significance of thermal practices in electrical centrifugal pumps units (In Russ.), Oborudovanie i tekhnologii dlya neftepromyslovogo kompleksa, 2009, no. 1, pp. 23–29.

3. Gareyev A.A., About the heat transfer coefficient, European Journal of Applied Sciences, 2022, V. 10(1), pp. 234–241, DOI: https://doi.org/10.14738/aivp.101.11655

4. Gareev A.A., Tsentrobezhnye nasosy v dobyche nefti (problemy i resheniya) (Centrifugal pumps in oil production (problems and solutions)), Ufa: Neftegazovoe delo Publ., 2020, 244 p.

5. Drozdov A.N., Tekhnologiya i tekhnika dobychi nefti pogruzhnymi nasosami v oslozhnennykh usloviyakh (Technology and engineering of oil production using submersible pumps under complicated conditions), Moscow: MAKS press Publ., 2008, 312 p.

The paper considers an approach to the primary assessment of the performance of multicircuit burner devices when working with a multi-component mixture composition, being applied to the solution of the problem of associated petroleum gas utilization. The formed approach assumes consecutive accounting of stoichiometric balance of fuel mixture and oxidant, numerical modeling of gas mixing process with the subsequent analysis of concentration fields of mixture components and oxidant and degree of mixture homogenization. It also includes the stage of estimation of possibility and efficiency of ignition of the obtained mixture and completeness of its combustion. On the basis of numerical modeling methods it is proposed to study only the process of mixing of multicomponent media in the working area of the burner device. Further analysis of the concentration fields of substances is performed visually, as well as using the universal homogenisation criterion. At the first stage of approbation of the proposed approach the efficiency of the burner devices is determined by the degree of homogenisation of the mixture of fuel mixture components supplied from two different circuits of the device with air entering the mixer through slits. The determining parameter, within the framework of the first stage of approbation, is the degree of homogeneity of the final mixture, i.e. the influence of the feeding mode of components on the field of their concentrations in the mixture.

References

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2. Kultyshev A.Yu., Goloshumova V.N, Aleshina A.S., Parogazovye ustanovki i osobennosti parovykh turbin dlya PGU (Combined-cycle plants and features of steam turbines for CCGT units), St. Petersburg: POLITEKh-PRESS Publ., 2022, 163 p.

3. Barochkin A.E., Modelirovanie, raschet i optimizatsiya mnogokomponentnykh mnogopotochnykh mnogostupenchatykh energeticheskikh sistem i ustanovok (Modeling, calculation and optimization of multi-component multi-flow multi-stage energy systems and installations): thesis of doctor of technical science, Ivanovo, 2024.

4. Makasheva A.P., Naymanova A.Zh., Numerical simulation of a multicomponent mixing layer with solid particles (In Russ.), Teplofizika i aeromekhanika = Thermophysics and Aeromechanics, 2019, V. 26, no. 4, pp. 521–537.

5. Bunkluarb N., Sawangtong W., Khajohnsaksumeth N., Wiwatanapataphee B., Numerical simulation of granular mixing in static mixers with different geometries, Advances in Difference Equations volume, 2019, no. 238, DOI: https://doi.org/10.1186/s13662-019-2174-5

6. Pezo M., Pezo L., Jovanović A. et al., DEM/CFD approach for modeling granular flow in the revolving static mixer, Chem. Eng. Res. Des., 2016, V. 109, pp. 317–326, DOI: http://doi.org/10.1016/j.cherd.2016.02.003

7. Jovanović A., Pezo M., Pezo L. et al., DEM/CFD analysis of granular flow in static mixers, Powder Technol., 2014, V. 266, pp. 240–248,

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9. Theron F., Le Sauze N., Comparison between three static mixers for emulsification in turbulent flow, Int. J. Multiph. Flow, 2011, V. 37(5), pp. 488–500,

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11. Danilov Yu.M., Kurbangaleev A.A., Mukhametzyanova A.G., Alekseev K.A., Numerical 3D modeling of mixing components in small tubular devices (STA) (In Russ.), Vestnik Kazanskogo tekhnologicheskogo universiteta, 2012, no. 12, pp. 167-169, URL: https://cyberleninka.ru/article/n/chislennoe-3d-modelirovanie-smesheniya-komponentov-v-malogabaritny...

12. Danilov Yu.M., Kurbangaleev A.A., Reducing computational errors in numerical 3D modeling of mixing in axisymmetric channels (In Russ.), Vestnik Kazanskogo tekhnologicheskogo universiteta, 2012, no. 12, pp. 161-163, URL: https://cyberleninka.ru/article/n/umenshenie-vychislitelnyh-pogreshnostey-pri-chislennom-3d-modeliro...

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This paper presents a study of the dynamics of polyacrylamide (PAA) displacement from a porous medium using a sand-pack reservoir model. The research introduces and validates a novel computational method for determining PAA concentration based on the relationship between pressure drop and the volume of pumped fluid. This approach proved to be an effective tool for monitoring polymer concentration in the porous medium throughout the experimental process and during gel degradation. Three methods for estimating PAA concentration were compared: viscometric analysis, bleaching, and the proposed computational. The results of the comparison highlight the computational method’s stability and reliability across all stages of the experiment, demonstrating its superiority, particularly in complex geological conditions. The study also identifies key factors inhibiting the full recovery of permeability in the porous medium after PAA displacement. These include pore clogging by residual polymer and the migration of sand particles, which underscore the need for additional optimization measures to restore permeability effectively. The paper provides recommendations for future research to enhance current methods and broaden their applicability. These recommendations include testing the approach on core samples, optimizing reagent formulations, and advancing analytical techniques. These efforts aim to improve the accuracy and reliability of methods for assessing and managing porous media. Ultimately, the findings can contribute to optimizing the efficiency of hydrocarbon reservoir development and operation, offering valuable insights for field applications.

References

1. Tolstykh L.I., Davletshina L.F., Poteshkina K.A., Poliakrilamid v protsessakh neftegazodobychi (Polyacrylamide in oil and gas production processes), Moscow: Publ. of Gubkim University, 2023, 135 p.

2. Al-Hajri S. et al., Perspective review of polymers as additives in water-based fracturing fluids, ACS Omega, 2022, no. 9(7), pp. 7431–7443,

DOI: http://doi.org/10.1021/acsomega.1c06739

3. Bey H.B. et al., Impact of polyacrylamide adsorption on flow through porous siliceous materials: State of the art, discussion, and industrial concern, Journal of Colloid and Interface Science, 2018, V. 531, pp. 693–704, DOI: http://doi.org/10.1016/j.jcis.2018.07.103

4. Yang Li et al., Reduced adsorption of polyacrylamide-based fracturing fluid on shale rock using urea, Energy Science and Engineering, 2018, no. 6 (6), pp. 749–759, DOI: http://doi.org/10.1002/ese3.249

5. Vorob’ev P.D., Krut’ko N.P., Vorob’eva E.V., Strnadova N., Successive adsorption of polyacrylamide compounds from electrolyte solutions on the surface of kaolinitic clay particles (In Russ.), Kolloidnyy zhurnal, 2008, V. 70, no. 2, pp. 171–174.

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7. Al-Hashmi A.R., Luckham P.F., Characterization of the adsorption of high molecular weight non-ionic and cationic polyacrylamide on glass from aqueous solutions using modified atomic force microscopy, Colloids and Surfaces A: Physicochemical and Engineering Aspects, 2010, V. 358, pp. 142–148, DOI: http://doi.org/10.1016/j.colsurfa.2010.01.049

8. Poteshkina K.A., Borodin S.A., Ronzhina V.V. et al., Mathematical modelling of polyacrylamide adsorption process, Chem Technol Fuels Oils, 2024, V. 60,

pp. 1155–1162, DOI: http://doi.org/10.1007/s10553-024-01778-8

9. Bey B.H., Fusier J., Harrisson S. et al., Impact of polyacrylamide adsorption on flow through porous siliceous materials: State of the art, discussion and industrial concern // Journal of colloid and interface science. – 2018. – № 531 – P. 693–704.

10. Al-Hajri S., Mahmood S.M., Abdulelah H., Akbari S., An overview on polymer retention in porous media, Energies, 2018, no. 11, pp. 2751–2770,

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11. Holmberg K., Jönsson B. et al., Surfactants and polymers in aqueous solution, John Wiley & Sons, 2002, 562 p.

12. Brattekås B., Seright R., Ersland G., Water leakoff during gel placement in fractures: Extension to oil-saturated porous media, SPE-190256-PA, 2020,

DOI: http://doi.org/10.2118/190256-PA

13. Ganguly S., Willhite G.P., Green D.W., McCool C.S., The effect of fluid leakoff on gel placement and gel stability in fractures, SPE-64987-MS, 2001,

DOI: http://doi.org/10.2118/64987-MS

14. Stavland A., Jonsbråten H.C., Lohne A. et al., Polymer flooding - Flow properties in porous media versus rheological parameters, SPE-131103-MS, 2010,

DOI: http://doi.org/10.2118/131103-MS

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J. Memb. Sci., 2018, V. 560, pp. 125–131, DOI: http://doi.org/10.1016/j.memsci.2018.04.055

The article presents the results of laboratory determination of the partition coefficient between the aqueous and petroleum phases of two corrosion inhibitors (CI) CI-1 and CI-2. These inhibitors were industrially used in Kondaneft Oil Company JSC when organizing inhibitory protection of oil and gas pipelines. The composition of CIs was determined by gas chromatography-mass spectrometry (GC-MS). As a result of laboratory studies, it was determined that CI-1 at concentration up to 150 mg/dm3 is not distributed into water, due to its probable concentration at the interface of the «oil-water» phases. The analysis of CI-2 showed that at concentrations of 50, 100, 150 and 200 mg/dm3, its migration into the aqueous phase occurs. The partition coefficients of this inhibitor were calculated, ranging from 1,2 to 4,9 depending on the different water-oil ratio, as well as on the initial concentration of the inhibitor introduced into the mixture. It was found that at the concentration of 20 mg/dm3, the partition of CI-2 into the aqueous phase did not occur. It was recorded that with an increase in the concentration of the introduced CI into the mixture, the partition coefficient decreases, i.e. its more efficient distribution into water begins at all values of water content. According to the industrial application of these CIs and to the results of corrosion monitoring, it was confirmed that CI-2 begins to show some effectiveness only after overcoming the threshold concentration of activation of partition and the effectiveness increases systematically with an increase in the administered dosage.

References

1. Markin A.N., Tkacheva V.E., Dresvyannikov A.F., Akhmetova A.N., Korroziya i zashchita neftepromyslovogo oborudovaniya (Corrosion and protection of oilfield equipment), Kazan Publ. of KSTU, 2022, 188 p.

2. Galikeev V.A., Galikeev I.A., Nasyrov V.A., Nasyrov A.M., Ekspluatatsiya mestorozhdeniy nefti v oslozhnennykh usloviyakh (Exploitation of oil fields in difficult conditions), Izhevsk: Paratsel’s Print Publ., 2015, 356 p.

3. Tkacheva V.E., Brikov A.V., Lunin D.A., Markin A.N., Lokal’naya CO2-korroziya neftepromyslovogo oborudovaniya (Localized CO2 corrosion of oilfield equipment), Ufa: Publ. of RN-BashNIPIneft’, 2021, 168 p.

4. Markin A.N., Sukhoverkhov S.V., Brikov A.V., Localized CO2-corrosion of oil gathering pipeline systems in the Western Siberia oilfields (In Russ.), Neftepromyslovoe delo, 2017, no. 1, pp. 46–48.

5. Markin A.N., Brikov A.V., Dependence of corrosion inhibitor efficiency on its partition coefficient (In Russ.), Neftepromyslovoe delo, 2021, no. 6, pp. 60–64,

DOI: https://doi.org/10.33285/0207-2351-2021-6(630)-60-64

6. Markin A.N., Sukhoverkhov S.V., Brikov A.V., Neftepromyslovaya khimiya: analiticheskie metody (Oilfield chemistry: Analytical methods), Yuzhno-Sakhalinsk: Sakhalin Regional Printing House, 2016, 212 p.

7. Fot K.S., Tkacheva V.E., Garfutdinov I.F., Markin A.N., Effective dosage of corrosion inhibitors for oilfield equipment protection from localized carbon dioxide corrosion (In Russ.), Neftegazovoe delo, 2024, no. 5, pp. 193–220, DOI: https://doi.org/10.17122/ogbus-2024-5-193-220

Chlororganic compounds (COCs), most often, can get into the crude oil during its extraction, because sometimes the use of chemical products containing COCs is abused. According to the national standard (GOST R 51858-2020) and technical regulations for commercial oil (TR EAEU 045/2017), the content of COCs should be standardized. The presence of organic chlorides in oil above the standardized value causes serious economic damage to the oil industry, primarily to oil refining. The article is devoted to laboratory research of the process of extraction of organic chloride CCl4 from oil through the formation of thiourea clathrates of channel type in the oil volume. The methodology of oil treatment with thiourea and preliminary results of the study are described. The obtained experimental data show that the formed thiourea clathrates of channel type can retain CCl4 molecule in their channels, and after separation of the clathrate phase from oil the concentration of organic chloride in oil decreases. The paper considers the effects of temperature, thiourea, organic chloride concentrations, and the number of treatments on the efficiency index (Ef) of CCl4 extraction from oil. The Ef index also depends on the initial content of organic chloride in oil – the higher the initial concentration of organic chloride in oil, the more effectively it is extracted from oil. Based on the analysis of experimental data, preliminary advantages and disadvantages of the process of extraction of organic chloride from oil were revealed to assess the possibility of its industrial application.

References

1. Khasbiullin I.I., Shmatkov A.A., The issues of controlling the use of chemical reagents to ensure the safety and efficiency of oil production, treatment and transportation (In Russ.), Nauka i tehnologii truboprovodnogo transporta nefti i nefteproduktov = Science & Technologies: Oil and Oil Products Pipeline Transportation, 2021, V. 11 (3), pp. 338–345, DOI: https://doi.org/10.28999/2541-9595-2021-11-3-338-345

2. Stepanova T.V., Vliyanie reagentov, ispol’zuemykh pri dobyche nefti, na svoystva neftyanogo syr’ya i protsessy ego pervichnoy pererabotki (The influence of reagents used in oil production on the properties of crude oil and the processes of its primary processing): thesis of candidate of technical science, Moscow, 2006,

168 p.

3. Vintilov S.V., Akishev D.A., Zholobov V.P., Zaytsev V.I., Analysis of problems associated with the formation of deposits in oil refining processes and the growth of corrosive wear of equipment at refineries (In Russ.), Khimicheskaya tekhnika, 2015, no. 6, URL: http://chemtech.ru/analiz-problem-svjazannyh-s-obrazovaniem-otlozhenij-v-processah-pererabotki-nefti...

4. Patent RU2221837C1, Method of processing of gasoline fractions containing organochlorine compounds on reforming installations, Inventors: Tomin V.P., Mikishev V.A., Elshin A.I., Kuzora I.E., Kolotov V.Yu.

5. Patent RU2672263C1, Method of reducing content of organic chlorides in oil, Inventors: Abdrakhmanova L.M., Tat’yanina O.S., Sudykin S.N.

6. Arjang S., Motahari K., Saidi M., Experimental and modeling study of organic chloride compounds removal from naphtha fraction of contaminated crude oil using sintered g-Al2O3 nanoparticles: equilibrium, kinetic and thermodynamic analysis, Energy Fuels, 2018, V. 32(3), pp. 4025–4039, DOI: https://doi.org/10.1021/acs.energyfuels.7b03845

7. Fazullin D.D., Mavrin G.V., Shaykhiev I.G., Study of the possibility of isolating hexane and tetrachloromethane from model emulsions using hydrophobic membranes

(In Russ.), Vestnik tekhnologicheskogo universiteta, 2016, V. 19(10), pp. 154–157.

8. Patent JP2014239656A, Cleansing agents for soil or underground water polluted with volatile organochlorine compounds and methods for cleansing polluted soil or underground water by using the cleansing agents, Inventors: Imada Ch., Sato T., Suzuki S.

9. Dyadin Yu.A., Supramolecular chemistry: Clathrate compounds (In Russ.), Sorosovskiy obrazovatel’nyy zhurnal, 1998, no. 2, pp. 79–88.

10. Chekhova G.N., Shubin Yu.V., Mesyats E.A. et al., Phase equilibria in the thiourea-chloroform and thiourea-carbon tetrachloride systems (In Russ.), Zhurnal fizicheskoy khimii = Russian Journal of Physical Chemistry, 2005, V. 79 (7), pp. 1170–1174.

11. Veshchestva, primenyaemye v kachestve adsorbtivov, i razmery ikh molekul (Substances used as adsorbents and the sizes of their molecules),

URL: https://www.kntgroup.ru/ru/information/adsorptive

12. Naumov V.N., Frolova G.I., Seryakov A.V. et al.,Termodinamicheskie funktsii kanal’nogo klatrata tiomocheviny s geksakhloretanom v intervale 5 - 315 K (In Russ.), Zhurnal fizicheskoy khimii, 2002, V. 76(7), pp. 1173–1178.

13. Solodovnikov S.F., Chekhova G.N., Romanenko G.V. et al., Crystal structure of the 1:3 thiourea-hexachloroethane inclusion compound at 295 K (In Russ.), Zhurnal strukturnoy khimii, 2007, V. 48(2), pp. 348–357.

14. Rudakova N.Ya., Timoshina A.V., Karbamidnoe kompleksoobrazovanie nefti (Urea complexation of oil), Lenigrad: Khimiya Publ., 1985, 240 p.

In order to improve the quality of the produced water and to ensure the planned loading of the RUSVIETPETRO JV LLC facility in the future, pilot tests were carried out to modernize the existing equipment using internal intensifying devices. These tests enabled to increase the capacity and quality of water treatment and to maintain the tendency of increasing oil production in a short time and with minimal financing. New types of internal devices were installed in the vessel, which increased the cross-sectional area of the coalescence and minimized the resistance of settling water and floating oil droplets. Due to the above-mentioned modification, the degree of water purification increases, which reduces the load on subsequent filtration stages, and has a positive effect on the operation of the pumping equipment. In turn, this solution ensures the quality of the produced water for injection into the Famennian aquifer in accordance with the requirements of Industrial Standard № 39-225-88. The installation of new type coalescing devices, made it possible not only to achieve the set goals, but also to upgrade the equipment with an increase in its capacity without changing the existing infrastructure. These activities enabled to minimize the cost of reconstruction and to ensure the integration of new technologies into the existing system without stopping production processes.

References

1. Golubev I.A., Lyagov A.V., Sovershenstvovanie sistem sbora i podgotovki skvazhinnoy produktsii putem organizatsii kustovogo sbrosa poputnoy dobyvaemoy plastovoy vody v germetizirovannom variante (Improving the systems for collecting and preparing well products by organizing a cluster discharge of associated produced formation water in a sealed version), Proceedings of Vserossiyskoy nauchno-tekhnicheskoy konferentsii “Innovatsionnoe neftegazovoe oborudovanie: problemy i resheniya” (Innovative oil and gas equipment: problems and solutions), Ufa: Publ. of USPTU, 2010, pp. 105-110.

2. Baykov N.M., Pozdnyshev G.N., Mansurova R.I., Sbor i promyslovaya podgotovki nefti, gaza i vody (Collection and field preparation of oil, gas and water), Moscow: Nedra Publ., 1981, 803 p.

3. Sistemy sbora nefti i gaza (Oil and gas gathering systems), URL: http://www.neftegaz-expo.ru/ru/articles/sistemy-sbora-nefti-na-mestorozhdenii/

The research considers issues of using the results of ground-based laser scanning to ensure mechanical safety of tanks of а marine terminal. It is shown, that a significant amount of data necessary for tanks technical condition assessment is provided by three-dimensional real geometry models of a tank wall, created on ground-based laser scanning results. The article shows results of stress-strain state of tank wall structures analysis obtained from the actual geometry. It is highlighted that three-dimensional ground-based laser scanning model enables to carry out a comprehensive tank wall geometry analysis, as well as to fix the coordinates and parameters of local minima and maxima of structural deviations and to analyze the stress-strain state based on the finite element method. The data obtained from the model analysis indicate that reliability and safety of the studied structures are ensured despite the structural difference in tank designs. The article presents numerical parameters for stresses arising in tank wall with local geometric deviations, shows the way detected deviations affect the stress distribution within the tank wall. The obtained calculated stresses indicate that the safe level of stress-strain state during operation is typical for all examined tanks, regardless of the year of construction and the regulatory framework on the basis of which the design and construction were carried out.

References

1. Gorban’ N.N., Vasil’ev G.G., Leonovich I.A., Tasks of forming a parametric system for ensuring the integrated safety of tank farms of marine terminals (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2024, no. 1, pp. 90-97, DOI: http://doi.org/10.24887/0028-2448-2024-1-90-97

2. Karavaychenko M.G., Prochnost’ i zhivuchest’ rezervuarov (Strength and survivability of tanks), St. Petersburg: Naukoemkie tekhnologii Publ., 2023, 524 p.

3. Tarasenko A.A., Chepur P.V., Chirkov S.V., Tarasenko D.A., Steel storage oil tank simulated using ANSYS Workbench 14.5 (In Russ.), Fundamental’nye issledovaniya, 2013, no. 10-15, pp. 3404–3408

4. Samigullin G.Kh., Lyagova A.A., Dmitrieva A.S., Trouble-free operation of tanks, assessment of the stress-strain state of a steel cylindrical tank with a “crack” type defect using the ANSYS (In Russ.), Neftegaz.RU, 2017, no. 12(72), pp. 14-17.

5. Chepur P.V., Tarasenko A.A., Numerical modeling and verification of tank RVSPK-50000 (In Russ.), Fundamental’nye issledovaniya, 2015, no. 7-1, pp. 95–100.

6. Tarasenko A.A., Chepur P.V., Gruchenkova A.A., Evaluation of technical condition of tanks with geometrical imperfections form wall (In Russ.),

Neftyanoe khozyaystvo = Oil Industry, 2017, no. 6, pp. 118–121, DOI: http://doi.org/10.24887/0028-2448-2017-6-118-121

7. Wang H.-Y., Du L., Fitness-for-service analysis of 15 000 m3 atmospheric pressure internal floating oil tank, Petrochemical Equipment, 2017, V. 46, pp. 35–39,

DOI: http://doi.org/10.3969/j.issn.1000-7466201705.007

8. Tursunkululy T., Zhangabay N., Avramov K. et al., Strength analysis of prestressed vertical cylindrical steel oil tanks under operational and dynamic loads, Eastern-European Journal of Enterprise Technologies, 2022, V. 2, no. 7, pp. 14–21, DOI: http://doi.org/10.15587/1729-4061.2022.254218

9. Gorban’ N.N., Vasil’ev G.G., Sal’nikov A.P., Accounting actual geometric shape of the tank shell when evaluating its fatigue life (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2018, no. 8, pp. 75–79, DOI: http://doi.org/10.24887/0028-2448-2018-8-75-79

10. Vasil’ev G.G., Lezhnev M.A., Leonovich I.A., Sal’nikov A.P., Stress-strain state of tanks in operation (In Russ.), Truboprovodnyy transport: teoriya i praktika, 2015,

no. 6 (52), pp. 41-44.

The stratigraphic breakdown of the section according to well logging data is the basis of all types of geological work. Stratigraphic correlation of layers is a routine task, when specialist has good knowledge of the geological structure of the region and the features of formations. Automatic correlation algorithm is proposed to facilitate the work of specialists. For automatically correlation of formations, it is necessary to select several reference wells that are evenly distributed over the area. As a rule, 20 % of the total number of wells under consideration is used. The correlation of layers is carried out by a geologist in reference wells, the selected algorithm is used between reference wells. The algorithm consists of several stages. In the first stage, a three-dimensional geological surface is constructed based on the data from reference wells. This provides the initial approximation of the stratigraphic boundary. Next, in the vicinity of the obtained initial approximation, the position of the stratigraphic boundary is refined. For this purpose the similarity in the behavior of well logging curves is analyzed. The article considers two approaches for assessing similarity: the first is a classical method using a target function dependent on the correlation coefficient, and the second is correlation using a neural network. As part of the study, experiments were conducted to evaluate the quality and efficiency of the proposed methods. Models using autoencoders performed relatively well when analyzing test data. These approaches can greatly facilitate the work of geologists in process of stratigraphic correlation.

References

1. Hinton G.E., Salakhutdinov R.R., Reducing the dimensionality of data with neural networks, Science, 2006, V. 313, no. 5786, pp. 504–507,

DOI: http://doi.org/10.1126/science.1127647

2. Ma H., Wei Y., Cui X., Image denoising with convolutional autoencoders, Proceedings of IEEE International Conference on Systems, Man and Cybernetics (SMC), 2018, pp. 3076–3081.

3. Qian S., Zhang S., Jia R., A new method for environmental sound classification based on convolutional autoencoder, Proceedings of 14th IEEE Conference on Industrial Electronics and Applications (ICIEA), 2019, pp. 2644–2649.

4. Bromley J., Bentz J.W., Bottou L. et al., Signature verification using a «siamese» time delay neural network, International Journal of Pattern Recognition and Artificial Intelligence, 1993, V. 7(04), pp. 669–688, DOI: https://doi.org/10.1142/s0218001493000339

5. Taigman Y., Yang M., Ranzato M., Wolf L., DeepFace: Closing the gap to human-level performance in face verification, Proceedings of IEEE Conference on Computer Vision and Pattern Recognition, 2014, DOI: https://doi.org/10.1109/cvpr.2014.220

6. Mueller J., Thyagarajan А., Siamese recurrent architectures for learning sentence similarity, Proceedings of the AAAI Conference on Artificial Intelligence, 2016,

V. 30 (1), DOI: https://doi.org/10.1609/aaai.v30i1.10350

7. Koch G., Zemel R., Salakhutdinov R., Siamese neural networks for one-shot image recognition, ICML deep learning workshop, 2015, V. 2,

URL: https://www.cs.cmu.edu/~rsalakhu/papers/oneshot1.pdf

During geological exploration and development of oil and gas fields, a large amount of information is collected. Currently, the data is interpreted and stored separately. Data duplication results in irrelevant information. This approach hinders the comprehensive analysis of accumulated material and the organization of continuous workflow based on related data, which makes it difficult to determine informative and reliable geological parameters. The development and implementation of a single digital platform for geological and geophysical information using modern digital technologies for storing, processing and analyzing data may change this situation. The digital system will gain the ability to continuously develop through the modernization of software modules and the implementation of innovations, provide users with a wide range of functional tools for data processing and analysis. The usage of machine learning based on neural networks enables to automate technical procedures for processing and analyzing geological and geophysical data, significantly reducing the errors factor, information distortion and freeing up specialists resources from routine operations. Such a structure promotes the usage of digital innovations for data processing and analysis and integrates production processes in the information space. This is the transition from the data digitalization to production processes digitalization, which leads their efficiency increase. The tools of the unified digital platform of geological and geophysical information will enable indepth data interpretation and obtain research results consistent with other related geological information. The listed functional capabilities implementation will contribute to increasing the efficiency of exploration and development of oil and gas fields.

References

1. Varlamov A.I., Gogonenkov G.N., Mel’nikov P.N., Cheremisina E.N., Development of digital technologies in petroleum industry and subsoil use in Russia: Current state and future considerations (In Russ.), Geologiya nefti i gaza, 2021, no. 3, pp. 5–20,

DOI: https://doi.org/10.31087/0016‑7894‑2021‑3‑5‑20

2. Karnaukhov A.M., Perspectives of research activities digitalization in geological exploration (In Russ.), Neftegazovaya geologiya. Teoriya i praktika, 2017, V. 12, no. 4, pp. 1–10, DOI: https://doi.org/10.17353/2070-5379/44_2017

3. Kravchenko M.N., Lyubimova A.V., Arbuzova E.E., Spiridonova V.V., Integrated GIS project for quantification of hydrocarbon resources in the Russian Federation as a platform for creating an integrated module for automated assessment of total initial resources (In Russ.), Geologiya nefti i gaza, 2021, no. 3, pp. 41–49, DOI: https://doi.org/10.31087/0016-7894-2021-3-41-49

The methods of identifying potential economic effects in relation to the development and implementation of information systems at the initial stage are considered. Thus, at the time of determining the economic effects, neither the suppliers of IT solutions, nor the systems themselves, nor the logic and tools on the basis of which they are built have been determined. Only the goals, objectives and business requirements as to the planned target state after implementation are defined. In the framework of solving this problem, which is in the domain of uncertainty, an analysis of the main existing methods for assessing economic effects in modern practice is carried out to identify the weaknesses and strengths of these methods, as well as the possibility of their implementation. Based on a comprehensive analysis, the authors’ original hybrid methodology for calculating economic effects is proposed for the conceptual elaboration of the information component of the planned project Production Management Center of an oil refinery. An example of the final list of identified qualitative and quantitative expected economic effects is presented, as well as recommendations are given on areas of analysis and methods for decomposing business requirements in order to generate potential economic effects in the field of information technology at the stage of conceptual development of the project.

References

1. Smirnov A., Tul’bovich E., Methods of controlling IT expenses and obtaining a guaranteed level of service (In Russ.), Upravlencheskiy uchet i byudzhetirovanie, 2008, no. 6.

2. Rapid Economic Justification (REJ): An introduction to the Microsoft REJ Framework, Gennaio: Microsoft.2003:8.

3. Seredenko E.S., Otsenka ekonomicheskoy effektivnosti analiticheskikh informatsionnykh sistem (Evaluation of economic efficiency of analytical information systems): thesis of candidate of economic science, Moscow, 2014.

4. Zinder E., What is IT efficiency? (In Russ.), Intelligent Enterprise, 2016, no. 8(141), URL: https://www.iemag.ru/master-class/detail.php?ID=15727

5. Anan’in V.I., The entrepreneurial value of IT for business (In Russ.), Ekonomika i zhizn’, 2011, no. 41, pp. 16–17.

6. Yadykov S., Information systems effectiveness - getting to the truth (In Russ.), Konsul’tant, 2010, no. 5.

7. Rumyantsev M., TCO: What is it and how to calculate it (In Russ.), Infobiznes, 2002, no. 7.

8. Skripki K.G., Basics of the TVO model (In Russ.) Direktor informatsionnoy sluzhby, 2005, no. 6, URL: https://www.osp.ru/cio/2005/06/174041

9. Grembergen W.V., Enterprise governance of information technology: Achieving strategic alignment and value, Springer, 2009, 233 p.

10. Kravchenko T.K., Seredenko N.N., Ogurechnikov E.V., Babkin A.E., Analysis and definition of concepts of information and analytical systems (In Russ.), Aktual’nye voprosy sovremennoy nauki, 2010, no. 11, pp. 223–230.

The modern world is changing the usual ways of developing design and working documentation for capital construction projects. The requirements of regulatory documents are changing; the latest program complexes are being developed and implemented. At the same time the cost of development of design and working documentation is calculated according to the Collections of basic prices approved more than 15 years ago. This situation clearly shows the need to update the regulatory framework for determining the cost of design work. This article describes a modern approach to the pricing of design and survey work at Rosneft Oil Company. The historical experience of the application of estimated standards is investigated, as well as the reasons determining the need to revise the current estimated standards for engineering surveys, preparation of design and working documentation. A study of the application of methods based on the analysis of the actual labor costs of the performers of the work and the resources involved in the development of the estimated standard for design and survey work is presented. The process of developing standard costs for design work is described by the calculation and analytical method based on the analysis of designers' labor costs. This method enables to consider current modern design methods and take into account their features in the indicators of the estimated standard. Based on the results of the conducted research, it is possible to build an objective model for the formation of a reliable cost of design work.

References

1. World Bank Group, URL: https://data.worldbank.org/indicator/NV.IND.TOTL.ZS?locations=Z4

2. Yusupova S.M., Reglamentatsiya i normirovanie truda (Regulation and standardization of labor), Saratov: Saratov State University, 2015, 147 p.

EPC/EPCM contracts (engineering, procurement, construction, management) are the most common types of contracts for the implementation of large projects in various fields. The article highlights the practice of their use in the construction of oil and gas market facilities. Today, in the Russian Federation, these forms of contracts are actively involved in the construction of facilities in the oil and gas industry and other industries due to their certain characteristics. The presented implementation models are aimed at Russian engineering companies, taking into account the identified legal differences and features of international and domestic legislation. In a comparative analysis between the articles of the Civil Code of the Russian Federation and the FIDIC form, the authors highlighted significant differences in approaches to the distribution of responsibility. EPC contracts have certain characteristics that largely distinguish them from EPC(M) contracts. The results obtained in this article led to the conclusion that at the moment the EPC and EPC(M) contracts are unified, but their application in Russia is subject to adaptation, taking into account Russian legislation. The work provides information about construction companies that can implement large projects. The analysis showed that, as part of the provision of services, domestic engineering companies use EPC and EPC(M) contract models, which cover the full cycle of work.

References

1. Mudrik I.V., EPC approach in oil and gas construction (In Russ.), Neftegaz.RU, 2023, no. 12(144), pp. 14–17.

2. URL: https://www.pmsoft.ru/news/pmsoft/vstupil-v-silu-natsionalnyy-standart-upravleniya-krupnymi-stroitel...

3. URL: https://sroportal.ru/publications/mezhdunarodnye-tipovye-kontrakty-fidik-i-ix-primenenie-v-investici...

4. URL: https://prcs.ru/analytics-article/rynok-epc-kontraktov-i-kontraktov-generalnogo-podryada/

5. ENR Engineering News-Record Top 250 Global Construction, sistema Capital IQ – Engineering News-Record Top Lists, URL: https://www.enr.com/toplists

6. Nikitin A.S., Pliev Kh.M. et al., Smart Construction Casebook – 2. Tekhnicheskiy zakazchik v Rossii. Sovremennye praktiki i tekhnologii upravleniya stroitel’stvom (Smart Construction Casebook – 2. Technical customer in Russia. Modern practices and technologies of construction management), Moscow: Tsentr kompetentsiy v stroitel’stve Publ., 2022, 375 p.

7. https://www.estimatix.ru/2023/10/04/9336967-osnovnoe-meropriyatie-v-sfere-upravleniya-proektam-wgl6/

8. Civil Code of the Russian Federation.

9. International Federation of Consulting Engineers, URL: http://fidic.org

10. Tsifrovaya platforma “Investitsionnye proekty Rossii” (Digital platform “Investment projects of Russia”), URL: https://investprojects.info/