The article examines the issue of improving the efficiency of geological exploration of oil and gas fields of the Cuu Long Basin in the territorial waters of Vietnam. The relevance of the study is determined by the need to reduce uncertainties in assessing the structure of sedimentary strata and to identify prospective zones. The main objective of the research is to validate a comprehensive approach to modeling the hydrocarbon system, which includes sequential stratigraphic modeling, analysis of tectonic history, and assessment of fault conductivity. The study employs methods of facies analysis, petroleum system analysis, and evaluation of reservoir properties of rocks. Special attention is paid to assessing clay content in faults and their role in hydrocarbon accumulation formation. The integrated modeling methodology that accounts for sedimentation patterns, tectonic evolution of the territory and fault characteristics demonstrated high reliability at existing sites. The practical significance of the work lies in enhancing the accuracy of prospective area prediction through an integrated modeling approach. Obtained results enable to optimize geological exploration planning and risk reduction in searching new hydrocarbon deposits. Promising future research directions include automation of sequential stratigraphic modeling stages to reduce time costs and implement the methodology in routine exploration practice.

References

1. Shakhov P.A., Desyatnikova A.E., Berezovskaya E.A., Zakiev E.M., Experience in combining modern methods of seismic exploration and sedimentation modeling on the example of the Cuu Long Basin (Vietnam) (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2023, no. 2, pp. 12–16, DOI: https://doi.org/10.24887/0028-2448-2023-2-12-16

2. Hall R., Cenozoic geological and plate tectonic evolution of SE Asia and the SW Pacific: computer-based reconstructions, model and animations, Journal of Asian earth sciences, 2002, V. 20, no. 4, pp. 353–431, DOI: https://doi.org/10.1016/S1367-9120(01)00069-4

3. Fyhn M.B.W., Boldreel L.O., Nielsen L.H., Geological development of the Central and South Vietnamese margin: Implications for the establishment of the South China Sea, Indochinese escape tectonics and Cenozoic volcanism, Tectonophysics, 2009, V. 478, no. 3–4, pp. 184–214, DOI: https://doi.org/10.1016/j.tecto.2009.08.002

4. Phong Van Phung et al., Fault seal capacity study for potential cluster prospects in Song Hong Basin, Vietnam, International Journal of Applied Engineering Research, 2018, V. 13, no. 5, pp. 2458–2467.

The article addresses the shift of geological exploration focus from the barrier carbonate massifs of the Sarapul depression of the Kama-Kinel system (Udmurtia) toward the near terraces of the Late Devonian-Tournaisian paleoshelf. Within the latter, widespread local organogenic structures of Famennian age were observed, traditionally associated with the oil and gas potential of reservoirs within the structures enclosing them in carbonate deposits of the Middle, Lower Tournaisian and Upper Famennian substages. Recent exploratory drilling at the Sharkansky site, with complete penetration of Frasnian-Famennian deposits in one of the aforementioned structures, confirmed the forecast of commercial oil potential in the Lower Famennian reservoirs and outlined the productivity potential of the Middle Famennian section. A general analysis of accumulated data on the Volga-Ural petroleum province shows that, within the ridges of swell-like uplifts, there are almost no deposits with accumulations in the lower half of the Famennian stage, but they are widely spread in offshore paleoshelf areas. A decrease (subsidence) of the oil-bearing stage is noted with distance from the barrier swells toward the shallow shelf. For the territory of Udmurtia, two types of structures were identified based on their genesis: associated with draping of submeridional swells and biohermal bodies. For the latter, the main characteristics and criteria for oil potential were outlined.

References

1. Mirnov R.V., Chanysheva L.N., Experience of using sequence stratigraphic approach for detailed study of upper Devonian-Tournaisian clinoform complex of Aktanysh-Chishminsky trough (In Russ.), Georesursy, 2025, no. 27(1), pp. 284–298, DOI: https://doi.org/10.18599/grs.2025.1.28

2. Savel’ev V.A., Neftegazonosnost’ i perspektivy osvoeniya resursov nefti Udmurtskoy Respubliki (Oil and gas potential and prospects of development of oil resources of the Udmurt Republic), Moscow–Izhevsk: Publ. of Institute of Computer Science, 2003, 287 p.

3. Chikhirin A.A., Shostak A.V., Kirillov K.A. et al., Perspektivy poiska litologicheskikh zalezhey v depressionnykh tolshchakh vypolneniya progibov Kamsko-Kinel’skoy sistemy v predelakh Udmurtskoy Respubliki (Prospects for searching for lithological deposits in depression strata filling the troughs of the Kama-Kinel system within the Udmurt Republic), Collected papers “Novye idei v geologii nefti i gaza – 2021” (New Ideas in Oil and Gas Geology – 2021), Moscow: Pero Publ., 2021, pp. 652–656.

4. Vilesov A.P., Sedimentological grading of upper Devonian carbonate bodies of different scales is a condition for reaching a new level of exploration in the Volga-Ural petroleum province (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2021, no. 11, pp. 76–81, DOI: https://doi.org/10.24887/0028-2448-2021-11-76-81

5. Dentskevich I.A., Oshchepkov V.A., Patterns of oil deposit distribution in the marginal zones of the Mukhanovo-Erokhovsky trough (In Russ.), Geologiya nefti i gaza, 1989, no. 5, pp. 21–23.

6. Shakirov V.A., Nikitin Yu.I., Vilesov A.P. et al., A new direction of exploration of oil deposits on the Bobrovsko-Pokrovsky arch (Orenburg region) (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2016, no. 12, pp. 90–94.

7. Lozin E.V., Work out in detail of Fammenian carbonates geology at platform Bashkortostan in connection their new oil and gas perspectives (In Russ.), Ekspozitsiya Neft’ Gaz, 2022, no. 3, pp. 11–15. – https://doi.org/10.24412/2076-6785-2022-3-11-15

8. Chikhirin A.A., Shostak A.V., Kirillov K.A., Prospect of oil potential of late Frasnian-Tournaisian sediments within the Udmurt-Perm paleoshelf (In Russ.), Uspekhi sovremennogo estestvoznaniya, 2021, no. 8, pp. 91–98, DOI: https://doi.org/10.17513/use.37676

At the Verkhnechonsky oil and gas condensate field, brine-saturated reservoirs containing lithium and other valuable elements are concentrated in both subsalt and inter-salt complexes. Subsalt complexes have been operated for 17 years using hydrocarbon feedstock with the reservoir pressure maintenance system, which leads to dilution of concentrations of valuable components in reservoir waters, the Osinsky horizon is used as a gas storage, and there are no reservoir waters in the Preobrazhenskoye horizon. The most likely objects for industrial development of hydromineral raw materials are the deposits of the Belskaya and Bulayskaya suites of the Lower Cambrian. Despite the large number of production and exploration wells, level of their exploration remains low. Basic information about the structure of promising complexes is provided by modern wells with a full range of well logging, 3D seismic and near-field transient electrical sounding method. Intrusive magmatism is manifested at Verkhnechonsky field which contributed to an increase in the mineralization of brines, including an increase in the concentration of lithium during the stages of tectonic-magmatic activation due to fluid and hydrothermal effects. Granite-gneiss domes are considered as an additional source of lithium. Based on a comprehensive analysis of drilling, borehole and surface geophysics data, subvertical through-leaching zones, karst, subsidence pools and other objects were identified indicating active hydrothermal exploration of the studied sediments by deep fluids. The objects and zones identified at the level of the Khristoforovsky, Atovsky and Birkinsky horizons provide grounds for predicting the presence of highly mineralized brines, suitable for industrial development.

References

1. Vakhromeev A.G., Geochemistry of rare earth elements in concentrated brines of the southern Siberian platform (In Russ.), Geologiya i minerageniya yuga Sibiri: vestnik GeoIGU, 2005, no. 4, pp. 67–73.1.

2. Vakhromeev A.G., Osobennosti gidrogeologicheskikh usloviy Verkhnechonskogo gazoneftyanogo mestorozhdeniya (Features of hydrogeological conditions of the Verkhnechonskoye gas and oil field), Proceedings of XII conference of young researchers in geology and geophysics of Eastern Siberia, Irkutsk, 1986.

3. Akhiyarov A.V., Semenova K.M., The Belsko-Bulaysky halogen-carbonate complex and its lithofacies and stratigraphic analogues within the Lena-Tunguska oil and gas province: oil and gas potential prospects and possible complications during drilling (In Russ.), Vesti gazovoy nauki, 2013, no. 5(16), pp. 253–264.

4. Fomin A.M., Moiseev S.A., Petroleum prospects and characteristics of productive units of the Cambrian inter-salt section belonging to the central part of the Lena-Tunguska petroleum province (In Russ.), Neftegazovaya geologiya. Teoriya i praktika, 2019, V. 14, no. 3, DOI: https://doi.org/10.17353/2070-5379/26_2019

5. Mitrofanova N.N., Boldyrev V.I., Korobeynikov N.K. et al., Gosudarstvennaya geologicheskaya karta Rossiyskoy Federatsii. Masshtab 1: 1 000 000 (tret’e pokolenie). Seriya Aldano-Zabaykal’skaya (State geological map of the Russian Federation. Scale 1:1,000,000 (third generation). Aldan-Transbaikal Series), St. Petersburg: Publ. of VSEGEI, 2012, 607 p.

6. Kamaletdinov M.A., Sizykh V.I., Kazantseva T.T. et al., Thrust tectonics of the East European and Siberian platforms (comparative characteristics and significance for oil and gas potential) (In Russ.), Geologiya. Izvestiya otdeleniya nauk o zemle i prirodnykh resursov, 2000, no. 5, pp. 46–60.

7. Skripin A.I., Alekseev A.B., Evolution of trap magmatism in the southern part of the Siberian platform (In Russ.), Geologiya i geofizika, 1981, no. 11, pp. 12–17.

8. Fon-der-Flaass G.S., Nikulin V.I., Atlas struktur rudnykh poley zhelezorudnykh mestorozhdeniy (Atlas of ore field structures of iron ore deposits), Irkutsk: Publ. of Irkutsk University, 2000, 192 p.

9. Kiryukhin A.V., Geotermoflyuidomekhanika gidrotermal’nykh, vulkanicheskikh i uglevodorodnykh sistem (Geothermofluid mechanics of hydrothermal, volcanic and hydrocarbon systems), St. Petersburg: Eko-Vektor Ay-Pi Publ., 2020, 431 p.

10. Valeev R.R., Kolesnikov D.V., Buddo I.V. et al., An approach to the water shortage problem solution for a reservoir pressure maintenance of oil fields in the Eastern Siberia (on the example of Srednebotuobinsky oil and gas-condensate field) (In Russ.), Geologiya, geofizika i razrabotka neftyanykh i gazovykh mestorozhdeniy, 2019, no. 1, pp. 55–67, DOI: https://doi.org/10.30713/2413-5011-2019-1-55-67

11. Vakhromeev A.G., Smirnov A.S., Danilova M.A. et al., Metalliferous brines of the south of the Siberian platform and the problems of their industrial development (In Russ.), Interekspo Geo-Sibir’, 2024, V. 2, no. 1, pp. 21–25, DOI: https://doi.org/10.33764/2618-981X-2024-2-1-21-25

12. Vakhromeev A.G., Zelinskaya E.V., Litvinova I.V., Pogrebnaya D.A., Model of secondary concentration of lithium-bearing brines in boiling fluid systems of magmatogenic-sedimentary basins of the hydromineral province of the Siberian platform (In Russ.), Proceedings of Geothermal Volcanology Workshop Petropavlovsk-Kamchatsky, Russia, September 4–10, 2023, pp. 15–20.

13. Romanyuk T.V., Tkachev A.V., Geodinamicheskiy stsenariy formirovaniya krupneyshikh mirovykh miotsen-chetvertichnykh bor-litienosnykh provintsiy (Geodynamic scenario for the formation of the world’s largest Miocene-Quaternary boron-lithium-bearing provinces), Moscow: Svetoch Plyus Publ., 2010, 304 p.

14. Vladimirov A.G. et al., Geochemical tendencies of lithium concentration in the earths crust and above its ground surface (In Russ.), Geologiya i mineral’no-syr’evye resursy Sibiri, 2014, no. S3-1, pp. 59–62.

15. Karikh T.M., Ivanyuk V.V., Nemchinova M.B. et al., Material composition of Verkhnechonsky field basement rocks and their reflection in the “basement–sedimentary cover” surface structure by seismic data (Siberian platform) (In Russ.), Geologiya, geofizika i razrabotka neftyanykh i gazovykh mestorozhdeniy, 2013, no. 12, pp. 13–21.

16. Donskaya T.V., Ranneproterozoyskiy granitoidnyy magmatizm Sibirskogo kratona (Early Proterozoic granitoid magmatism of the Siberian craton): thesis of doctor of geological and mineralogical science, Irkutsk, 2019.

17. Kvachko S.K., Gubina E.A., Tikhonova K.A. et al., Strukturno-veshchestvennye kompleksy kristallicheskogo fundamenta tsentral’noy chasti Nepsko-Botuobinskoy anteklizy i ikh svyaz’ s neftegazonosnost’yu (Structural and material complexes of the crystalline basement of the central part of the Nepa-Botuoba anteclise and their relationship with oil and gas potential), Proceedings of 7th scientific and practical conference “GeoBaykal 2022”, Irkutsk, 2023, pp. 18-22.

18. Geokhimiya, minerageniya i geneticheskie tipy mestorozhdeniy redkikh elementov (Geochemistry, minerageny and genetic types of rare element deposits), Part 1. Geokhimiya redkikh elementov (Geochemistry of rare elements), Moscow: Nauka Publ., 1964.

19. Miroshnikova L.K., Features of the geochemical structure of the Vetkinskaya blast pipe at the southwestern end of the Norilsk plateau (In Russ.), Izvestiya Sibirskogo otdeleniya RAEN. Geologiya, poiski i razvedka rudnykh mestorozhdeniy, 2008, no. 7(33), pp. 85–96.

20. Sergeeva A.V., Vakhromeev A.G., Kiryukhin A.V. et al., Interaction of magma and salt deposits as a stage in the formation of extremely saturated rare-metal brines of the Siberian platform (In Russ.), Proceedings of Geothermal Volcanology Workshop 2024, Petropavlovsk-Kamchatskiy, 02–08 September 2024, Petropavlovsk-Kamchatskiy: Publ. of Institute of Volcanology and Seismology, Far Eastern Branch of the Russian Academy of Sciences, 2024, pp. 108-111.

The paper presents the results of a comprehensive petrophysical study of siltstone–sandstone rocks of the Gazsalin member of the Kuznetsov formation of Turonian age. The analysis performed is based on the interpretation of well logging data as well as laboratory core studies from six wells located within three fields of the Russko-Chasel megaswell. It is established that the studied deposits are characterized by pronounced thin bedding, high lithological heterogeneity, and significant clay content, which results in a combination of high porosity and extremely low permeability. It is shown that standard well logging methods have limited vertical resolution when applied to thinly bedded clayey siltstone–sandstone rocks and do not enable reliable estimation of the effective thickness of reservoir laminae. The integration of neutron and density logging data, together with X-ray diffraction analysis of clay minerals, enabled to refine the clay volume model and improve the reliability of porosity calculations. The applicability of the classical Archie model was evaluated, revealing instability of its parameters across different wells. Analysis of core capillary pressure data and residual water distribution, combined with clay mineralogical data, enabled refinement of electrical model parameters, representing an important step toward constructing a reliable petrophysical model of the Turonian deposits.

References

1. Edelman I., Ivantsov N., Shandrygin A. et al., Approaches to development of high-viscosity oil fields in arctic conditions using the example of the Russkoe field

(In Russ.), SPE-149917-MS, 2011, DOI: https://doi.org/10.2118/149917-MS

2. Agalakov S.E., Kudamanov A.I., Marinov V.A., Facies model of the Western Siberia Upper Cretaceous (In Russ.), Interekspo GEO-Sibir’, 2017, V. 2, no. 1, pp. 101–105.

3. Kontorovich A.E., Ershov S.V., Kazanenkov V.A. et al., Cretaceous paleogeography of the West Siberian sedimentary basin (In Russ.), Geologiya i geofizika = Russian Geology and Geophysics, 2014, V. 55, no. 5–6, pp. 745–776, DOI: https://doi.org/10.15372/GiG20140504

4. Kudamanov A.I., Agalakov S.E., Marinov V.A., The problems of Turonian-Early Coniacian sedimentation within the boundaries of the West Siberian plate (In Russ.), Geologiya, geofizika i razrabotka neftyanykh i gazovykh mestorozhdeniy, 2018, no. 7, pp. 19–26, DOI: https://doi.org/10.30713/2413-5011-2018-7-19-26

5. Kudamanov A.I., Agalakov S.E., Marinov V.A. et al., Traces of tectonic control sedimentations accumulated during the Turonian age in the Western Siberia (In Russ.), Geologiya, geofizika i razrabotka neftyanykh i gazovykh mestorozhdeniy, 2020, no. 10(346), pp. 12–21, DOI: https://doi.org/10.30713/2413-5011-2020-10(346)-12-21

6. Avramenko E.B., Grishchenko M.A., Oshnyakov I.O., Kudamanov A.I., Conceptual geological model of Turonian sediments on the example of the Kharampurskoye field in Western Siberia (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2019, no. 11, pp. 82–87, DOI: https://doi.org/10.24887/0028-2448-2019-11-82-87

7. Loznyuk O.A., Kuziv K.B., Kiselev A.N. et al., Main principles of reserves estimation and reservoir engineering in low-permeable Turonian gas reservoirs at Rosneft assets (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2021, no. 11, pp. 32–38, DOI: https://doi.org/10.24887/0028-2448-2021-11-32-38

8. Mal’shakov A.V., Oshnyakov I.O., Kuznetsov E.G. et al., Innovative approaches to study heterogeneous anisotropic reservoirs of Turonian deposits for reliable assessment of reservoir properties (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2016, no. 11, pp. 18–22.

9. Archie G.E., The electrical resistivity log as an aid in determining some reservoir characteristics, Transactions of the AIME, 1942, V. 146, pp. 54–67,

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

10. Waxman M.H., Smits L.J.M., Electrical conductivities in oil-bearing shaly sands, Society of Petroleum Engineers Journal, 1968, V. 8, no. 2, pp. 107–122,

DOI: https://doi.org/10.2118/1863-A

11. Juhasz I., Normalised Qv – The key to shaly sand evaluation using the Waxman-Smits equation in the absence of core data, Proceedings of SPWLA 22nd Annual Logging Symposium, Mexico City, Mexico, June 23–26, 1981.

Due to the increasing complexity of hydrocarbon reserve structures and the increasing difficulty of geological exploration work, the tasks of increasing the accuracy and reliability of data on the properties of reservoir fluids used to calculate hydrocarbon reserves, develop design solutions, and perform technical and economic assessments of development efficiency, including the assessment of capital investments and operating costs during field development, are becoming increasingly important. The only way to obtain such information is by collecting representative samples of formation fluids. A sample is considered representative if its component composition is identical to that of the formation fluid. The optimal choice for collecting representative downhole formation fluid samples is the use of flow-through downhole samplers. An important factor in ensuring the operability of electronically controlled samplers is testing the functionality of the power supply elements during equipment preparation. Absolutely all power supply elements should be depassivated before they can be used. High-pressure gas sampling is performed during a stabilized well flow regime from a gas separator or from the gas line upstream of a critical flow prover (orifice meter). For the sampling, storage, and transportation of gas and gas condensate under pressure, shatter-proof metal-composite cylinders are used. These cylinders enable the reliable preservation of the collected fluid until laboratory analysis is conducted, provided that the requirements for transportation, operation, maintenance, and repair are met.

References

1. Ostroukhov N.S., Rassokhin A.S., Karnachev D.V., Domestic thief tubes (In Russ.), Vesti gazovoy nauki, 2016, no. 4, pp. 181–185.

2. OST 153-39.2-048-2003. Neft’. Tipovoe issledovanie plastovykh flyuidov i separirovannykh neftey. Ob»em issledovaniy i formy predstavleniya rezul’tatov (Oil. Standard Study of Reservoir Fluids and Separated Oils. Scope of Study and Results Presentation Forms.), Moscow, 2003, 94 p.

3. STO RMNTK 153-39.2-002-2003. Neft’. Otbor
prob plastovykh flyuidov (Oil. Reservoir fluid sampling), Moscow, 2003.

ZARUBEZHNEFT-Dobycha Kharyaga LLC has been successfully developing technologies for multilateral construction of directional and horizontal production wells since 2020 in terms of completion complexity according to Technology Advancement for Multi-Laterals classification (TAML) starting from TAML-1 to TAML-3, including well designs such as Fishbone and Dovetail. The article discusses issues related to drilling of multilateral and multi-borehole directional and horizontal wells at the Kharyaginskoye field of the Timan-Pechora oil and gas province. A brief history of the development of the Kharyaginskoye oil field and the history of the development of technologies for multilateral wells drilling at ZARUBEZHNEFT-Dobycha Kharyaga LLC is presented. The article describes the need for technologies in the modern oil and gas industry in terms of complex deposits development with hard-to-recover hydrocarbon reserves in low-permeability reservoirs. The history of the development of the TAML classification of multilateral wells is given. The classification of complexity levels for the construction of TAML multilateral wells is presented, which includes six levels - from the simplest without mechanical connection of the trunks to completely isolated boreholes with the possibility of independent operation of each. The distinctive features of each of the six difficulty levels of drilling multilateral and multi-borehole wells are given. Data on drilled wells at the Kharyaginskoye field is presented, including technologies used and results obtained using various well designs.

References

1. Guseynova E.L., Guseynov E.M., Multi-lateral wells drilling using rapid technology (In Russ.), Neftegazovoe delo, 2018, V. 16, no. 4, pp. 6–12,

DOI: https://doi.org/10.17122/ngdelo-2018-4-6-12

2. Klassifikatsiya mnogostvol’nykh tekhnologiy TAML (Classification of multi-barrel TAML technologies), URL: https://neftegaz.ru/tech-library/burenie/142482-klassifikatsiya-taml

3. Zaikin I.P., Kempf K.V., Shkarin D.V., Experience in constructing a multilateral well in Zarubezhneft JSC (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2017, no. 8,

pp. 21–24, DOI: https://doi.org/10.24887/0028-2448-2017-8-21-24

Pilot field tests of a single-component polymer gelling solution were conducted at the pilot areas of one of the fields in Eastern Siberia to ensure conformance control in injection wells and to increase oil recovery. The net-reservoir sections show high permeability and high heterogeneity, which is the cause for premature breakthroughs of injected water to production wells. The reservoir stimulation technology using a single-component gelling solution was selected based on the results of laboratory studies in free volumes and flow experiments on heterogeneous highly permeable reservoir models using high-salinity formation and injected water. It was established that the flow resistance factor increased during injection of the agent solution up to 56,7, and the residual resistance factor was equal to 9,4. The maximum increase achieved in the displacement efficiency during flow experiments was 0,087. Pilot field tests conducted in three injection wells demonstrated high performance of the technology. The duration of the technological effect was 10-12 months, the average specific incremental recovery per calendar year was 2,177 tons/well job, the total incremental oil recovery for the entire observation period (13 months) was 41,5 thousand tons. Based on the results of well interventions, the tested polymer gelling solution was considered promising for further application.

References

1. Fonakov E.S., Sattarov R.I., Malygin A.V., ATREN WSO – Mirrico Group’s solution for water influx control and enhanced oil recovery (In Russ.), Neftegazovaya vertikal’, 2017, no. 19(416), pp. 80–84.

2. Ron’zhin E.Yu., Kuderov S.A., Gaynanshina A.R. et al., Practical results of injectivity conformance control method application and the use of Atren WSO chemical at the objects of “Orenburgneft” JSC (In Russ.), Neft’. Gaz. Novatsii, 2019, no. 7, pp. 54–56.

3. MR-01-001-01. Metodika otsenki tekhnologicheskoy effektivnosti metodov povysheniya nefteotdachi plastov (Methodology for assessing the technological efficiency of enhanced oil recovery methods), Moscow: Ministry of Energy of the Russian Federation, 2003.

4. RD-153-39.1-004-96. Metodicheskoe rukovodstvo po otsenke tekhnologicheskoy effektivnosti i primeneniya metodov uvelicheniya nefteotdachi (Guidelines for assessing the technological effectiveness of enhanced oil recovery methods), Moscow: Ministry of Energy of the Russian Federation, 1996.

5. Morozovskiy N., Kanevskaya R., Yulmukhametov D. et al., Verification technique of technical efficiency of physical-chemical EOR (In Russ.), SPE-191573-18RPTC-MS, 2018, DOI: https://doi.org/10.2118/191573-18RPTC-MS

The paper addresses the problem of selecting an optimal development system for oil and gas fields using horizontal wells (HW), multilateral wells (MLW), and horizontal wells completed with multi-stage hydraulic fracturing (MSHF) under a wide range of geological conditions. Based on more than 25 years of reservoir simulation and exploration experience of fields in Western and Eastern Siberia, on the Arctic shelf, and a number of onshore fields, a matrix-type decision algorithm that integrates key geological and technological parameters into a single framework was developed. The algorithm explicitly accounts for fluid saturation type, permeability anisotropy, lateral and vertical connectivity, absolute permeability level, reservoir heterogeneity, oil viscosity and the proximity of fluid contacts that enables to significantly narrow the space of options and to focus modelling efforts on a limited set of development scenarios combining well pattern geometry, completion types and reservoir pressure maintenance systems. Recommended ranges are provided for horizontal section length, number of laterals in MLW, and number of MSHF stages, as well as for the applicability of line-drive, staggered and radial patterns in thin oil rims, gas-oil zones and low-permeability reservoirs. The proposed workflow helps to reduce the number of simulation runs, accelerates the selection of robust development concepts for unconventional and marginal resources and ultimately improves the capital efficiency and recovery factors of complex oil and gas fields.

References

1. Rossiyskiy rynok bureniya neftyanykh skvazhin: tekushchee sostoyanie i stsenarii razvitiya do 2030 goda (The Russian oil drilling market: Current status and development scenarios to 2030), Moscow: Publ. of RPI, 2024, 119 p.

2. Tuykin T.A., Gryazov A.A., Fazlutdinov V.I., Povyshenie effektivnosti tekhnologiy zakanchivaya i MGRP (Improving the efficiency of finishing and multistage hydraulic fracturing technologies), Proceedings of Scientific and technical conference “Innovatsionnye tekhnologii v dobyche uglevodorodov” (Innovative technologies in hydrocarbon production), Ufa, 20–23 May 2025, Ufa, 2025.

3. Khasanov M.M., Ushmaev O.S., Samolovov D.A. et al., Estimation of cost effective oil thickness of oil rims developed with horizontal wells (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2013, no. 12, pp. 44–47.

4. Bilinchuk A.V., Rustamov I.F., Bulgakov E.Yu. et al., Gazprom neft: Drilling management centre case study (Integrated operating management systems), ROGTEC Magazine, 2018, no. 9, pp. 36–44.

5. Sugaipov D.A., Vorob’eva G.N., Galeev R.R. et al., Selecting the optimal development system (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2019, no. 6, pp. 38–40, DOI: https://doi.org/10.24887/0028-2448-2019-6-38-40

6. Sugaipov D.A., Rustamov I.F., Ushmaev O.S. et al., Results of multilateral drilling on Novoportovskoye field (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2017,

no. 12, pp. 35–36, DOI: https://doi.org/10.24887/0028-2448-2017-12-35-36

7. Sugaipov D.A., Bazhenov D.Yu., Devyat’yarov S.S. et al., ERA:Production – an integrated platform for increasing the efficiency of the operation of the artificial lift and oil fields (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2017, no. 12, pp. 60–63, DOI: https://doi.org/10.24887/0028-2448-2017-12-60-63

8. Sugaipov D.A., Rustamov I.F., Ushmaev O.S. et al., Multilateral wells application in continental facies of Vostochno-Messoyakhskoye field (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2017, no. 12, pp. 49–51, DOI: https://doi.org/10.24887/0028-2448-2017-12-49-51

9. Sugaipov D.A., Nekhaev S.A., Perevozkin I.V. et al., Optimization of well pattern for oil rim fields (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2019, no. 12,

pp. 44–46, DOI: https://doi.org/10.24887/0028-2448-2019-12-44-46

10. Sugaipov D.A., Kovalenko I.V., Kuznetsov S.V. et al., Development of the oil fringe of the Yaro-Yahinskoye field by horizontal wells in conditions of layered reservoirs with a high degree of secondary changes (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2018, no. 12, pp. 54–56, DOI: https://doi.org/10.24887/0028-2448-2018-12-54-56

11. Sugaipov D.A., Yakovlev A.A., Galyautdinov I.M. et al., Improving of new wells drilling efficiency based on the selection of optimal drilling pattern for the south-western block of Orenburg oil, gas and condensate field (In Russ.), PROneft’. Professional’no o nefti, 2019, no. 1, pp. 29–33, DOI: https://doi.org/10.24887/2587-7399-2019-1-29-33

12. Sugaipov D.A., Ushmaev O.S., Bazhenov D.Yu. et al., Approaches to justifying combined development systems: a case study of NP8 and J2-6 reservoirs of Novoportovskoye oil-gas-condensate field (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2018, no. 12, pp. 26–29, DOI: https://doi.org/10.24887/0028-2448-2018-12-26-29

13. Sugaipov D.A., Lyapin V.V., Reshetnikov D.A. et al., Selecting optimal technology for wells completion in the oil rims of continental genesis on the example of layers PK1-3 of the Vostochno-Messoyakhskoye and Tazovskoye fields (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2019, no. 4, pp. 66–69,

DOI: https://doi.org/10.24887/0028-2448-2019-4-66-69

14. Sugaipov D.A., Savel’ev V.A., Mirsaetov O.M., Vliyanie parametrov razrabotki na okhvat gorizontal’no razburennogo plasta drenirovaniem i vozdeystviem v zavisimosti ot geologo-fizicheskikh faktorov (The influence of development parameters on the coverage of a horizontally drilled formation by drainage and impact depending on geological and physical factors), Proceedings of The Second Republican Scientific and Practical Conference “Povyshenie effektivnosti razrabotki trudnoizvlekaemykh zapasov nefti” (Improving the efficiency of developing hard-to-recover oil reserves), 4–5 November 2003, Izhevsk, 2003, pp. 65–72.

15. Sugaipov D.A., Savel’ev V.A., Mirsaetov O.M., Volkov A.Ya., K voprosu o vozmozhnosti primeneniya nagnetatel’nykh gorizontal’nykh skvazhin dlya razrabotki neftyanykh mestorozhdeniy (On the possibility of using horizontal injection wells for the development of oil fields), Proceedings of The Second Republican Scientific and Practical Conference “Aktual’nye zadachi vyyavleniya i realizatsii potentsial’nykh vozmozhnostey gorizontal’nykh tekhnologiy nefteizvlecheniya” (Current challenges in identifying and implementing the potential of horizontal oil recovery technologies), 18–19 December 2003, Kazan, pp. 28–30.

16. Savel’ev V.A, Sugaipov D.A., Evaluation of the efficiency of oil field development using horizontal production and injection wells (In Russ.), Vestnik Udmurtskogo Universiteta, 2002, no. 8, pp. 87–102.

17. Sugaipov D.A., Savel’ev V.A., Volkov A.Ya., Mirsaetov O.M., On the optimal location of horizontal wells in oil field development (In Russ.), Neft’ i burenie, 2003, no. 12, pp. 15–22.

18. Mustafin A.R., Development of approaches to the design of completion structures for horizontal and multilateral wells with hydraulic fracturing for the development of hard-to-recover reserves (In Russ.), Inzhenernaya praktika, 2005, no. 1.

19. Khasanov M.M., Ushmaev O.S., Nekhaev S.A., Karamutdinova D.M., Selection of optimal parameters of oil field development (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2012, no. 12, pp. 26–31.

20. Khasanov M.M., Ushmaev O.S., Samolovov D.A. et al., A method to determine optimum well spacing for oil rims gas-oil zones, SPE-166898-MS, 2013,

DOI: https://doi.org/10.2118/166898-ms

21. Govzich A.N., Bilinchuk A.V., Fayzullin I.G., Horizontal well multi-stage fracturing -Gazprom Neft JSC experience (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2012, no. 12, pp. 59-61.

22. Khasanov M.M., Ushmaev O.S., Samolovov D.A. et al., A method to determine optimum well spacing for oil rims gas-oil zones (In Russ.), SPE-166898-MS, 2013, DOI: https://doi.org/10.2118/166898-MS

The problem of choosing a rational bottom-hole pressure (BHP) in oil wells in Western Siberia drilled on traditional terrigenous reservoirs is considered. Data on the operating modes of about 1500 wells of 65 facilities of 20 oil fields in Western Siberia were processed. The geological and physical characteristics of the studied productive strata are presented. The average values for groups of flooded wells in the BHP ranges relative to the saturation pressure (SP) are determined: more than 0,9 BHP; (0,7-0,9 BHP); (0,7-0,5 BHP); less than 0,5 BHP. Examples of sustainable operation of flooded wells operating at very low BHP < 0,5 are shown. The average technological parameters were determined by the groups of wells: the depth of the pump descent, the dynamic level, the flow rates of oil and liquid, the water cut of products, the initial and current reservoir pressures, BHP, productivity coefficients, etc. An example is given of successful development of a low-water section of the ultra-low-permeability reservoir AC10-12 of the Priobskoye field at BHP twice as low as SP. By constructing sliding displacement characteristics, the positive effect of reducing BHP (significantly lower than SP) on the value of recoverable oil reserves was estimated. The long-term experience of operating flooded wells in Western Siberia at low BHP was recognized as successful and highly effective.

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2. Lebedev S.A., Usenko V.F., Andreev E.A., Issledovanie i ustanovlenie tekhnologicheskogo rezhima raboty neftyanykh skvazhin so snizheniem zaboynogo davleniya nizhe davleniya nasyshcheniya v devonskikh plastakh Tuymazinskogo neftyanogo mestorozhdeniya i plaste DIV Konstantinovskogo mestorozhdeniya (Study and establishment of a technological operating mode for oil wells with a decrease in bottomhole pressure below the saturation pressure in the Devonian formations of the Tuymazinskoye oil field and the DIV formation of the Konstantinovskoye field), NTS po dobyche nefti, 1959, V. 3, pp. 82–83.

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11. Volkov M.G., Presnyakov A.Yu., Klyushin I.G. et al., Monitoring and management the abnormal well stocks based on the Information System Mekhfond of Rosneft Oil Company (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2021, no. 2, pp. 90–94, DOI: https://doi.org/10.24887/0028-2448-2021-2-90-94

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13. Cheremisin N.A., Sonich V.P., Klimov A.A., Vliyanie na nefteotdachu povyshennykh depressiy i perspektivy ikh primeneniya (The impact of increased depressions on oil recovery and the prospects for their application), Proceedings of 5th scientific and practical conference “Puti realizatsii neftegazovogo potentsiala KhMAO” (Ways to realize the oil and gas potential of the Khanty-Mansi Autonomous Okrug), Khanty-Mansiysk, 2002, pp. 182–186.

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pp. 30–39, DOI: https://doi.org/10.24887/0028-2448-2019-7-36-39

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21. Amerkhanov R.M., Gilyazov A.Kh., D’yakonov A.A. et al., Optimization of production well operation through combination of engineering approach, computer programming and machine learning methods (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2024, no. 8, pp. 94–99, DOI: https://doi.org/10.24887/0028-2448-2024-8-94-99

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A comprehensive technology for simultaneous water and gas (SWAG) injection with associated gas utilization from the annulus of production pumping wells was proposed. The developed pump-ejector system with a booster pump for SWAG injection was installed in one of the well pads at the Romashkinskoye field. The implementation of a dual-operation unit with an electric submersible pump (ESP) and a sucker rod pump (SRP) in one of the pad's wells for water recovery using ESP of saline water with a density of 1180 kg/m3 from Devonian formations located below the existing perforated interval where oil is produced by the SRP unit enabled a continuous supply of highly mineralized saline formation water to the SWAG system. There is no hydrate formation with the SWAG technology. The pump-ejector system operates reliably when pumping a water-gas mixture into an injection well in 24-hour operation. In addition to increasing the injection pressure to 14 MPa, it also heats the flow to 27-32 °C. In addition to the delayed increase in oil recovery due to SWAG, the implementation of a pump-ejector system with annular gas pumping achieves an immediate increase in fluid production by reducing the annular pressure in the production pumping wells. Another advantage of the SWAG technology is that, along with water and annular associated petroleum gas, hydrocarbon gas contained in the highly mineralized formation water produced by the ESP unit is also injected into the injection well, which shall further enhance oil recovery.

References

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he paper under consideration summarizes the results of a group of authors' work on monitoring, analyzing, and managing well stock in complex geological and technological conditions. Application of a Model-Based System Engineering (MBSE) approach to managing the artificial lifting process is considered as the core concept. It is shown that traditional management methods based on the isolated consideration of individual objects are ineffective when operating wells in hard-to-recover reserves that are characterized by low-permeability, high water cut, and unstable flow regimes. The proposed approach implements a hierarchical system of interconnected models: from data models and physical models of wells and infrastructure to constraint models and optimization models. The key principles of the methodology are the following: structured system decomposition by levels, requirements traceability from the supersystem level down to specific control actions, model interoperability through standardized interfaces, and validation and verification at each level of the model hierarchy. Practical implementation was carried out through the integration of an intelligent automated gas-lift gas flow control system and the installation of an electric submersible pump, providing group optimization of well stock operations accounting for mutual influence of wells through common gathering infrastructure. Results of applying the approach to stabilize well network operations are presented, demonstrating the possibility of achieving systemic effects through application of the proposed approach.

References

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11. Petrushin M.A. et al., Modeling of mechanized wells operating in alternating frequency mode considering check valve leakage and practical application for efficient well management, SPE-227858-MS, 2025, DOI: https://doi.org/10.2118/227858-MS

12. Yudin E.V., Gorbacheva V.N., Smirnov N.A., Modeling and optimization of wells operating modes under annular flow conditions (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2022, no. 11, pp. 122–126, DOI: https://doi.org/10.24887/0028-2448-2022-11-122-126

13. Yudin E.V., Khabibullin R.A., Kobzar’ O.S. et al., Methodology of calculation of fluid partition coefficient in wells equipped with electric submersible pumps under conditions of self-flowing through the annular space (In Russ.), PRONEFT’’. Professional’no o nefti = PROneft. Professionally about Oil, 2025, no. 10(3), pp. 96–106,

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DOI: https://doi.org/10.2118/222942-MS

One of the promising areas for Angarsk Petrochemical Company JSC which is a subsidiary of Rosneft Oil Company is the production of special products for oil production enterprises that experience a shortage of certain resources due to sanctions. These special products include components for drilling mud preparation. The article presents the results of the development of a low-viscosity hydrocarbon base for drilling mud (LVHBDM) with stricter environmental requirements for oil production enterprises at Angarsk Petrochemical Company JSC. According to the quality requirements for LVHBDM for offshore oil production at Sakhalinmorneftegaz-Shelf JSC, a subsidiary of Rosneft PJSC, the aromatic hydrocarbon content should not exceed 0,8 % by weight, and the sulfur content should not exceed 2 mg/kg. At the same time, there are strict requirements for LVHBDM in terms of its performance properties: viscosity, flash and pour points, and the content of organochlorine compounds. As a result of these studies, a technology for producing LVHBDM was developed using combined processes of deep hydrogenation and light hydrocracking of the vacuum distillate from primary oil refining, followed by the separation of the target fraction from the hydrogenate using a distillation unit. The LVHBDM was successfully tested in an oil and gas production company of the Rosneft Oil Company Group. Measures were taken to put the LVHBDM into industrial production. The developed LVHBDM production technology is highly cost-effective.

References

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9. Boyd P.A. et al., New base oil used in low-toxicity oil muds, Journal of petroleum technology, 1985, V. 37, no. 1, pp. 137–142, DOI: https://doi.org/10.2118/12119-PA

10. Mazurov V.A., Reologicheskie svoystva mnogokomponentnykh bufernykh zhidkostey na polisakharidnoy osnove (Rheological properties of multicomponent buffer fluids based on polysaccharides), Collected papers “Neftepromyslovaya khimiya” (Oilfield chemistry), Proceedings of V (International Scientific and Practical Conference (XIII All-Russian Scientific and Practical Conference)), Moscow: Publ. of Gubkin University, 2018, pp. 9–12.

11. Drilling Fluids Market Size, Share and COVID-19 Impact Analysis, By Type, By Application, and Regional Forecast, URL: https://www.fortunebusinessinsights.com/industry-reports/drilling-fluid-market-100401

12. Patent US 7311814 (B2), MPK C10G47/00. Process for the production of hydrocarbon fluids, Inventors: Guyomar P.Y., Theyskens A.A.

13. Patent US 10836968 (B2), MPK C10G69/04. Method for obtaining hydrocarbon solvents with boiling point above 300° C. and pour point lower than or equal to –

25° C, Inventors: Aubry C., Grasso G., Dath J.P.

14. Patent WO 2022029234 (A1), MPK C10G65/08. Process for the production of fluids, Inventors: Ferreira C., Caudrelier F., Benghalem A.

15. Patent RU 2668612 (C1), MPK C09K8/035. Method for producing component for drilling solutions. Inventors: Karpov N.V., Vakhromov N.N., Dutlov E.V., Piskunov A.V., Bubnov M.A., Gudkevich I.V., Borisanov D.V.

16. OGP (International Association of Oil and Gas Producers)/IPIECA (Environmental Conservation Association). Drilling fluids and health risk management: A guide for drilling personnel, managers and health professionals in the oil and gas industry, OGP Report Number, 2009, no. № 396, 60 p.

17. Tiron D.V., Sovershenstvovanie tekhnologii emul’sionnykh rastvorov dlya bureniya skvazhin v usloviyakh povyshennykh zaboynykh temperatur (Improving the technology of emulsion solutions for drilling wells in conditions of elevated bottomhole temperatures): thesis of candidate of technical science. St. Petersburg, 2017.

18. Kameshkov A.V., Gayle A.A., Production of diesel fuels with improved low temperature properties (Review) (In Russ.), Izvestiya SPbGTI(TU), 2015, no. 29, pp. 49–60.

19. Niskovskaya M.Yu., Raskulova T.V., Fereferov M.Yu. et al., Tekhnologiya pererabotki zhidkikh i gazoobraznykh prirodnykh energonositeley (Technology for processing liquid and gaseous natural energy sources), Angarsk: Publ. of Angarsk State Technical University, 2017, 316 p.

20. Dubrovskiy D.A., Kuzora I.E., Leymeter T.D. et al., Development of hydrocarbon basis production technology for drilling muds based on capacities of JSC «ANHK»

(In Russ.), Neftepererabotka i neftekhimiya, 2019, no. 12, pp. 9–14.

21. Kuzora I.E., Stadnik A.V., Development of technology for production of bases for drilling fluids on the basis of available capacities of «ANHK» JSC (In Russ.), Burenie

ineft’, 2021, no. 9, pp. 48.

22. Patent RU 2762672, MPK51 C09K 8/035, C09K 8/34, Method for producing a hydrocarbon base of drilling fluids, Inventors: Zelenskiy K.V., Dubrovskiy D.A., Leymeter T.D., Kuzora I.E., Semenov I.A., Stadnik A.V., Marushchenko I.Yu., Sergeev V.A.

23. Kuzora I.E., Krepostnov D.D., Mayorov V.V., et al., Organization and increase in production volume of domestic basis for hydrocarbon-based solutions (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2025, No. 10, pp. 74-79, DOI: https://doi.org/10.24887/0028-2448-2025-10-74-79

24. Kovalenko M.V., Kuzora I.E., Glebkin N.A. et al., Expansion of raw material resources for transformer oil production (In Russ.), Neftepererabotka i neftekhimiya, 2025, no. 1, pp. 34–39, DOI: https://doi.org/10.24412/0233-5727-2025-1-34-39

The study presents the results of comprehensive experimental investigations of the rheological properties, stability, flow behavior, and destruction of water-in-oil emulsions based on the emulsifier KR-3E grade B and hydrophobic silicon dioxide Orisil M300. The influence of the aqueous phase composition (tap water, calcium chloride solution with a density of 1,15 g/cm3 widely used in well servicing and downhole operations, and their 1:1 mixture) and the concentration of silicon dioxide nanoparticles (0,3, and 5 wt % relative to the hydrocarbon phase) on the key parameters of the emulsion systems was examined. It was established that silicon dioxide acts as an effective thickening agent, significantly increasing the viscosity and stability of the emulsions, particularly in saline environments. Emulsions based on CaCl2 solutions containing 3-5 % of SiO2 nanoparticles demonstrated exceptional thermal stability (showing no phase separation for more than 95 hours at 90 °C) and a time-dependent increase in viscosity. At the same time, such formulations lost flowability at room temperature, which complicates their injection into wells. The most pronounced viscosity-reducing effect on the resulting emulsions was observed for the multipurpose hydrocarbon solvent KR-4R, which proved effective in wellbore treatments. It is shown that using a mixture of tap water and calcium chloride solution enables the formation of Pickering emulsions with an optimal balance of rheological properties and stability, stabilized by solid silicon dioxide nanoparticles.

References

1. Glushchenko V.N., Khizhnyak G.P., Directions for improving the compositions of reverse emulsions for well plugging (In Russ.), Nedropol’zovanie, 2023, V. 23, no. 1,

pp. 44–50, DOI: https://doi.org/10.15593/2712-8008/2023.1.6

2. Nikulin V.Yu., Mukminov R.R., Mukhametov F.Kh. et al., Overview of promising killing technologies in conditions of abnormally low formation pressures and risks of gas breakthrough. Part 1. Technology classification and experience with water-based and hydrocarbon-based thickened liquids (In Russ.), Neftegazovoe delo, 2022,

V. 20, no. 3, pp. 87–96, DOI: https://doi.org/10.17122/ngdelo-2022-3-87-96

3. Bashkirtseva N.Yu., Sladovskaya O.Yu., Rakhmatullin R.R., Primenenie poverkhnostno-aktivnykh veshchestv v protsessakh podgotovki i transportirovki nefti (The use of surfactants in oil preparation and transportation processes), Kazan’: Publ. of Kazan National Research Technological University, 2016, 166 p.

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

5. Bulatov A.I., Kusov G.V., Savenok O.V., Asfal’tosmoloparafinovye otlozheniya i gidratoobrazovaniya: preduprezhdenie i udalenie (Asphalt, resin and paraffin deposits and hydrate formations: prevention and removal), Part 1, Krasnodar: Yug Publ., 2011, 348 p.

6. Fatkhullin K.A., Povyshenie strukturno-mekhanicheskoy prochnosti vodno-neftyanykh emul’siy za schet vvedeniya dioksida kremniya (Increasing the structural and mechanical strength of water-oil emulsions by introducing silicon dioxide), Proceedings of 76th scientific and technical conference of students, postgraduates and young scientists of Ufa State Petroleum Technological University, Part. 1, Ufa: Publ. of USPTU, 2025, 550 p.

7. Jie Yang, Jinsheng Sun, Ren Wang, Yuanzhi Qu, Treatment of drilling fluid waste during oil and gas drilling: a review, Environmental Science and Pollution Research, 2023, V. 30, no. 8, pp. 19662–19682, DOI: https://doi.org/10.1007/s11356-022-25114-x

8. Tadros T.F., Emulsion formation and stability, Weinheim: Wiley-VCH, 2013, 562 p.

9. Israelachvili J.N., Intermolecular and surface forces, 3rd ed., San Diego: Academic Press (Elsevier), 2011, 704 p., DOI: https://doi.org/10.1016/C2011-0-05119-0

10. Caenn R., Darley H.C.H., Gray G.R., Composition and properties of drilling and completion fluids, 7th ed., Oxford: Gulf Professional Publishing (Elsevier), 2017, 1022 p.

11. Karimov R.M., Promyvka truboprovodov vodno-uglevodorodnymi obratnymi emul’siyami solevykh rastvorov i khimreagentov (Flushing of pipelines with water-hydrocarbon reverse emulsions of salt solutions and chemical reagents), Proceedings of XVII International Scientific and Practical Conference “Truboprovodnyy transport– 2022” (Pipeline Transport – 2022), Ufa: Publ. of USPTU, 2022, pp. 93–94.

12. Kuznetsov V.S., Karimov R.M., K voprosu ispol’zovaniya obratnykh emul’siy v zadachakh neftegazovoy otrasli (On the use of inverse emulsions in the oil and gas industry), Proceedings of 75th scientific and technical conference of students, postgraduates and young scientists of Ufa State Petroleum Technological University: edited by Ibragimov I.G., Ufa: Publ. of USPTU, 2024, pp. 266–267.

Hydraulic fracturing is a key technology for increasing the productivity of oil and gas wells. The fracturing fluid plays a crucial role in the efficiency of hydraulic fracturing, which properties affect the geometry of the crack, the design parameters of the treatment, the residual permeability of the propane pack and reservoir, the technological success of the operation, and the predicted efficiency of the work performed. The article presents the results and an assessment of the prospects for the use of hydraulic fracturing fluid based on polyacrylamide (PAM) of domestic production. The scientific novelty of the work lies in a comprehensive experimental approach, including rheological assessment of the liquid, filtration studies of the propane pack, and filtration tests of core from one of the deposits in Eastern Siberia before and after exposure to the studied fracturing fluid. It was established that the modified PAM of domestic production is characterized by a controlled rate of hydration, increased stability and high sand-bearing capacity compared to the previously used guaro-borate systems. It is shown that the coefficient of conductivity recovery of the propane pack after exposure to PAM liquid is 28 % higher compared to the guaro-borate system. The advantages of the system under consideration include a simplified formulation, minimizing the negative impact on the reservoir and propane, as well as reducing the risk of unwanted crack growth in height. The results obtained substantiate the expediency of using domestic PAM as an alternative to imported reagents during hydraulic fracturing at facilities of Gazprom PJSC.

References

1. URL: http://rosfloc.ru/?ysclid=mfpf5hfdox710663087

2. Samoylov A.S., Votchel’ V.A., Sokolov A.F., Parekha A.S., Determination of optimal formulations of hydraulic fracturing fluids for conditions of low reservoir temperatures of the Vendian sediments based on laboratory studies (In Russ.), Neftepromyslovoe delo, 2024, no. 11(671), pp. 38-48.

3. M-01.04.03.03-08. Kontrol’ kachestva zhidkostey GRP na osnove VVSG (Quality control of hydraulic fracturing fluids based on high-viscosity synthetic gelling agents), St. Petersburg: Publ. of Gazpromneft, 2023.

4. Samoylov A.S., Votchel’ V.A., Parekha A.S. et al., Determination and testing of optimal formulations of hydraulic fracturing fluids for reservoirs with a high content of montmorillonite clays (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2024, no. 11, pp. 114–118, DOI: https://doi.org/10.24887/0028-2448-2024-11-114-118

5. GOST 26450.2-85. Rocks. Method for determination of absolute gas permeability coefficient by stationary and non-stationary filtration.

6. Kolesnik S.V., Efimov M.E., Intensification of oil production through the use of hydraulic fracturing fluid based on polyacrylamide (In Russ.), Neftepromyslovoe delo, 2023, no. 9(657), pp. 43–47.

The article presents the results of pilot field tests of the corrosion inhibitor (CI) designated as CI-2. The previously obtained correlation for the presence of CI-2 content in the aqueous phase of transported products from its partition coefficient L under field conditions was tested. It was confirmed that for CI-2 the threshold concentration of partition activation was approximately 25 g/m3. At low concentrations of CI-2 in the aqueous phase, the number of defects in the corrosion control samples visually decreases, while there is a clear stimulation of localized corrosion (LC) on the remaining defects. The effect of a «stockade» was found during the operation of CI-2, expressed in an unstable manifestation of the protective effect of the inhibitor in relation to LC with an increase in the equivalent protective concentration. Increasing the equivalent protective concentration to 110 g/m3 can’t neutralize this effect and ensure the stability of the inhibitor. Corrosion monitoring during field tests, using the double focusing method, enables to fix the ratio of LC on corrosion control samples as an average of 2,5. For one of the oil companies of the West Siberian region, the empirical coefficient of the ratio between maximum LC and average LC is determined to be 2,5-3,0, while the ratio of the rate of LC to the rate of general corrosion is more than 112. To improve the quality of inhibitor protection, it is necessary to use reliable instrumental methods for recording LC. Establishing numerical standards for average and maximum LC rates is essential. It is also important to improve the methodological approaches used in laboratories to select CI with stable effectiveness against LC.

References

1. Yanin E.P., Korroziya kak istochnik zagryazneniya okruzhayushchey sredy (Corrosion as a source of environmental pollution), Moscow: ARSO Publ., 2020, 112 p.

2. Markin A.N., Nizamov R.E., Sukhoverkhov S.V., Neftepromyslovaya khimiya: prakticheskoe rukovodstvo (Oilfield chemistry: A practical guide), Vladivostok: Dal’nauka Publ., 2011, 288 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., Nizamov R.E., CO2-korroziya neftepromyslovogo oborudovaniya (CO2 corrosion of oilfield equipment), Moscow: Publ. of VNIIOENG, 2003, 188 p.

5. Turdymatov A.A., Abdrakhmanov N.Kh., Abdrakhmanova K.N., Vorokhobko V.V., Efficiency of chemical inhibitory protection in fight against internal corrosion of field pipelines (In Russ.), Neftegazovoe delo, 2016, no. 3, pp. 137–156.

6. Serysheva G.S., Analysis of the selection and evaluation of the effectiveness of new brands of corrosion inhibitors at the facilities of the RITEK-Samara-Nafta TPP (In Russ.), Inzhenernaya praktika, 2020, no. 4, pp. 44–46.

7. Savel’ev V.V., Ivanov A.N., Avdeev A.S. et al., Integrated solutions for improving the reliability of Vietsovpetro subsea oil pipelines (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2024, no. 2, pp. 106–110,

DOI: https://doi.org/10.24887/0028-2448-2024-2-106-110

8. Velikzhanina N.V., Korberg P.N., The effectiveness of the implementation of inhibitor protection of high-pressure water pipelines at the fields of TPP Langepasneftegaz of LUKOIL-Western Siberia LLC (In Russ.), Inzhenernaya praktika, 2019, no. 1, pp. 42–47.

9. Tkacheva V.E., Markin A.N., Markin I.A., Presnyakov A.Yu., Local corrosion: calculation in oil field conditions (according to weight measurements) (In Russ.), Praktika protivokorrozionnoy zashchity, 2021, V. 26, no. 1, pp. 28-40,

DOI: https://doi.org/10.31615/j.corros.prot.2021.99.1-3

10. Vtorenko E.A., Valekzhanin I.V., Latypov O.A., Khakimov A.M., Determination of the rate of local corrosion of tubing as a necessary element of corrosion monitoring (In Russ.), KORROZIYa, 2024, no. 4 (105), pp. 40-44,

DOI: https://doi.org/10.24412/2076-6785-2024-4-40-44

11. Fot K.S., Markin A.N., High corrosion inhibitor availability concept: Myth or reality? (In Russ.), Neftegazovoe delo, 2025, V. 23, no. 2, pp. 179–190,

DOI: https://doi.org/10.24412/2076-6785-2024-4-40-44

12. Horsup D.I., Clark J.C., Binks B.P. et al., The fate of oilfield corrosion inhibitors in multiphase systems, CORROSION, 2010, V. 66, no. 3,

DOI: https://doi.org/10.5006/1.3359624

13. Fot K.S., Kolevatov A.N., Zhmaeva E.V. et al., Corrosion inhibitor partition coefficient as a promising tool for effective inhibitory protection (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2025, no. 1, pp. 80–85,

DOI: https://doi.org/10.24887/0028-2448-2025-1-80-85

14. 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

15. Zvezdkina E.M., Zhuravel’ N.G., Lapitskaya E.V. et al., Analysis and ways to improve the efficiency of inhibitor protection of oil field pipelines at the Republican Unitary Enterprise “Production Association “Belorusneft” (In Russ.), Inzhenernaya praktika, 2012, no. 5.

16. Tkacheva V.E., Markin A.N., Medium for local CO2-corrosion laboratory testing (In Russ.), Praktika protivokorrozionnoy zashchity, 2021, V. 26, no. 4,

pp. 7–17, DOI: https://doi.org/10.31615/j.corros.prot.2021.102.4-1

Many oil and gas facilities are located in the permafrost zone, where the urgent task is to reduce capital expenditures (CAPEX). One of the optimization directions in the construction of above-ground pipelines is to increase the span between the supports. The possibility of increasing the span of the flyover using the example of a field pipeline is examined. The calculations were performed using ANSYS software. The parameters of the grid model that provide a stable solution are determined, and a comparative analysis of deformations and stresses of the pipeline from the effects of static loads obtained in the START-PROF software is carried out. Due to the prediction of the magnitude and frequency of dynamic loads with a large error, it is impossible to accurately determine the service life of the pipeline; an estimate was made of the number of calculated load cycles of the pipeline before destruction according to the fatigue curves for steel 09G2C strength class K48. For the pipeline in question, there is a range of span values at which pipeline movements are ensured within the sites of construction supports, the stresses that occur don’t exceed the limit values, but there is a significant decrease in the service life. The results of the discounted CAPEX assessment showed that despite the reduction in the service life of the pipeline when the flyover span is higher than the value obtained under dynamic strength conditions, the discounted CAPEX at a rate of 15 % will be lower ensuring higher economic performance.

References

1. GOST R 55990 – 2014. Oil and gas-oil fields. Field pipelines. Design codes.

2. GOST 32388-2013. Processing pipes. Standards and calculation methods for the stress, vibration and seismic effects.

3. SP 33.13330.2012. Raschet na prochnost’ stal’nykh truboprovodov (Stress calculation of steel pipelines), 2013, URL: https://docs.cntd.ru/document/1200092599

4. SA 03-003-07. Raschety na prochnost’ i vibratsiyu stal’nykh tekhnologicheskikh truboprovodov: normativnye dokumenty mezhotraslevogo primeneniya po voprosam promyshlennoy bezopasnosti i okhrany nedr (Strength and vibration calculations for steel process pipelines: inter-industry regulatory documents on industrial safety and subsoil protection), Moscow: Standartinform Publ., 2007, 72 p.

5. Feodos’ev V.I., On the vibrations and stability of a pipe when liquid flows through it (In Russ.), Inzhenernyy sbornik, 1952, V. 10, pp. 169–170.

6. Efimov A.A., Natural oscillation of underwater pipelines (In Russ.), Izvestiya vuzov. Neft’ i gaza, 2008, no. 1, pp. 49–56.

7. Il’in V.P., Sokolov V.G., Issledovanie svobodnykh kolebaniya krivoy truby s potokom zhidkosti (Issledovanie svobodnykh kolebaniya krivoy truby s potokom zhidkosti), In: Uspekhi stroitel’noy mekhaniki i teorii sooruzheniy (Advances in structural mechanics and theory of structures), 2010, pp. 88–93.

8. Sokolov V.G., Bereznev A.V., Equations of motion of a curved section of a pipeline with a liquid flow (In Russ.), Izvestiya vuzov. Neft’ i gaz, 2004, no. 6, pp. 76–80.

9. Sokolov V.G., Bereznev A.V., Solution of the problem of free vibrations of curved sections of pipelines with flowing liquid (In Russ.), Izvestiya vuzov. Neft’ i gaz, 2005, no. 1, pp. 80–84.

10. Zaripov D.M., Non-linear vibrations of the pipeline under the action of impact pressure in internal fluid (In Russ.), Tr. Instituta mekhaniki Ufimskogo nauchnogo tsentra RAN = Proceedings of the Mavlyutov Institute of Mechanics, 2016, no. 11, pp. 136–140, DOI: https://doi.org/10.21662/uim2016.1.020

11. Mironov M.A., Pyatakov P.A., Andreev A.A., Forced flexural vibrations of a pipe with a liquid flow (In Russ.), Akusticheskiy zhurnal = Acoustical physics, 2010, V. 56,

no. 5, pp. 684–692.

12. Shakir’yanov M.M., Spatial chaotic vibrations of a pipeline in the continuous medium under the impact of alternating internal pressure (In Russ.), Izvestiya Ufimskogo nauchnogo tsentra RAN, 2016, no. 4, pp. 35–47.

13. Ganiev R.F., Il’gamov M.A., Khakimov A.G., Shakir’yanov M.M., Spatial aperiodic vibrations of the pipelines under transient internal pressure (In Russ.), Problemy mashinostroeniya i nadezhnosti mashin = Journal of machinery manufacture and reliability, 2017, no. 2, pp. 3–12.

14. Cherentsov D.A., Pirogov S.P., Determination of the natural frequencies of the above-ground sections of pipelines transporting an incompressible fluid (In Russ.), Izvestiya vuzov. Neft’ i gaz, 2023, no. 3(159), pp. 84–94, DOI: https://doi.org/10.31660/0445-0108-2023-3-84-94

15. Cherentsov D.A., Pirogov S.P., The influence of pumped liquid on the frequencies of free vibrations of above-ground sections of pipelines (In Russ.), Delovoy zhurnal NEFTEGAZ.RU, 2023, no. 8(140), pp. 118–119.

16. Cherentsov D.A., Pirogov S.P., Mathematical model of free vibrations in above-ground pipelines sections transporting multiphase fluid (In Russ.), Vestnik Tyumenskogo gos. universiteta. Fiziko-matematicheskoe modelirovanie. Neft’, gaz, energetika, 2024, no. 4(40), pp. 68–78, DOI: https://doi.org/10.21684/2411-7978-2024-10-4-68-78

17. Cherentsov D.A., Pirogov S.P., Evaluation of the influence of multiphase fluid parameters on the natural frequencies of above-ground field pipelines (In Russ.), Izvestiya vuzov. Neft’ i gaz, 2025, no. 1(169), pp. 100–112, DOI: https://doi.org/10.31660/0445-0108-2025-1-100-112

One of the main causes of occupational injuries and diseases is the stress on the musculoskeletal system. Personal protective equipment (PPE) such as industrial exoskeletons began to be used at facilities across various sectors of the economy. This type of PPE is reflected in Order No. 767n of the Russian Ministry of Labor dated October 29.10.2021 «On Approval of Uniform Standards for the Issuance of Personal Protective Equipment and Washing Agents» as additional. In accordance with the Technical Regulations of the Customs Union TR CU 019/2011 «On the Safety of Personal Protective Equipment» PPE should undergo a conformity assessment procedure (certification or declaration). Nowadays, there are no documents in the Russian legal framework that set requirements for industrial exoskeletons. Therefore, PPE recommended by the Ministry of Labor cannot be used at facilities without legal consequences. The use of industrial exoskeletons is currently organized by companies for testing and trial operation, although some companies use this type of PPE. The issuance of PPE after the legal vacuum is eliminated must be justified by the presence of harmful occupational factors related to physical exertion or a high risk of physical overload. The need for industrial exoskeletons at an enterprise is determined by the results of a special assessment of working conditions and/or hazard identification and occupational risk assessment. This article presents an analysis of the regulatory framework for industrial exoskeletons, the state of the industrial exoskeleton market in Russia, an assessment of their current applicability, a proposed rationale for their use.

References

1. O sostoyanii sanitarno-epidemiologicheskogo blagopoluchiya naseleniya v Rossiyskoy Federatsii v 2022 godu (On the state of sanitary and epidemiological well-being of the population in the Russian Federation in 2022), Moscow: Publ. of Federal Service for Surveillance on Consumer Rights Protection and Human Wellbeing, 2023, pp. 166–170.

2. Meditsina, stroyka, armiya: gde segodnya primenyayutsya ekzoskelety (Medicine, construction, and the military: where exoskeletons are used today),

URL: https://trends.rbc.ru/trends/industry/617192ae9a7947e18cfcd8aa