The article considers the problem of predicting the nature of the inflow of Achimov reservoirs in the northern part of Western Siberia. The solution of the problem is complicated by a number of factors: geological heterogeneity, low porosity and permeability, variability and low mineralization of formation waters, the presence of abnormally high formation pressure and high formation temperatures. The paper considers the results of special laboratory experiments on electrical, capillary, filtration characteristics of rocks and their comparison with the results of geophysical well logging. The nature of changes in porosity and saturation parameters depending on the mineralization of formation water under atmospheric and reservoir conditions was established. Correlations between critical water saturation values and the water and oil content in the reservoir were established in order to determine the nature of rock saturation, taking into account the intervals of the sub-reservoir by combining capillary, electrical and filtration models. Based on the obtained results, a method for determining the water saturation coefficient of rocks using the Dakhnov-Archie model and a method for verifying formation water mineralization over a field area under conditions of its variability were improved. A method for determining the saturation nature of reservoirs, taking into account sub-reservoir intervals, was also refined. Validation of the proposed method demonstrated a significant increase in the reliability of initial water cut prediction based on well logging data.

References

1. Zhizhimontov I.N., Makhmutov I.R., Yevdoshchuk A.A., Smirnova E.V., Heterogeneous saturation cause analysis during petrophysical modeling of low permeability Achimov deposits (In Russ.), Neftyanoye khozyaystvo = Oil Industry, 2022, no. 3, pp. 30–35, DOI: https://doi.org/10.24887/0028-2448-2022-3-30-35

2. Makhmutov I.R., Turenko S.K., Study of distribution patterns of oil- and water-saturated reservoirs in a section of the Achimov formation (In Russ.), Aktual′nyye problemy nefti i gaza, 2025, V. 16, no. 2, pp. 204–220, DOI: https://doi.org/10.29222/ipng.2078-5712.2025.11

3. Doroginitskaya L.M., Kolichestvennaya otsenka dobyvnykh kharakteristik kollektorov nefti i gaza po petrofizicheskim dannym i materialam GIS (Quantitative assessment of production characteristics of oil and gas reservoirs based on petrophysical data and well logging materials), Tomsk: Publ. of TPU, 2007, 276 p.

4. Makhmutov I.R., Tarandyuk M.S., Turenko S.K., Development of a petrophysical model of the Achimov deposits based on a two-level lithophysical typing of rocks

(In Russ.), Nedropol′zovaniye XXI vek, 2025, no. 5-6 (109), pp. 16-25.

5. Mukhidinov SH.V., Belyakov E.O., Determination of mobile water in reservoirs of Achimov thickness (In Russ.), PROneft′. Professional′no o nefti = PROneft. Professionally about Oil, 2020, no. 4(18), pp. 34–39, DOI: https://doi.org/10.7868/S2587739920040047

6. Rodivilov D.B., Kantemirov YU.D., Makhmutov I.R., Akin′shin A.V., Prakticheskoye rukovodstvo po petrofizicheskomu modelirovaniyu neftegazonasyshchennosti

(A practical guide to petrophysical modeling of oil and gas saturation), Tyumen: Ekspress Publ., 2023, 144 p., DOI: https://doi.org/10.54744/TNSC.2023.62.68.001

7. Dakhnov V.N., Interpretatsiya karotazhnykh diagramm (Interpretation of well logs), Moscow – Leningrad: Gostoptekhizdat Publ., 1941, 496 p.

8. McPhee C., Reed J., Zubizarreta I., Core analysis: A best practice guide, Netherlands: Elsevier, 2015, 829 p.

9. Rodivilov D.B., Salomatin E.N., Shul′ga R.S., Modification of the Dakhnov–Archie electrical model with successive changes in the mineralization of pore waters under thermobaric conditions (In Russ.) PROneft′. Professional′no o nefti = PROneft. Professionally about Oil, 2025, V. 10, no. 3(37), pp. 60–67,

DOI: https://doi.org/10.51890/2587-7399-2025-10-3-60-67

10. Waxman M.H., Smits L.J., Electrical conductivities in oil-bearing shaly sands, Soc. Pet. Eng. J., 1968, no. 8, pp. 107–122, DOI: http://doi.org/10.2118/1863-A

11. Vendel’shteyn B.Yu., Ellanskiy M.M., Effect of rock adsorption properties on the dependence of relative resistance on porosity coefficient (In Russ.), Prikladnaya geofizika, 1964, V. 40, pp. 181–193.

12. Pickett G.R., Pattern recognition as a means of formation evaluation, The Log Analyst, 1973, V. 14, no. 4, pp. 3–11.

The article analyzes methods and technologies for assessing abnormal reservoir pressure and operational detection of abnormally high pressure zones when drilling oil and gas wells. Prevention of accidents and complications by such zones detection is assessed as one of the main methods to improve the efficiency of oil work. Methods for abnormal reservoir pressure detection, as well as signs used for this purpose, are systematized and classified. The advantages of the developed methods are substantiated, which are based on the dependencies between the technical parameters of drilling. A brief chronology of the creation and improvement of this class of methods is noted. A method included in this group of operational detection is proposed which also enables calculation of weighted mud density to counteract abnormal pressure. The method is based on the principle of mathematical calculation of the dependence of the mechanical drilling speed on a number of other mechanical drilling parameters. A brief summary of the principle of detection, the functional blocks of the system and the operation of the system based on this method is given. An algorithm for the operation of the system was developed. Based on this algorithm, a control program was written in the C++ programming language. The operability of the system was tested by laboratory experiments based on the method of computer simulation.

References

1. Suleymanov E., The main mission of SOCAR CDWT is to strengthen the growing economy of Azerbaijan every day (In Russ.), International analytical journal “Caspian Energy”, 2022, no. 2(115), pp. 50–51.

2. Dadashov I.Kh., Abishov Ch.Kh., Drilling works highlights in Azerbaijan and opportunities of their improvements (In Russ.), Azerbaydzhanskoye neftyanoye khozyaystvo = Azerbaijan Oil Industry, 2012, no. 10, pp. 14–18.

3. Parisa E.Z., Kharakteristiki variatsii termobaricheskikh parametrov vo flyuidooriyentirovannykh sloyakh v glubinnykh sloyakh (Characteristics of variations in thermobaric parameters in fluid-oriented layers in deep layers): thesis of candidate of technical science, Baku, 2016.

4. Mamedov A.A., Kakhramanov G.N., Mamedova G.A., Role of abnormally high formation pressures in the distribution of oil-gas bearing content in South Caspian depression (In Russ.), Azerbaydzhanskoye neftyanoye khozyaystvo = Azerbaijan Oil Industry, 2021, no. 2, pp. 4–9, DOI: https://doi.org/10.37474/0365-8554/2021-2-4-9

5. Abdullayeva M.Y., Alizadeh Sh.N., Ways of rational use of water resources in the oil industry, RS Global, World Science, 2022, no. 5(77), pp. 1–6,

DOI: https://doi.org/10.31435/rsglobal_ws/30092022/7868

6. Korotayev B.A., Vasёkha V.M., Onufrik A.M., Reservoir pressure evolution model during exploration drilling (In Russ.), Vestnik MGTU, 2017, V. 20, no. 1/1, pp. 104–110, DOI: https://doi.org/10.21443/1560-9278-2017-20-1/1-104-110

7. Kerimov K.M., Abbasov Dzh.S., Zabolostani P.I., Some possibilities of AHFP zones prediction in large depths (In Russ.), Azerbaydzhanskoye neftyanoye khozyaystvo = Azerbaijan Oil Industry, 2014, no. 1, pp. 11–14.

8. Bingham M.G., A new approach to interpreting rock drillubility, Oil and Gas J., 1964, V. 62(46), pp. 173–179.

9. Jordan I.R., Shirley O.I., Application of drilling perfomance data to overpressure detection, J. Petroleum Technol., 1966, V. 28-11, pp. 1387–1394,

DOI: http://doi.org/10.2118/1407-PA

10. Mouchet J.-P., Mitchell A., Abnormal pressures while drilling: Origins, prediction, detection, evaluation, Editions Technip, 1989, 288 p.

11. Copyright certificate no. 1254782. Ustroystvo dlya opredeleniya zon anomal′no-vysokikh plastovykh davleniy (Device for determining zones of abnormally high reservoir pressures), Authors: Makhmudov Yu.A., Aliyev G.Kh., Agayev B.S. et al.

12. Copyright certificate no. 1275940. Ustroystvo dlya opredeleniya zon anomal′no-vysokikh plastovykh davleniy (Device for determining zones of abnormally high reservoir pressures), Authors: Makhmudov Yu.A., Aliyev G.Kh., Agayev B.S. et al.

13. Agaev B., Samidov A., Pashaeva M., Alieva K. On prodiction of high pressure zones in oil wells the on the bazis of the modernized d-exponent, Proceedings of The XXV International Sientific Sympozium “Civilizational bridges between people and cultures”. Dedicated to the 30th anniversary of the establishment of diplomatic relations between Azerbaijan and Ukraine, the 22-23rd of April 2022, Kyiv, 2022, pp. 161–166.

14. Biletskiy M.T., Ratov B.T., Delikesheva D.H., Automatic mud density measurement device (In Russ.), Gornyy informatsionno-analiticheskiy byulleten′, 2019, no. 7,

pp. 140–148, DOI: https://doi.org/10.25018/0236-1493-2019-07-0-140

The article is devoted to the technology of nitrogen-based foam injection with reduced interfacial tension being a promising combined method for enhanced oil recovery (EOR). The efficient development of carbonate reservoirs, characterized by an extensive fracture network, high temperatures (70 °C) and high salinity (209 g/l), typical for the Central-Khoreiver Uplift fields, is associated with challenges of uneven sweep and a rapid increase in water cut. Under such conditions, the implementation of traditional EOR methods is limited. The presented technology contributes to an increase in oil displacement efficiency by reducing residual oil saturation and to an improvement in sweep efficiency through gas mobility control and lower relative permeability of the injected agents. Selecting a stable and effective surfactant composition for such challenging reservoir conditions constitutes a non-trivial task. This work describes a systematic approach to optimization of the surfactant formulation that combines the properties of an effective foaming agent and an oil-displacing agent. The approach encompasses surfactant solubility evaluation, detailed investigation of foam generation capacity and stability in bulk and during filtration experiments, optimization of the blend composition, and foam injection parameters. Under the conditions considered, it was concluded that the effectiveness of the technology is predominantly attributed to the stability of the foam system rather than the reduction of interfacial tension. The developed composition achieved a 17 % additional oil recovery factor in filtration experiments by demonstrating high oil displacement efficiency.

References

1. Li R.F., Yan W., Liu S. et al., Foam mobility control for surfactant EOR, SPE-113910-MS, 2008, DOI: https://doi.org/10.2118/113910-MS

2. Renyi C. et al., A new laboratory study on alternate injection of high strength foam and ultra-low interfacial tension foam to enhance oil recovery, Journal of Petroleum Science and Engineering, 2015, V. 125, pp. 75–89, DOI: https://doi.org/10.1016/j.petrol.2014.11.018

3. Srivastava M. et al., A systematic study of alkali surfactant gas injection as an enhanced oil recovery technique, SPE-124752-MS, 2009,

DOI: https://doi.org/10.2118/124752-MS

4. Chengdong Y., Wanfen P., Foam for high temperature and ultra-high salinity conditions: Its displacement efficiency under different permeability heterogeneity,

SPE-200078-MS, 2022, DOI: https://doi.org/10.2118/200078-MS

5. Eloïse C., Advanced EOR foam in naturally fractured carbonates reservoirs: Optimal balance between foam and interfacial tension properties, SPE-194992-MS, 2019, DOI: https://doi.org/10.2118/194992-MS

6. Eloïse C. et al., Foams with ultra-low interfacial tensions for an efficient EOR process in fractured reservoirs, SPE-174658-MS, 2015,

DOI: https://doi.org/10.2118/174658-MS

7. Guo H. et al., A novel alkaline-surfactant-foam EOR process, SPE-145043-PA, 2011, DOI: https://doi.org/10.2118/145043-PA

8. Wang D. et al., Successful field test of the first ultra-low interfacial tension foam flood, SPE-72147-MS, 2001, DOI: https://doi.org/10.2523/72147-MS

9. Lunkenheimera K., Malysa K., Simple and generally applicable method of determination and evaluation of foam properties, Journal of Surfactants and Detergents, 2003, V. 6, no. 1, pp. 69–74, DOI: https://doi.org/10.1007/s11743-003-0251-8

Surfactant polymer flooding is widely used as a highly effective method for increasing oil recovery. The article discusses the results of laboratory and field studies of the surfactant polymer compounds use in the fields of Surgutneftegaz PJSC, provides implementation options, and assessment of the feasibility of using these compounds in Surgutneftegaz PJSC. The purpose of the work is to obtain a technological effect of methods to increase oil recovery by injecting surfactant polymer compounds in reservoirs with high permeability. Based on the results of laboratory studies it was noted that an increase in the concentration of polyacrylamide in aqueous solutions (0,1-0,4 %) and the volume of pumping their edges (0,1-4,0 pore volumes Vpor) through reservoir models of the formation X of the field N demonstrates the increase in oil displacement from 0,7 to 8,1 %, the most technically and economically feasible values were obtained using a polymer in the concentration range of 0,2-0,3 %. The additional displacement of residual oil is reached after exposure of polyacrylamide solutions in the amount of (1-2) Vpor. According to flow tests, oil displacement increase (on average by 9,4 %) was revealed after sequential treatment of core columns with polyacrylamide (0,2-0,3 %) and surfactant (3 %), as a result the volume of additional oil recovery increased by 1,3-2,7 times in contrast to the application of each method separately. The results of experimental work indicate that additional volumes of oil production were obtained as a result of the implementation of appropriate geological and technical operations.

Currently, the vast majority of oil fields in Russia are brown fields. Infill drilling or sidetracking is one of the main ways to stabilize and increase oil production, and the problem of localizing residual oil reserves and selecting candidate wells for sidetracking arises. The study reviews existing approaches (hydrodynamic modeling, digital development analysis, and simplified proxy modeling) to localize residual oil reserves in large mature fields, to identify areas for infill drilling or sidetracking. Applying these approaches can be very time-consuming and not always effective. To improve the efficiency of the candidate well selection technology for sidetracking, a new approach was developed. This approach enables rapid identification of priority areas for well intervention operations, infill drilling, and sidetracking. The approach involves modeling the movement of oil reserves driven by producing and injection wells, taking into account the actual geology of the reservoir, rock and fluid properties, and historical production data. Using this new approach, residual reserves were localized for long term history reservoir, and a successful sidetrack was drilled. Furthermore, a comparison of the estimated residual reserves with the initial production rates of sidetracks drilled after the reservoir localization demonstrates the high efficiency of the approach and its potential for further development.

References

1. Kudiyarov A.G., Gayfullin A.R., Sistemnyy podkhod k lokalizatsii ostatochnykh izvlekaemykh zapasov v nizkopronitsaemykh barovykh peschanikakh (A systems approach to localization of residual recoverable reserves in low-permeability bar sandstones), Collected papers “Dostizheniya, problemy i perspektivy neftegazovoy otrasli” (Achievements, problems and prospects of the oil and gas industry), Proceedings of IV International scientific and practical conference, Al’met’evsk: Publ. of ASPI, 2019, pp. 57–62.

2. Kanevskaya R.D., Matematicheskoe modelirovanie gidrodinamicheskikh protsessov razrabotki mestorozhdeniy uglevodorodov (Mathematical modeling of hydrodynamic processes of exploitation of hydrocarbons), Izhevsk: Institut komp’yuternykh issledovaniy, 2002, 140 p.

3. 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.

4. Latifullin F.M., Sattarov Ram.Z., Sharifullina M.A., Application of lazurit workstation software package for geological and reservoir modeling and well intervention planning for Tatneft’s production assets (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2017, no. 6, pp. 40-43,

DOI: https://doi.org/10.24887/0028-2448-2017-6-40-43

5. Denisov O.V., Nasybullin A.V., The express method for residual oil reserves localization on the basis of proxy model (In Russ.), Neftyanaya provintsiya, 2019, no. 2(18), pp. 113–124, DOI: https://doi.org/10.25689/NP.2019.2.113-124

6. Sayarpour M., Development and application of capacitance-resistive models to water/CO floods: Dissertation, Texas: The University of Texas at Austin, 2008.

7. Zakharyan A.Z., Ursegov S.O., From digital to mathematical models: a new look at geological and hydrodynamic modeling of oil and gas fields by means of artificial intelligence (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2019,

no. 12, pp. 144–148, DOI: https://doi.org/10.24887/0028-2448-2019-12-144-148

8. Sudakov V.A., Safuanov R.I., Kozlova A.N., Poryvaev T.M. et al., Localization and development of residual oil reserves using geochemical studies based on neural network algorithms (In Russ.), Georesursy, 2022, V. 24, no. 4, pp. 50–64, DOI: https://doi.org/10.18599/grs.2022.4.4

9. Zinurov L.A., Mingareev R.A., Lutfullin A.A. et al., Lokalizatsiya ostatochnykh zapasov na zrelom mestorozhdenii s pomoshch’yu tekhnologii impul’sno-kodovogo gidroproslushivaniya (Localization of the remaining reserves on brownfields with pulse code pressure testing), Proceedings of 7th scientific and practical conference GeoBaykal 2022, Irkutsk, February 27 – March 3, 2023, Moscow: Publ. of EAGE GEOMODEL’’, 2023, pp. 150–153.

10. Aslanyan A.M., Gulyaev D.N., Krichevskiy V.M. et al., Well interference analysis by multiple well deconvolution for pressure maintains system optimization

(In Russ.), PRONEFT’’. Professional’no o nefti, 2019, no. 3, pp. 56–61,

DOI: https://doi.org/10.24887/2587-7399-2019-3-56-61

The re-injection of associated petroleum gas into the gas cap is an effective way of its temporary utilization until the necessary infrastructure for its further use is built. The experience of implementing such projects showed a positive impact of gas re-injection on the oil recovery factor. The increase in the oil recovery factor is achieved by changing the mobility of the oil and gas phases which depends on the properties of the reservoir, reservoir fluids, and the injected gas. The article presents the results of calculating the change in mobility of the oil and gas phases and the additional oil production for various calculated changes in mobility. The calculations were performed for several oil and gas condensate fields of the Gazprom Neft Companу Group. As a result of these calculations, it was found that an increase in the oil recovery factor occurs when the mobility ratio of the oil and gas phases exceeds 143. When the mobility ratio is lower, there is a loss of oil due to the breakthrough of injected gas. Taking into account the calculation error, gas reinjection has a positive effect at phase mobility ratios below 150. Above this value, oil recovery decreases due to the predominance of gas breakthrough to the oil wells over the effect of maintaining reservoir pressure. An increase in the oil recovery factor occurs when the conditions for partially mixed displacement of oil by gas are met, which is possible under high reservoir pressures and low viscosity of the reservoir oil.

References

1. Voyvodyanu A.V., Fominykh O.V., Kovalenko I.V., Kramar V.G., Experience in developing oil rims at the Novoportovskoye field through the reinjection of associated petroleum gas (In Russ.), Izvestiya vuzov. Neft’ i gaz, 2025, no. 3, pp. 57–65, DOI: https://doi.org/10.31660/0445-0108-2025-3-57-65

2. Voyvodyanu A.V., Vinogradov A.S., Ilikbaev V.V., Virt V.I., Determination of the main technological parameters of gas injection into the reservoir using the example the field development of the Gazprom Neft company group (In Russ.), PROneft’. Professional’no o nefti, 2025, V. 10, no. 1, pp. 27–33, DOI: https://doi.org/10.51890/2587-7399-2025-10-1-27-33

3. Anuryev D.A., Grinchenko V.A., Miroshnichenko A.V. et al., Development history case of a major oil-gas-condensate field in a new province, SPE-166887-MS, 2013, DOI: https://doi.org/10.2118/166887-MS

4. Stepanova G.S., To assess the oil displacement coefficient using various methods of gas and water-gas stimulation (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 1991, no. 7, pp. 18–19.

5. Zakirov E.S., Zakirov S.N., Indrupskiy I.M., Anikeev D.P., Calculation of mobility in well completion intervals (In Russ.), Aktual’nye problemy nefti i gaza, 2018, no. 2(21), DOI: https://doi.org/ 10.29222/ipng.2078-5712.2018-21.art24

6. Chappelear J.E., Williamson A.S., Representing wells in numerical reservoir simulation: Part 2. Implementation, SPEJ, 1981, DOI: https://doi.org/10.2118/9770-PA

7. Emifov A.A., Razrabotka statisticheskikh
modeley dlya prognoza koeffitsienta podvizhnosti nefti v razlichnykh
fatsial’nykh usloviyakh: na primere bashkirskikh zalezhey Permskogo kraya
(Development of statistical models for predicting the oil mobility coefficient
in various facies conditions: using the example of the Bashkir deposits of the
Perm region): thesis of candidate of technical science, Perm, 2013.

The article initially presents the results of a field trial of an innovative technology for injecting undersaturated water to control gas-oil ratio in oil wells, developed by a subsidiary of Rosneft Oil Company. The basic technology of injecting undersaturated water into producing wells is used in the gas industry for well killing, as well as for small-volume water injection during well workovers to displace the gas cone. The presented technology was improved to use the large-cap water injection for treatment in combination with well settling in fields with a massive gas cap. The technology is aimed at suppressing gas coning in wells operating in sub-gas zones with a high gas-oil ratio and is applicable to reservoirs using water with a density of 1100 kg/m³ and higher. The method is based on high-volume water injection into the oil-producing well from the nearest injection well. The physical basis of the method includes gas displacement through water penetration into the pressure-depleted zone, improvement of relative phase permeabilities, partial gas dissolution, stimulation of hydrate formation in the coning zone. The field trial conducted at the Srednebotuobinskoye field demonstrated high technological efficiency: after injecting a large volume of water, the gas-oil ratio was significantly reduced, oil production rate increased, well performance stabilized. The proposed technology shows high potential for improving the economic efficiency of developing hard-to-recover reserves of Rosneft Oil Company fields in Eastern Siberia without major capital investments. Further pilot-industrial operations are planned to refine the applicability criteria and optimize treatment parameters.

References

1. Fevang Ø., Whitson C.H., Modeling gas-condensate well deliverability, SPE-30714-PA, 2019, DOI: https://doi.org/10.2118/30714-PA

2. Al-Nofli M.A., Kelkar M., Integrated assessment of water injection performance in high-GOR oil reservoirs, SPE-212345-PA, 2023,

DOI: https://doi.org/10.2118/212345-PA

3. Podchuvalova E.Yu., Polyakov D.V., Shafikov R.R., Injecting water into a gas cap: evolution of the oil refinery development system in offshore field (In Russ.), Vestnik neftegazovoy otrasli Kazakhstana = Kazakhstan journal for oil & gas industry, 2022, V. 4, no. 2, pp. 87–95, DOI: https://doi.org/10.54859/kjogi106006

4. Ivanov E.N., Akinin D.V., Valeev R.R. et al., Development of reservoir with gas cap and underlying water on Srednebotuobinskoye field (In Russ.), SPE 182055-RU, 2016, DOI: https://doi.org/10.2118/182055-MS

5. Istisheva V.F., Zabelin V.I., Ivanov E.N. et al., Limiting gas production from massive gas caps (In Russ.), Izvestiya vuzov. Neft’ i gaz, 2024, no. 4, pp. 50–63,

DOI: https://doi.org/10.31660/0445-0108-2024-4-50-63

6. Gritsenko A.I., Romanov V.A., Razrabotka neftegazovykh mestorozhdeniy (Development of oil and gas fields), Moscow: Nedra Publ., 2019, pp. 204–232.

7. Priz K.I., Alekseev A.S., Cherkasov N.A. et al., The experience in intermittent production and de-gassed oil injection for dissipation of gas coning (In Russ.), Ekspozitsiya Neft’ Gaz, 2023, no. 5, pp. 69–73, URL: https://doi.org/10.24412/2076-6785-2023-5-69-73

The occurrence of asphalt, resin and paraffin deposits (ARPD) in gas-lift operated production wells on offshore platforms of Vietsovpetro JV has a sufficient impact on production stability and oil output. Meeting target production levels using traditional offshore ARPD mitigation methods (steam treatment and chemical inhibition with pour-point depressants) results in substantial operating losses, prolonged well shutdowns, and a non-steady-state production regime after restart. Additional ARPD removal operations on unmanned wellhead platforms lead to increased operating costs and are complicated by logistical constraints. To reduce the impact of ARPD on oil production, Vietsovpetro JV is pursuing both the enhancement of existing mitigation methods and the deployment of new technical solutions, including the adaptation of onshore-proven technologies to offshore conditions. This paper presents the factors limiting the effectiveness of conventional steam-based ARPD removal, the field adaptation of slickline ARPD removal in production tubing under gas-lift conditions, and the results of implementing a new technology based on injection gas heating using an electric heater unit. Pilot-scale field tests demonstrated that injecting heated gas into the wellbore increases the temperature of produced fluids within the most ARPD prone interval above the pour point of the crude oil, enabling the elimination of steam treatment operations and making the technology suitable for unmanned offshore platforms.

References

1. Veliyev M.M., Ivanov A.N., Bondarenko V.A. et al., Experience of asphaltene sediments control during oil production at White Tiger field (In Russ.), Neftyanoye khozyaystvo – Oil Industry, 2020, no. 6, pp. 84–89, DOI: https://doi.org/10.24887/0028-2448-2020-6-84-89

2. Akhmadeyev A.G., Pham Thanh Vinh, Nguyen Huu Nhan et al., Application of technology for treating paraffinic oil with a pour point depressant injected into the gas lift line (In Russ.), Neftyanoye khozyaystvo – Oil Industry, 2025, no. 7, pp. 126–129, DOI: https://doi.org/10.24887/0028-2448-2025-7-126-129

The paper addresses the problem of ensuring the accuracy of directional survey measurements in directional and horizontal drilling, which depends on the use of geomagnetic models for determining wellbore azimuth relative to true north. It is demonstrated that the parameters of mathematical geomagnetic field models directly affect survey uncertainty and the size of wellbore position uncertainty ellipses. A comparative analysis of global geomagnetic models with different resolutions (IGRF, WMM, WMM-HR, HDGM, BGGM) is performed with respect to their applicability to drilling operations. The high definition geomagnetic model (HDGM), previously widely used in the oilfield service industry, is taken as a reference. The study is based on data from 108 wells located in eight regions of the Russian Federation. Quantitative deviations in magnetic field parameters, including total field intensity, inclination, and magnetic declination, are evaluated. Particular attention is given to the influence of the horizontal magnetic field component and latitude on azimuth uncertainty growth. The results show that, after appropriate adjustment of error model parameters in accordance with Industry Steering Committee on Wellbore Survey Accuracy (ISCWSA) requirements, the world magnetic model provides acceptable accuracy, with uncertainty ellipse growth not exceeding 8 % compared to HDGM. The findings confirm the feasibility of using open-access geomagnetic models for directional drilling under limited availability of high-resolution commercial models and highlight the importance of adapting error codes and accounting for regional geomagnetic conditions to maintain reliable wellbore positioning.

References

1. Gvishiani A. et al., Automated hardware and software system for monitoring the Earth’s magnetic environment, Data Sci. J., 2016, V. 15,

DOI: https://doi.org/10.5334/dsj-2016-018

2. Zhdaneev O.V., Zaytsev A.V., Lobankov V.M., Metrologicheskoe obespechenie apparatury dlya geofizicheskikh issledovaniy (In Russ.), Zapiski Gornogo instituta, 2020, V. 246, pp. 667-677, DOI: https://doi.org/10.31897/PMI.2020.6.9

3. Zhdaneyev O.V., Assessment of product localization during the import substitution in the fuel and energy sector (In Russ.), Ekonomika regiona, 2022, V. 18, no. 3,

pp. 770–786, DOI: https://doi.org/10.17059/ekon.reg.2022-3-11

4. Edvardsen I. et al., Best practices and recommendations for magnetic directional surveying in the Barents Sea, SPE-195600-MS, 2019,

DOI: https://doi.org/10.2118/195600-MS

5. Macmillan S., McKay A., Grindrod S., Confidence limits associated with values of the Earth’s magnetic field used for directional drilling, Proceedings of SPE/IADC Drilling Conference and Exhibition, Amsterdam, 2009.

6. Maus S. et al., High definition geomagnetic models: A new perspective for improved wellbore positioning, Proceedings of IADC/SPE Drilling Conference and Exhibition, San Diego, 2012.

7. Lowdon R.M., Chia C.R., Multistation analysis and geomagnetic referencing significantly improve magnetic survey results, SPE-79820-MS, 2003,

DOI: https://doi.org/10.2118/79820-MS

8. Arsen′yev S.A., Theoretical modeling of the main magnetic field of the Earth and planets (In Russ.), Aktual′nyye problemy gumanitarnykh i yestestvennykh nauk, 2015, no. 4–2, pp. 313–321.

9. Nair M. et al., Next generation high-definition geomagnetic model for wellbore positioning, incorporating new crustal magnetic data, SPE-31044-MS, 2021,

DOI: https://doi.org/10.4043/31044-MS

10. Finlay C.C. et al., The CHAOS-7 geomagnetic field model and observed changes in the South Atlantic anomaly, Earth Planets Space, 2020, V. 72, no. 1,

DOI: https://doi.org/10.1186/s40623-020-01252-9

11. Ruifeng Y., Binbin D., Deli G., Calculation for wellbore trajectory measurement error incorporating magnetic azimuth correction, Pet. Drill. Tech., 2023, V. 51, no. 6,

pp. 25–31.

This work presents the results of mathematical modeling of the operation of a fired triethylene glycol reboiler. Modeling process was performed through several steps. First modeling step consisted of the process simulation of regeneration unit to calculate material and energy balances of each individual unit and streams of modeled system. In the second step, starting from the obtained results in the first step, coupled thermal heat transfer calculation of fuel gas burning in the firetube was performed, taking into account heat transfer through firetube wall surface from flue gases to external medium and convective heat transfer from firetube external surface to glycol. Fuel gas burning process inside firetube and heat transfer to glycol were modeled taking into account flow of both gas and liquid fluid in their respective sides. As a result of performed calculations contour diagrams with temperature fields of firetube and reboiler shell side were obtained. Coupled heat transfer calculations were verified comparing the results of computational fluid dynamics (CFD) simulation with experimental data. In the final step of present work a stress-strain evaluation of firetube was performed and it was determined that strain stresses in firetube do not exceed the permissible limits if its external surface is not heated above 410 °C.

References

1. Zhdanova N.V., Khalif A.L., Osushka uglevodorodnykh gazov (Drying of hydrocarbon gases), Moscow: Khimiya Publ., 1984, 192 p.

2. Warnatz J., Maas U., Dibble R.W., Combustion: Physical and chemical fundamentals, modelling and simulation, experiments, pollutant formation, 1996,

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

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

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

6. Cheremisinoff N.P., Gupta R., Handbook of fluids in motion, Boston: Ann Arbor Science, 1983, 1202 p.

7. ANSYS CFX User’s Guide, Release 2020 R1. ANSYS CFX-Solver Theory Guide section, URL: https://cfdlectures.com/tutorials/cfxtutorial.pdf

8. Ettouil F.B. et al., Predicting dynamic and thermal histories of agglomerated particles injected within a d.c. plasma jet, Surface and Coatings Technology Journal, 2008, V. 202, no. 18, pp. 4491–4495, DOI: https://doi.org/10.1016/j.surfcoat.2008.04.032

9. Rojas J.R., Numerical simulation of the melting of particle injected in a plasma jet, Ingenaire, 2009, V.17, pp. 299–308, DOI: https://doi.org/10.4067/S0718-33052009000300003

10. GOST R 34233.1-2017. Sosudy i apparaty. Normy i metody rascheta na prochnost’. Obshchie trebovaniya (Vessels and apparatus. Norms and methods of strength calculation. General requirements)

The article describes an analysis of various killing fluids for the fields of one of the oil companies in the West Siberian region. The Oil Company's productive formations of fields are deep-seated, have a high temperature factor (93-104°C), significant formation reservoir pressures, and a high content of hydrocarbonate ions in the produced associated water. This causes the problem of incompatibility of these waters with killing fluids of various densities, as well as the severe corrosion activity towards downhole equipment. The interference of reservoir pressure over the area and section of oil fields determines the use of killing fluids of different densities during well killing operations. The article discusses the characteristics of the technological properties of killing fluids of various densities based on the following components: sodium chloride (halite), calcium chloride, a blended saline of halite and calcium nitrate, a blended saline of calcium chloride and calcium nitrate, potassium formate, and two ready-made salt of trademarks. It has been shown that in most cases, corrosion inhibitors and scale inhibitors mutually reduce each other’s effectiveness. This is reflected in an increase in salt deposits and corrosion aggressiveness when mixing killing fluids with produced associated waters.

In addition, the issue of the imperfections of market ready-made mixtures and the need for separate selection and testing of killing fluids for water injection and producing wells is discussed, due to their significant differences in operating conditions.

References

1. RD 153-39-023-97. Pravila vedeniya remontnykh rabot v skvazhinakh (Rules for carrying out repair work in wells), Moscow: Publ. of NPO “Bureniye”, 1997, 93 p.

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. Variative approach to the killing fluids selection for sandstone formations. Part 2. Core testing of killing fluids influence on rock permability (In Russ.), Ekspozitsiya Neft′ Gaz, 2024, no. 1, pp. 38–42, DOI: https://doi.org/10.24412/2076-6785-2024-1-38-42

4. Folomeev A.E., Vakhrushev S.A., Khatmullin A.R. et al., Reducing the negative impact of workover fluids on Sorovskoe oilfield sandstone formation by their modification (In Russ.), Izvestiya Tomskogo politekhnicheskogo universiteta. Inzhiniring georesursov, 2022, V. 333, no. 2, pp. 26–37,

DOI: https://doi.org/10.18799/24131830/2022/2/3328

5. Ryabokon’ S.A., Tekhnologicheskie zhidkosti dlya zakanchivaniya i remonta skvazhin (Process fluids for completion and repair of wells), Krasnodar: Publ. of NPO Burenie, 2009, 337 p.

6. Nasyrov A.M., Borkhovich S.YU., Bardanova O.N., Osvoyeniye i glusheniye neftyanykh skvazhin (Development and killing of oil wells), Moscow – Vologda: Publ. of Infra-Inzheneriya, 2022, 262 p.

7. Voloshin A.I., Gusakov V.N., Fakhreeva A.V., Dokichev V.A., Scaling prevention inhibitors in oil production (In Russ.), Neftepromyslovoe delo, 2018, no. 11, pp. 60–72, DOI: https://doi.org/10.30713/0207-2351-2018-11-60-72

The article describes ways to automate the analysis of textual lithological core descriptions using large language models (LLM). The LithoText service, developed by Rosneft Oil Company as a part of the digital transformation program, is presented. For the first time in the production practice of oil and gas geology, this service uses LLM, prompt engineering technology and domain expertise from geologists. The LithoText service uses prompt engineering technology and domain expert knowledge of lithologist and enables to automatically determine 16 physical core parameters from the texts of geological reports such as rock type, color, saturation, texture, grain size, fracturing, type of void space, and others. The service processes lithological data using created artificial intelligence (AI) agents, each of which is responsible for a specific parameter. The parameters are determined using a LLM which is designed for reading and understanding natural language text. A comparison between classical machine learning methods and LLMs demonstrated the superiority of the latter. The service provides automatic extraction of lithological parameters, validation with benchmark datasets, and retrospective analysis of historical data. Pilot implementation in the Company showed a reduction in processing time by several times, reducing the likelihood of errors due to the human factor. The results confirm the potential of LLMs for petroleum geology applications. The scope application is the analysis of lithological descriptions of the core.

References

1. “Rosneft” vnedryayet iskusstvennyy intellekt v izucheniye kerna (Rosneft is introducing artificial intelligence into core analysis.),

URL: https://www.rosneft.ru/press/news/item/222239/

2. Nedolivko N.M., Issledovanie kerna neftegazovykh skvazhin (Oil and gas wells core study), Tomsk: Publ. of TPU, 2006, 163 p.,

URL: https://portal.tpu.ru/SHARED/n/NEDOLIVKO/disc1/Tab2/Posobie.pdf

3. Das M.A., Comparative study on TF-IDF feature weighting method, 2023, DOI: https://doi.org/10.48550/arXiv.2308.04037

4. Reimers N., Gurevych I., Sentence-BERT: Sentence embeddings using Siamese BERT-Networks, DOI: https://doi.org/10.48550/arXiv.1908.10084

5. Yadryshnikova O.A., Tenyunin A.F., Bychkov M.L., Iskusstvennyy intellekt i geologicheskiye arkhivy: novyye podkhody dlya avtomaticheskoy indeksatsii (Artificial Intelligence and geological archives: New approaches for automatic indexing), Collected papers “Aktual′nyye problemy neftegazovoy otrasli” (Current issues in the oil and gas industry), Proceedings of scientific and practical conferences of the journal “Neftyanoye khozyaystvo”, Moscow, 2024, Moscow: Neftyanoye khozyaystvo Publ., 2025, pp. 139-143.

6. Kostina A., Dikaiakos M.D., Stefanidis D., Pallis G., Large language models for text classification: Case study and comprehensive review, 2025,

DOI: https://doi.org/10.48550/arXiv.2501.08457

7. Sber Developers. Prompt engineering: luchshiye praktiki (Sber Developers. Prompt Engineering: Best Practices),

URL: https://developers.sber.ru/docs/ru/gigachat/prompts-hub/prompt-engineering

The article focuses on developing an approach to managing the digital transformation of oil supply chains using scenario analysis. An integral index is used as the core analytical tool, enabling a quantitative assessment of the efficiency and resilience of oil supply chain segments. Previous studies confirmed the dependence of index values on the digital maturity level of supply chain segments. Digital transformation management is examined through scenario analysis applied to a four-stage supply chain: extraction – transportation – storage – distribution. The calculation results revealed significant disparities in the integral index across the supply chain stages, from 41,5 (extraction) to 76,3 (storage). These findings highlight the need for targeted digitalization of the most vulnerable segments. Scenario modeling enabled to analyze the dynamics of the index under different digital transformation strategies. Under the inertial scenario, the index reached 52,1, under the moderate transformation scenario - 67,3, under the aggressive digitalization scenario - 81,9. To support investment decision-making, the approach incorporates an indicator of integrated performance per unit of capital (IPC). Its values increased from less than 3 % to 13 % when moving from a low to a high level of digital maturity. The study demonstrates that the integral index in scenario analysis can be used as a managerial tool for diagnosing supply chain conditions, prioritizing digitalization initiatives, forming investment portfolios. A network effect was identified: digitalization of individual supply chain stages enhances the performance of adjacent stages, confirming the necessity of a comprehensive approach to managing the digital transformation of oil supply chains.

References

1. Ulanov V., Skorobogatko O., Impact of EU carbon border adjustment mechanism on the economic efficiency of Russian oil refining, Zapiski Gornogo instituta = Journal of Mining Institute, 2022, Online first, DOI: https://doi.org/10.31897/PMI.2022.83

2. Skobelev D.O., Cherepovitsyna A.A., Guseva T.V., Carbon capture and storage: net zero contribution and cost estimation approaches (In Russ.), Zapiski Gornogo instituta = Journal of Mining Institute, 2023, V. 259, pp. 125–140, DOI: https://doi.org/10.31897/PMI.2023.10

3. Carter C.R., Rogers D.S., A framework of sustainable supply chain management: moving toward new theory, International Journal of Physical Distribution & Logistics Management, 2008, V. 38, no. 5, pp. 360–387, DOI: https://doi.org/10.1108/09600030810882816

4. Ivanov D., Intelligent digital twin (iDT) for supply chain stress-testing, resilience, and viability, International Journal of Production Economics, 2023, V. 263,

DOI: https://doi.org/10.1016/j.ijpe.2023.108938

5. Gökalp E., Martinez V., Digital transformation maturity assessment: development of the digital transformation capability maturity model, International Journal of Production Research, 2022, V. 60, no. 20, pp. 6282–6302, DOI: https://doi.org/10.1080/00207543.2021.1991020

6. Büyüközkan G., Göçer F., Digital supply chain: literature review and a proposed framework for future research, Computers in Industry, 2018, V. 97, pp. 157–177,

DOI: https://doi.org/10.1016/j.compind.2018.02.010

7. Hui Fang, Fei Fang, Qiang Hu, Yuehua Wan, Supply chain management: a review and bibliometric analysis, Processes, 2022, V. 10, no. 9,

DOI: https://doi.org/10.3390/pr10091681

8. Ahmed H., Bashar M.A., Rahman M.A.T., Innovative approaches to sustainable supply chain management in the manufacturing industry: a systematic literature review, Global Mainstream Journal of Innovation, Engineering & Emerging Technology, 2024, V. 3, no. 2, DOI: https://doi.org/10.62304/jieet.v3i02.81

9. Hanelt A., Bohnsack R., Marz D., Marante C.A., A systematic review of the literature on digital transformation: insights and implications for strategy and organizational change, Journal of Management Studies, 2021, V. 58, no. 5, pp. 1159–1197, DOI: https://doi.org/10.1111/joms.12639

10. Saaty T.L., Decision making with the analytic hierarchy process, International Journal of Services Sciences, 2008, V. 1, no. 1, pp. 83–98,

DOI: https://doi.org/10.1504/IJSSCI.2008.017590

11. Pournader M., Ghaderi H., Hassanzadegan A., Fahimnia B., Artificial intelligence applications in supply chain management, International Journal of Production Economics, 2021, V. 241, DOI: https://doi.org/10.1016/j.ijpe.2021.108250

12. Andaloussi M.B., A bibliometric literature review of digital supply chain: trends, insights, and future directions, SAGE Open, 2024, V. 14, no. 2,

DOI: https://doi.org/10.1177/21582440241240340

13. Bratskikh D.S., Romasheva N.V., Konopelko A.Yu., Nikolaychuk L.A., Model of supply chain management in the oil and gas industry using digital technologies

(In Russ.), Neftyanoye khozyaystvo = Oil Industry, 2024, no. 7, pp. 120–125, DOI: https://doi.org/10.24887/0028-2448-2024-7-120-125.technologies

14. Tiwari M.K., Bidanda B., Geunes J. et al., Supply chain digitisation and management, International Journal of Production Research, 2024, V. 62, no. 8, pp. 2918–2926, DOI: https://doi.org/10.1080/00207543.2024.2316476

15. Matrokhina K., Trofimets V., Mazakov E. et al., Development of methodology for scenario analysis of investment projects of enterprises of the mineral resource complex (In Russ.), Zapiski Gornogo instituta = Journal of Mining Institute, 2023, V. 259, pp. 112–124, DOI: https://doi.org/10.31897/PMI.2023.3

The article studies the impact of regulatory safety margin factors on the design solutions and safety of vertical cylindrical steel oil tanks. It is demonstrated that the traditional design approach, based on a system of partial safety factors (for material, load, responsibility, and working conditions) is excessively conservative. This results in a significant and non-uniform strength margin along the wall’s height: while the lower shell course utilizes about 59 % of the material's yield strength, the upper courses are stressed at only 8-20 %, indicating non-optimal metal consumption. Using the example of calculation for RVS-10 000 and RVS-20 000 oil tanks according to State Standard GOST 31385-2023 without safety factors, it is shown that the stability condition is more critical than the strength condition. To ensure stability when calculating without factors, the shell course thicknesses should be increased almost to the values determined by the regulatory strength calculation. It is noted that there is an existing industry practice of using even more inflated thicknesses, which lacks sufficient justification and increases material intensity and cost. The conclusion is made about the need for more flexible and optimized calculation methods to reduce excessive metal consumption while maintaining the required safety level. The possibility of optimizing regulatory requirements for tank design is substaniated. The research results can be used to update standards in order to reduce the material intensity of structures without compromising their reliability and safety.

References

1. Russian Federal Law No. 384-FZ “Technical regulations on the safety of buildings and facilities” of December 30th, 2009. – http://government.ru/docs/all/99400/

2. Gorban′ N.N., Vasil′yev G.G., Leonovich I.A., Sal′nikov A.P., Mechanical safety analysis of marine terminal oil tanks based on ground laser scanning data (In Russ.), Neftyanoye khozyaystvo = Oil Industry, 2025, no. 1, pp. 90–94, DOI: https://doi.org/10.24887/0028-2448-2025-1-90-94. – EDN: VSUOXM.

3. Gorban′ N.N., Vasil′yev G.G., Leonovich I.A., Conceptual approaches to managing the technical condition of marine oil terminals (In Russ.), Neftyanoye khozyaystvo = Oil Industry, 2025, no. 7, pp. 135–141, DOI: https://doi.org/10.24887/0028-2448-2025-7-135-141.

4. GOST 31385-2023. Vertical cylindrical steel tanks for oil and oil-products. General specifications, URL: https://docs.cntd.ru/document/1302050679

5. SP 16.13330.2017. Stal′nyye konstruktsii (Steel structures), URL: https://docs.cntd.ru/document/456069588

6. SP 20.13330.2016. Nagruzki i vozdeystviya (Loads and impacts), URL: https://docs.cntd.ru/document/550965467

7. GOST 19281-2014. High strength rolled steel. General specification, URL: https://docs.cntd.ru/document/1302050679

8. Vasilyev G.G., Sal′nikov A.P., Gorban′ N.N., Creating three-dimensional models of storage tanks with incomplete information based on terrestrial laser scanning data (In Russ.), Trudy RGU nefti i gaza (NIU) imeni I.M. Gubkina, 2025, no. 3(320), pp. 77–88.

Field pipelines are subject to internal corrosion due to exposure to highly mineralized reservoir water. In this regard, special attention is paid to the resistance of the materials of pipes to the effects of destructive factors, as they significantly reduce the period of trouble-free operation of pipelines. Under these conditions, experimental rolled pipe steel with improved performance properties was created. Comparative tests of technical characteristics of the obtained alloy with the most commonly used rolled products indicate a high development potential, and preliminary laboratory tests, the results of which are presented in the work, indicate a multiple increase in reliability and trouble-free operation of hydrocarbon transportation facilities. As part of the work, the main reasons for the decrease in the reliability of field pipelines and the features of their operation are identified, and the methodology for testing new grades of steel is described. The microstructure of the studied samples is considered and their structural features are determined. Pilot industrial tests of an experimental grade of steel were carried out at production facilities, which enabled to confirm the high laboratory test results in real conditions. The results obtained enable to draw conclusions about the prospects of the developed alloy and the possibility of its application in real conditions, increasing the production efficiency of oil producing companies.

References

1. Kuznetsov D.V., Tikhonov S.M., Komissarov A.A. et al., “Severkor” – korrozionno-stoykiy trubnyy prokat. Perspektivy vnedreniya (Severkor – corrosion-resistant rolled tubular products. Implementation prospects), Collected papers “(Gas Transportation Systems: Present and Future (GTS-2017))”, Proceedings of VII International Scientific and Technical Conference, 26–27 October 2017, Moscow: Publ. of Gazprom VNIIGAZ, 2017, p. 109.

2. Rodionova I.G., Baklanova O.N., Amezhnov A.V. et al., The influence of non-metallic inclusions on the corrosion resistance of carbon and low-alloy steels for oil field pipelines (In Russ.), Stal′, 2017, V. XKH, no. 10, pp. 41–48.

3. Rodionova I.G., Amezhnov A.V., Baklanova O.N. et al., Evolution of requirements for steels with increased corrosion resistance used in neutral aqueous environments, including in contact with ground electrolytes (In Russ.), Collected papers “Povysheniye nadezhnosti magistral′nykh gazoprovodov, podverzhennykh korrozionnomu rastreskivaniyu pod napryazheniyem (KRN-2018)” (Improving the reliability of main gas pipelines susceptible to stress corrosion cracking): Proceedings of IV International scientific and practical seminar, Moscow, 06–08 June 2022, Moscow: Publ. of Gazprom VNIIGAZ, 2018, p. 26.

4. Bolobov V.I., Popov G.G., E.A. Krivokrysenko et al., Comparative resistance of oil interfield pipeline steels to rill corrosion (In Russ.), Problemy sbora, podgotovki i transporta nefti i nefteproduktov, 2020, V. 123, no. 1, pp. 128–139, DOI: https://doi.org/10.17122/ntj-oil-2020-1-128-139

5. Burkov P.V. et al., Simulation of pipeline in the area of the underwater crossing, IOP Conference Series: Earth and Environmental Science, 2014, V. 21,

DOI: https://doi.org/10.1088/1755-1315/21/1/012037

6. Burkov P., Kalmykova K., Burkova S., Tien D.T.T., Research of stress-deformed state of main gas-pipeline section in loose soil settlement, IOP Conference Series: Earth and Environmental Science, 2014, V. 21, DOI: https://doi.org/10.1088/1755-1315/21/1/012039

7. Burkov P.V., Analysis of the stress-strain state of the pipeline in permafrost conditions (In Russ.), Vestnik Kuzbasskogo gosudarstvennogo tekhnicheskogo universiteta nauchno-tekhnicheskiy zhurnal, 2013, no. 6(100), pp. 77–79.

8. Zhilina T., Afonin K., Mironov V. et al., The influence of grooving corrosion on the strength of pipelines, E3S Web of Conferences: Topical Problems of Green Architecture, Civil and Environmental Engineering, TPACEE 2019, V. 164, DOI: https://doi.org/10.1051/e3sconf/202016403011

9. Stepanov P.P., Sakhnevich A.N., Mokerov S.K., Kincharov A.I., Experience of operating new generation pipe steel in the Volga-Ural oil and gas province (In Russ.), Neftyanoye khozyaystvo = Oil Industry, 2020, no. 1, pp. 83–87.

10. Rodionova I.G., Baklanova O.N., Amezhnov A.V. et al., Influence of the chemical composition of non-metallic inclusions on corrosion resistance of carbon and low-alloy steels in aqueous media typical for service conditions of oil-field pipelines (In Russ.), Problemy chernoy metallurgii i materialovedeniya, 2018, no. 3, pp. 81–90.

11. Rodionova I.G., Yamburov S.I., Amezhnov A.V. et al., About the influence of zirconium on the corrosion resistance of carbon and low-alloy pipe steels (In Russ.),

Problemy chernoy metallurgii i materialovedeniya, 2018, no. 3, pp. 16–25.

The operation of oil pipelines involves the formation of gas accumulations at elevated points. The main reason for this is the occurrence of temporary pass points. A rational way to eliminate gas accumulations is to remove them with a stream of pumped liquid, since this doesn’t require the introduction of additional equipment or chemicals into the pipeline. For such operations, it is necessary to have adequate dependencies describing the conditions for the removal of gas accumulations by the pumped liquid flow. The article provides a critical overview of previous studies to determine the conditions for the complete removal of gas accumulations. It is shown that some of them are purely theoretical. Another part is a summary of the results of experiments on small diameter pipes with manifested capillary effects. Water, which significantly differs from oil and oil products, was often used as a model liquid. Some studies considered the conditions not for the removal of gas accumulations, but for their equilibrium under the influence of the flow of pumped liquid. The article describes a unique stand that enables to study the activity of gas accumulations in a pipeline with a variable profile, including sections of DN100 pipes. The results of experimental study of the mechanism of gas accumulation removal from the inclined downward pipeline are presented. Influence of surface tension on outflow velocity was revealed. It was shown that previously known formulas for predicting the flow rate, which provides a one-time removal of gas accumulations, have a significant error.

References

1. Charnyy I.A., The influence of terrain and fixed inclusions of liquid or gas on the throughput of pipelines (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 1965, no. 6, pp. 51–55.

2. Lur’e M.V., Removal of water accumulations from the pipeline with the help of the pumped oil flow (In Russ.), Nauka i tehnologii truboprovodnogo transporta nefti i nefteproduktov = Science & Technologies: Oil and Oil Products Pipeline Transportation, 2017, no. 1(28), pp. 62–68.

3. Gallyamov A.K., Korobkov G.E., Sultanov N.F., Fazletdinov A.S., Conditions for removing gas (air) accumulations from pipelines (In Russ.), Transport i khranenie nefti i nefteproduktov, 1972, no. 9, pp. 10–12.

4. Gallyamov A.K., Baykov I.R., Geyer B.V., Estimation of the effective rate of removal of water and gas accumulations from pipelines (In Russ.), Neftyanaya promyshlennost’, 1990, no. 9, pp. 34–36.

5. Nechval’ A.M., Dinamika obrazovaniya gazovykh skopleniy v truboprovodakh i ikh udalenie potokom perekachivaemoy zhidkosti (Dynamics of formation of gas accumulations in pipelines and their removal by the flow of pumped liquid): thesis of candidate of technical science, Ufa, 1991.

6. Kutukov S.E., Razrabotka metodov funktsional’noy diagnostiki tekhnologicheskikh rezhimov ekspluatatsii magistral’nykh nefteprovodov (Development of methods for functional diagnostics of technological modes of trunk pipelines operation): thesis of doctor of technical science, Ufa, 2003.

7. Korshak A.A., Razrabotka tekhnologii perekachki gazonasyshchennykh neftey (Development of technology for pumping gas-saturated oils): thesis of doctor of technical science, Moscow, 1991.

8. Lur’e M.V., Didkovskaya A.S., Arbuzov N.S., Calculation of filling the relief oil pipeline with liquid (In Russ.), Nauka i tehnologii truboprovodnogo transporta nefti i nefteproduktov = Science & Technologies: Oil and Oil Products Pipeline Transportation, 2013, no. 4(12), pp. 30–33.

9. Gallyamov A.K., Korobkov G.E., Sultanov N.F., On the rate of removal of gas accumulations (In Russ.), Transport i khranenie nefteproduktov i uglevodorodnogo syr’ya, 1971, no. 6, pp. 9–10.

10. Huang Haocheng, Jiang Jin, Chen Qi et al., Study on the motion characteristics of residual air mass in pipelines in water transfer project, MATEC Web of Conferences, 2018, V. 246, DOI: https://doi.org/10.1051/matecconf/201824601113ISWSO2018

11. Escarameia M., Burrows R., Little M., Murray S., Air problems in pipelines – a design manual, HR Wallingford Ltd., 2005, 90 p.

12. Wu-yi Wan, Chen-yu Li, Yun-qi Yu, Investigation on critical equilibrium of trapped air pocket in water supply pipeline system, Journal of Zhejiang University-SCIENCE A, 2017, V. 18, pp. 167-178.

13. May D., Allen J., Nelson D., Hydraulic investigation of air in small diameter pipes, International Journal of Hydraulic Engineering, 2018, no. 7, pp. 51–57,

DOI: https://doi.org/10.5923/j.ijhe.20180703.02

14. Bucur D.M., Isbasoiu E.C., Airpockets in pipeline systems, UPB Scientific Bulletin, Ser.D: Mechanical Engineering, 2008, V. 70, no. 4, pp. 35–44.

15. Casey T.J., Air in water and wastewater pipes, Dublin: Aquavarra Research Ltd., 2021, 7 r., URL: https://www.aquavarra.ie/TNAirPD3.pdf

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The article explores the potential of Smart Microcontainer (SMC) technology. The essence of the innovation is to create microscopic capsules that hold active reagents and release them in response to specific external signals - temperature change, pH, exposure to magnetic field or ultrasound. This real-time, point-to-point reaction control capability paves the way for overcoming limitations of modern chemical technology. Three practically significant areas of application are considered. The first is polymerization control, when SMC solve the critical problem of heat dissipation and temperature fluctuations, which enables not only to increase safety, but also to significantly narrow the molecular weight distribution of the final product. The second area is catalysis. Microencapsulation of highly active but sophisticated Lewis acids enables to create heterogeneous systems that combine the efficiency of a homogeneous catalyst with the ease of its recovery and regeneration. This dramatically reduces reagent consumption and minimizes toxic waste generation in processes such as Friedel-Crafts acylation. Particular attention is paid to olefin epoxidation processes, traditionally associated with high risks of thermal overclocking and low selectivity. Controlled release of hydrogen peroxide from microcontainers eliminates dangerous local overconcentrations, smooths exothermics, and suppresses unwanted acid-catalyzed epoxy ring opening. Thus, SMC technology represents an integrated approach that takes into account safety, selectivity, resource savings and ecology, puts SMC as the basis for the transition to smarter, more efficient and sustainable production processes in the future.

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