The article shows the main spatio-temporal regularities of the development of the processes of generation, migration and accumulation of hydrocarbon fluids in the eastern part of the Scythian plate. The authors studied the features of the generationaccumulation hydrocarbon systems of the northern platform side - the Karpinsko-Mangyshlak and East Ciscaucasian oil and gas regions based on the application of technologies of basin analysis and modeling of hydrocarbon systems. The research results indicate that the following hydrocarbon systems are distinguished in the sedimentary cover of the eastern part of the Scythian plate: Jurassic, Cretaceous, Paleocene-Eocene, and Oligocene-Miocene systems. Based on the results of the studies and modeling, the main directions of further prospecting and exploration work in the eastern part of the Scythian plate were determined. The study area was differentiated by the nature of the predicted oil and gas content, the age of the promising complexes and the confinement to tectonic structures and zones.

Keywords: generation; migration; accumulation; hydrocarbons; Scythian plate; hydrocarbon systems; basin analysis; modeling; source rocks.

References

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14. Kerimov, V. Yu., Osipov, A. V., Mustaev, R.N., et al. (2019). Conditions of formation and development of the void space at great depths. Oil Industry, 4, 22–27.
15. Guliyev, I. S., Kerimov, V. Y., Osipov, A. V., Mustaev, R. N. (2017). Generation and accumulation of hydrocarbons at great depths under the Earth's crust. SOCAR Proceedings, 1, 4-16.
16. Kerimov, V. Yu., Yandarbiev, N. Sh., Bondarev, A. V., et al. (2017). Evaluation of organic carbon content of low permeability shale strata (on the example of the pre-Caucasus khadum suite. Geology, Geophysics and Development of Oil and Gas Fields, 1, 24-31.
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The article is devoted to the analysis of the field preparation of hard-to-recover oils on the example of a field in Kazakhstan. On the basis of laboratory and field studies, the physicochemical properties of oil emulsions were studied, the characters of the emulsion were identified by the type of natural stabilizers, the group composition, their aggregate stability, as well as rheological features were determined. In the article the main reasons that complicate the processes of field preparation of hard-to-recover, rheologically complex oils were analyzed and identified. Some ways of improving the efficiency of field treatment of high-viscosity oils in the presence of intensive technogenic impact on the formation in order to increase the oil recovery factor are also indicated.

Keywords: oil-water emulsion; hydrogen sulfide; mechanical impurities; intermediate layer; sulfate-reducing bacteria; thionic bacteria; dispersed composition; aggregate stability; iron sulfide; demulsifier; stabilizer.

References

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The state of Russia's resource base has a downward trend. In the light of the need to keep the economic indicators not lower than the achieved ones, the emerging problems in the production of hydrocarbons require to solve them are use of new methods. Reducing the volume of associated water, maintaining the environmental safety of oil production while maintaining and even reducing the cost of oil production, due to new technologies and materials, are urgent tasks. For issues of reliable restoration of the technical condition of wells and the limitation of water inflow are this work is devoted. The technology based on the use of a modified polymer water-insulating composition is presented. Analytical and field studies were conducted. The technology and the polymer composition have shown the possibility of application during water inflow restriction and repair and insulation works.

Keywords: repair and insulation works; water shutoff; polymer composition; modification of the composition

References

1. Suleimanov, B. A., Ismailov, F. S., Veliyev, E. F., Dyshin, O. A. (2013). The influence of light metal nanoparticles on the strength of polymer gels used in oil industry. SOCAR Proceedings, 2, 24-28.
2. Suleimanov, B. A., Veliyev, E. F., Naghiyeva, N. V. (2020). Preformed particle gels for enhanced oil recovery. International Journal of Modern Physics B, 34(28), 2050260.
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6. Suleimanov, B. A., Guseynova, N. I., Veliyev, E. F. (2017, October). Control of displacement front uniformity by fractal dimensions. In: SPE Russian Petroleum Technology Conference. Society of Petroleum Engineers.
7. Suleimanov, B. A., Veliyev, E. F., Naghiyeva, N. V. (2021). Colloidal dispersion gels for in-depth permeability modification. Modern Physics Letters B, 35(01), 2150038.
8. Veliyev, E. F. (2020). Review of modern in-situ fluid diversion technologies. SOCAR Proceedings, 2, 50-66.
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10. Chang, H. L., Zhang, Z. Q., Wang, Q. М., et al. (2006). Advances in polymer flooding and alkaline/surfactant/ polymer processes as developed and applied in the Peoples Republic of China. SPE-89175-JPT. Journal of Petroleum Technology, 58(2), 84-89.
11. Diaz, D., Somaruga, C., Norman, C., Romero, J. (2008, April). Colloidal dispersion gels improve oil recovery in a heterogeneous argentina waterflood. SPE-113320-MS. In: SPE/DOE Symposium on Improved Oil Recovery, Tulsa. Society of Petroleum Engineers.
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13. Turner, B. (2009, March). Polymer gel water-shatoff application combined with stimulation increase oil production and life of wells in the Monterey Formation Offshore California. SPE-121194-MS. In: SPE Westen Regional Meeting held in San Jose, California, USA. Society of Petroleum Engineers.
14. Daneshy, A. А. (2006, February). Selection and execution criteria for water control treatments. SPE-98059-MS. In: SPE Symposium and Exhibition on Formation Damage Control, Lafayette, USA. Society of Petroleum Engineers.
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16. Ketova, Yu. A., Galkin, S. V., Sedova, V. A. (2019). Analysis of polymeric compositions application efficiency during repair and insulation works on oil wells. Oilfield Engineering, 12(612), 71 73.
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22. Suleimanov, B. A., Ismailov, F. S., Dyshin, O. A., Veliyev, E. F. (2016, October). Screening evaluation of EOR methods based on fuzzy logic and Bayesian inference mechanisms. SPE-182044-MS. In: SPE Russian Petroleum Technology Conference and Exhibition. Society of Petroleum Engineers.
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25. Suleimanov, B. A., Ismayilov, F. S., Veliyev, E. F. (2014). On the metal nanoparticles effect on the strength of polymer gels based on carboxymethyl cellulose, applying at oil recovery. Oil Industry, (1), 86-88.
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The thermobaric conditions for the formation of gas hydrates in the presence of the sodium salt of carboxymethylcellulose, dextran, and arabinogalactan were studied in a quasi-equilibrium thermodynamic experiment. It is established that polysaccharides slow down the rate and change the conditions of gas hydrate formation of a mixture of natural gases, showing the properties of a thermodynamic and kinetic inhibitor with technological efficiency exceeding methanol by 170-270 times when used in the same dosages. The results of the development of a «green» synergistic inhibitor of gas hydrate formation «Glycan RU» on their basis are presented, which includes a combination of thermodynamic and kinetic inhibitors. Pilot field tests of «Glycan RU» were carried out at the wells of the Priobskoye, Prirazlomnoye, Ombinsky, Zapadno-Ugutskoye oilfields. It was found that at dosages of 1000 g/m³ and 500 g/m³, there is no formation of hydrate plugs in the annulus. «Glycan RU» is recommended for industrial use by the technology of periodic injection and/or continuous dosing through wellhead dispensers.

Keywords: carboxymethylcellulose; dextran; arabinogalactan; polysaccharides; «green» inhibitor of gas hydrate formation; «Glycan RU».

References

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3. Ke, W., Kelland, M.A. (2016). Kinetic hydrate inhibitor studies for gas hydrate systems: a review of experimental equipment and test methods. Energy Fuels, 30(12), 10015−1002.
4. Birchwood, R., Dai, J., Shelander, D., Boswell, R. (2010). Developments in gas hydrates. Oilfield Review, 22(1), 18-33.
5. Kelland, M. A. (2017). Designing kinetic hydrate inhibitors—eight projects with only partial success, but some lessons learnt. Energy Fuels, 31(5), 5046-5054.
6. Carroll, J. (2014) Natural gas hydrates. A guide for engineers. US: Gulf Professional Publishing.
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10. Zhukov, A. Yu., Mukhamadiev. A. A. (2010). Methods of "green" chemistry: new ecofriendly solutions in the field of oilfield reagents. Oil Industry, 8, 138-139.
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One of the complex technological tasks in the process of drilling is to ensure the stability of the wellbore walls, as well as their modeling for further forecasting the state of the wellbore and the likelihood of hydraulic fracturing. This is due to the fact that most of the complications and factors affecting the equilibrium state of the wall are associated with external influences. The article discusses the mechanical and partially hydraulic aspects of solving the described problems associated with modeling the stability of the wellbore walls and predicting hydraulic fracturing. As a result of calculations, the necessary data are obtained for making a decision on the density of the drilling fluid for drilling the considered interval of rocks. The assumed model of the porous rock and the given calculation formulas make it possible to fully evaluate the influence of the formation fluid pressure on the mechanical processes in the rocks when they are opened by a well.

Keywords: hydraulic fracturing; blade bit; steel ball-shaped toothed bit; polycrystalline diamond bit; laser drilling; impact rope drilling; rotary drilling.

References

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Determination of reliable values of filtration parameters of productive strata is the most important task of monitoring the processes of developing reserves. One of the most effective methods for solving the problem is hydrodynamic testing of wells using the pressure recovery method, as well as modern methods - the pressure stabilization method and the method based on production analysis (Decline Analyze). This article is devoted to the assessment of the reliability of these three methods in determining the filtration parameters of terrigenous and carbonate productive deposits of oil fields
in the Perm Krai. To solve the problem, multivariate regression analysis was used. A series of multidimensional mathematical models of well flow rates was built using filtration parameters determined for each of the methods. It is proposed to consider the filtration parameters included in the models with the maximum statistical estimates of performance as the most reliable. With regard to the fields under consideration, it was found that in terrigenous reservoirs, all three methods demonstrate stable results. In carbonate reservoirs, reliable values of filtration parameters are determined by processing pressure build-up curves. Pressure stabilization and production analysis methods show less robust results and require additional research in order to develop sound recommendations for their practical application.

Keywords: permeability; skin factor; pressure stabilization curve; decline analyze; liquid flow rate; geological and technological parameters; oil deposit; carbonate deposits.

References

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19. Zhuikov, Yu.F., Ilyinskiy, A.V., Shikanov, E.A., Shikanov, A.E. (2019). Study of increasing the permeability of oil formation under ultrasound exposure using the neutron tunning methods. SOCAR Proceedings, 2019(2), 53-58.
20. Rogov, E.A. (2020). Study of the well nearbottomhole zone permeability during treatment by process fluids. Journal of Mining Institute, 242, 169-173.
21. Baspayev, Y.T., Ayapbergenov, Y.O., Rzayeva, S.D. (2018). Analysis of the well killing fluids effect on the filtration properties of the rocks of the «Uzen» field. SOCAR Proceedings, 2018(3), 38-44.

Most of the main types of complications in the process of drilling wells, such as collapses, taluses, collapses of the walls, the formation of caverns, etc., are associated with external mechanical and hydrodynamic effects on the walls of the wellbore. Therefore, ensuring the stability of the borehole walls is one of the urgent and difficult technological formation fluid pressure on mechanical processes in rocks when they are opened with a directional well, especially of horizontal wells. This article provides solutions to problems associated with hydraulic fracturing of a well and the condition of its prevention, calculation of generalized stresses in the rock formation for inclined well. As a result of this calculations, the necessary data are obtained for making a decision on the density of the drilling fluid to drilling the considered interval of rocks, as well as for making other technological decisions. The given calculation formulas make it possible to fully evaluate the effect of the formation fluid pressure on the mechanical processes in the rocks when they are opened by a horizontal well.

Keywords: hydraulic fracturing; blade bit; steel ball-shaped toothed bit; polycrystalline diamond bit; laser drilling; impact rope drilling; rotary drilling.

References

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The paper presents the possibilities of expanding production opportunities in the oil company PJSC Tatneft. For this purpose, the well No.xxx7g with an inclined pilot borehole was drilled at the Bavlinskoye oil field and oriented core samples were taken to study the lithological cross-section and the geological structure of the subsurface horizons. The horizontal wellbore itself is located in the dankovo-lebedyansky horizon, where multi-zone hydraulic fracturing was carried out through ports with packers there. The following methods will increase the share of recoverable oil reserves in the oldest oil-producing Volga region by starting the development of new productive horizons and increase the oil recovery factors for these reservoirs. The methods used in this work will reduce the unit costs of increasing oil production and achieve a cost-effective level of work on wells of this type. The work had its own peculiarities. One of the reasons for the difficulty in interpreting the hydraulic fracturing Minifrac (Meyer software package) was the rather long time of closing fractures in domanic deposits during the registration of pressure drop. In turn, during the minifrac analysis of the Nolte G Time Test graph showed that the fracture did not close, and therefore it is impossible to determine the closing pressure (the pressure gradient of the gap) with reliable accuracy. Note that when interpreting the flow test results, the best match of the experimental and calculated curves is achieved when using the model of a horizontal well operating a homogeneous reservoir. Also, the deterioration of the bottom-hole zone may be associated with a weak opening of the created fractures.

Keywords: oil; well; hydraulic fracturing; unconventionals; fracture; core.

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The paper discusses results of the unique field-scale experiment on halving of active wells and increase of pressure differential at bottomholes of active wells in the Bavlinskoye oil field. With a view to assess the effect of well interference between shut-in and active wells, two scenarios of oil flow lines in the reservoir, shut-in scenario and do-nothing scenario, were modeled. The numerical computation demonstrated that increase of pressure differential at an early stage of development can maintain the obtained level of production with a less number of free-flowing wells. It was also found that an optimal well pattern has to be used at an early stage of development. In this case, oil losses are lower vs. infill drilling at the late stage of development. In the latter case, high water cut challenges economic production, which was the case with half of re-entry experimental wells.

Keywords: free-flow production; increase of differential pressure; field-scale experiment; well pattern; well interference; oil flow paths.

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The article presents the developed algorithm and the results of carried out differentiation and grouping of oil deposits in the carbonate reservoirs of the Volga-Ural oil and gas province, both under development and out of exploration, according to geological parameters, the determination of which is possible at the stage of geological exploration. A method for selecting an analogue deposit, which has been in development for a long time has been worked out for a deposit coming out of exploration in order to use the experience of developing an analogue deposit in the conditions of a deposit being put into development. The comparison of the selected groups of objects by geological parameters is carried out, the characteristics of the features of each of them are given, the main differences in the geological structure are revealed. It has been established that the features of the geological structure of various groups of objects are mostly determined by their tectonic-stratigraphic confinement.

Keywords: free-flow production; increase of differential pressure; field-scale experiment; well pattern; well interference; oil flow paths.

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21. Rogachev, M. K., Mukhametshin, V. V. (2018). Control and regulation of the hydrochloric acid treatment of the bottomhole zone based on field-geological data. Journal of Mining Institute, 231, 275-280.
22. Mukhametshin, V. V., Kuleshova, L. S. (2020). On uncertainty level reduction in managing waterflooding of the deposits with hard to extract reserves. Bulletin of the Tomsk Polytechnic University. Geo Assets Engineering, 331, 5, 140–146.
23. Mukhametshin, V. V., Andreev, V. E., Dubinsky, G. S., et al. (2016). The usage of principles of system geologicaltechnological forecasting in the justification of the recovery methods. SOCAR Proceedings, 3, 46–51.
24. Akhmetov, R.T., Mukhametshin, V.V., Andreev, A.V., & Sultanov, Sh.Kh. (2017). Some testing results of productive strata wettability index forecasting technique. SOCAR Procеedings, 4, 83-87.

In article possibilities of predicting the viscosity of stable multicomponent water-oil systems in practice, when it is impossible, for a number of reasons, to obtain their experimental values, are considered. A predictive model is proposed to describe the change in the viscosity properties of various oil-water emulsions depending on the degree of water saturation. It is shown that the proposed formula allows to determine the effective viscosity of water-oil systems in the entire range of variation of the velocity gradient in the absence of experimental data and is acceptable for engineering practice.

Keywords: viscosity; water-oil emulsions; matematical description; water saturation degree; heterogeneous systems.

References

1. Safieva, R. Z., Syunyaev, R. Z. Physicochemical properties of dispersed system and oil & gas extraction technologies. Moscow-Izhevsk: Institute for Computer Research, «Regular and chaotic dynamics» SRC.
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Industrial experiment works (IEW) were carried out to study the mechanism of filtration and reservoir properties changes (FRP) in the process of wells swabbing. Based on the hydrodynamic studies, the results of the works are analyzed. A method for oil production enhancing by reservoirs hydraulic compression has been worked out. In the process of well swabbing the barograms were recorded, pressure recovery curves were taken with the determination of hydraulic conductivity and piezoconductivity values, potential productivity coefficients, well flow rate, reservoir pressure before and after exposure. The interpretation of hydrodynamic studies was carried out by the deterministic analysis with subsequent modeling of the situation. The reservoir, opened by the perforation interval, is of complex structure, as a result of which the liquid was absorbed by the interlayer located above the area with newly formed microcracks.

Keywords: hard-to-recover reserves; swabbing; carbonate reservoirs; filtration reservoir properties; pressure recovery curve.

References

1. Muslimov, R. Kh. (2014). Oil recovery: past, present, future (production optimization, maximization of recovery factor). Kazan: FEN.
2. Mukhametshin, V. V., Kuleshova, L. S. (2020). On uncertainty level reduction in managing waterflooding of the deposits with hard to extract reserves. Bulletin of the TPU. Geo Assets Engineering, 331(5), 140–146.
3. Andreev, A. V., Mukhametshin, V. Sh., Kotenev, Yu. A. (2016). Deposit productivity forecast in carbonate reservoirs with hard to recover reserves. SOCAR Procеedings, 3, 40-45.
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5. Mukhametshin, V. V. (2020). Oil production facilities management improving using the analogy method. SOCAR Proceedings, 4, 42-50.
6. Muslimov, R. Kh. (2016). A new strategy for the development of oil fields in modern Russia – optimization of production and maximization of KIN. Oil. Gas. Innovations, 4, 8–17.
7. Zubova, L. Yu, Zubova, O. D, Knyazev, P. Yu, Khuzin, R. R. (2012).Method of formation hydraulic compression. RU Patent 2462588.
8. Khuzin, R. R. (2012). Geotechnological bases of hardto-recover reserves of small complex oil fields. Samara: Oil. Gas. Innovations.
9. Yakupov, R. F., Mukhametshin, V. Sh. (2013). Problem of efficiency of low-productivity carbonate reservoir development on example of Turnaisian stage of Tuymazinskoye field. Oil Industry, 12, 106–110.
10. Davydova, A. E., Shchurenko, A. A., Dadakin, N. M., et al. (2018). Optimization of carbonate reservoir well testing. Perm Journal of Petroleum and Mining Engineering, 17(2), 123–135.
11. Du, X., Lu, Zh., Li, D., et al. (2019). A novel analytical well test model for fractured vuggy carbonate reservoirs considering the coupling between oil flow and wave propagation. Journal of Petroleum Science and Engineering, 173, 447–461.
12. Jing, C., Dong, X., Cuid, W., et al. (2020). Artificial neural network–based time-domain interwell tracer testing for ultralow-permeability fractured reservoirs. Journal of Petroleum Science and Engineering, 195.
13. Zoveidavianpoor, M., Samsuri, A., Shadizadeh, S. R. (2012, March). Development of a fuzzy system model for candidate-well selection for hydraulic fracturing in a carbonate reservoir. SPE-153200-MS. In: SPE Oil and Gas India Conference and Exhibition. Society of Petroleum Engineers
14. Mukhametshin, V. V., Andreev, V. E. (2018). Increasing the efficiency of assessing the performance of techniques aimed at expanding the use of resource potential of oilfields with hard-to-recover reserves. Bulletin of the TPU. Geo Assets Engineering, 329(8), 30–36.
15. Dinghong, C., Yuwei, N., Fei, Y., et al. (2006, May). Application and realization of fuzzy method for selecting wells and formations in fracturing in putaohua oilfield: production and operations: diagnostics and evaluation. SPE-106355-MS. In: SPE Technical Symposium of Saudi Arabia Section. Society of Petroleum Engineers
16. Yakupov, R. F., Mukhametshin, V. Sh., Tyncherov, K. T. (2018). Filtration model of oil coning in a bottom waterdrive reservoir. Periodico Tche Quimica, 15(30), 725-733.
17. Li, D., Zha, W., Liu, S., et al. (2016). Pressure transient analysis of low permeability reservoir with pseudo threshold pressure gradient. Journal of Petroleum Science and Engineering, 147, 308–316.
18. Mardashov, D. V., Rogachev, M. K., Zeigman, Yu. V., Mukhametshin, V. V. (2021). Well killing technology before workover operation in complicated conditions. Energies, 654, 1–15.
19. Wijaya, N., Sheng, J. J. (2020). Comparative study of well soaking timing (pre vs. post flowback) for water blockage removal from matrix-fracture interface. Petroleum, 6(3), 286–292.
20. Khuzina, L. B., Mukhametshin, V. Sh., Tyncherov, K. T., Shaikhutdinova, A. F. (2018). On the choice of the oscillators' installation site. International Journal of Civil Engineering and Technology, 9(9), 1952–1959.
21. Galkin, V. I., Ponomareva, I. N., Cherepanov, S. S., et al. (2020). New approach to the study of the results of hydraulic fracturing (on the example of bobrikovsky deposits of the Shershnevsky field). Bulletin of the TPU. Geo Assets Engineering, 331(4), 107–114.
22. Rogachev, M. K., Mukhametshin, V. V. (2018). Control and regulation of the hydrochloric acid treatment of the bottomhole zone based on field-geological data. Journal of Mining Institute, 231, 275–280.
23. Alvarado, V., Thyne, G., Murrel, G. R. (2008, September). Screening strategy for chemical enhanced oil recovery in Wyoming Basin. SPE-115940-MS. In: SPE Annual Technical Conference and Exhibition. Society of Petroleum Engineers.
24. Bulygin, D. V., Nikolaev, A. N., Elesin, A. V. (2018). Hydrodynamic evaluation of the efficiency of flow deflecting technologies in conditions of formation of manmade filtration channels. Georesources, 20, 3, 172–177.
25. He, J., Ling, K. (2016). Measuring permeabilities of Middle-Bakken samples using three different methods. Journal of Natural Gas Science and Engineering, 31, 28–38.
26. Yakupov, R. F., Mukhametshin, V. Sh., Khakimzyanov, I. N., Trofimov, V. E. (2019). Optimization of reserve production from water oil zones of D3ps horizon of Shkapovsky oil field by means of horizontal wells. Georesursy, 21(3), 55–61.

The influence of the electromagnetic field (EMF) on the corrosion of structural carbon steel in a 3% aqueous solution of sodium chloride in the presence of CO2 was studied. It is shown that the EMF increases the corrosion rate of steel by 1.13 times in a 3% aqueous solution of NaCl in the presence of CO₂. When Ca²⁺ ions are added to the solution, the corrosion rate of steel decreases under the influence of an electromagnetic field. It is assumed that the formation of CaCO₃ in the near-surface layer of the solution and its adsorption on the metal surface prevents the development of corrosion. The influence of the electromagnetic field generated in the frequency range from 100 to 200 kHz on the crystallization of CaCO₃ from supersaturated aqueous solutions on the model system CaCl₂ – NaHCO₃ – FeSO₄ is studied. It was found that Fe²⁺, rather than EMF, has a more significant effect on salt deposition. The efficiency of the effect of Fe2+ on the inhibition of salt deposition in the model of mineralized water CaCl₂-NaHCO₃ is 11.5% higher than when exposed to EMF. During the crystallization of CaCO₃, the predominant formation of aragonite is observed. In the presence of iron ions and under the influence of EMF, there was a decrease in the formation of aragonite and an increase in the formation of calcite and vaterite.

Keywords: electromagnetic field; corrosion; carbon steel; iron ions; scale deposition; crystallization; calcium carbonate.

References

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7. Alimbekova, S. R., Isangildina, T. R., Ishmuratov, F. G., et al. (2017). A new "green" electromagnetic method for preventing salt deposition in oil production. Problems of collection, preparation and transport of oil and petroleum products, 110(4), 63-72.
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9. Alimbekova, S. R. Dokichev, V. A. (2020). Effect of electromagnetic field on water-in-oil emulsion and calcium carbonate crystallization. IOP Conference Series: Materials Science and Engineering, 862, 062077.
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13. Korchef, A. (2019). Effect of iron ions on the crystal growth kinetics and microstructure of calcium carbonate. Crystal Growth and Design, 19(12), 6893-6902.
14. Mejri, W., Salah, I. B., Tlili, M. M. (2015). Speciation of Fe(II) and Fe(III) effect on CaCO3 crystallization. Crystal Research and Technology, 50(3), 236-243.
15. Alsaiari, H. A., Kan, A., Tomson, M. (2010). Effect of calcium and iron (II) ions on the precipitation of calcium carbonate and ferrous carbonate. SPE Journal, 15(2), 294-300.
16. Morse, J. W., Arvidson, R. S., Lüttge, A. (2007). Calcium carbonate formation and dissolution. Chemical Reviews, 107(2), 342-381.
17. Herzog, R. E., Shi, Q., Patil, J. N., Katz, J. L. (1989). Magnetic water treatment: the effect of iron on calcium carbonate nucleation and growth. Langmuir, 5, 861-867.
18. Oddo, J. E., Tomson, M. B. (1994). Why scale forms and how to predict it. SPE Production & Facilities, 2, 47-54.
19. Fedotov, M. A., Taraban, E. A., Zaikovskii, V. I., et al. (1998). Effect of magnetic field on the formation and aging of Fe(III) hydroxide. Russian Journal of Inorganic Chemistry, 43(3), 388-393.
20. Lesnin, V. I., Dunin, A. G., Khavkin, A. Ya. (1993). Changes in the physical and chemical properties of aqueous solutions under the influence of an electromagnetic field. Journal of Physical Chemistry, 67(7), 1561-1662.
21. Mansoori, H., Young, D., Brown, B., Singer, M. (2018). Influence of calcium and magnesium ions on CO2 corrosion of carbon steel in oil and gas production systems - A review. Journal of Natural Gas Science and Engineering, 59, 287–296.
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25. Schlomach, J., Quarch, K., Kind, M. (2006). Investigation of precipitation of calcium carbonate at high supersaturations. Chemical Engineering & Technology, 29, 215–220.

When developing hard-to-recover hydrocarbon reserves, enterprises use various complexes and systems to facilitate technological processes that contribute to the lifting of heavy and viscous oils to the surface, as well as the extraction of light oils from lowpermeability reservoirs. During the operation of fields, abnormal situations also arise, caused by the appearance of asphalt-resin-paraffin deposits (ARPD) and salt deposits on the walls of tubing pipes, Christmas trees, process pipelines and equipment at the bottom. The existing methods of combating and preventing the manifestations of ARPD and salt precipitation can be conditionally divided into mechanical, chemical, thermal. To prevent and combat ARPD, as well as to reduce the viscosity of produced oils, thermal methods are most preferred, among which electrothermal methods are considered effective. In the case of salt sediments, technologies based on electrical energy are also an effective means of prevention, in particular, exposure of the well emulsion to a magnetic field.

Keywords: electrical technological systems and complexes; hard-to-remove oil reserves; asphalt-resin-paraffin deposits; induction heating systems.

References

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Corrosion destruction of the metal of the field equipment and gas pipelines of the oil and gas condensate field (OGCF) was revealed, the cause of which is carbon dioxide corrosion. In order to determine the corrosiveness of the OGCF equipment media, laboratory tests were carried out with periodic moisture condensation in an atmosphere of carbon dioxide, autoclave tests in the liquid phase at elevated temperatures and partial pressure of CO₂, and laboratory tests in the gas-vapor phase in the presence of CO₂. Tests were carried out on steel 20, the selected solutions were tested on pipe segments of 09G2S steels (well connections and loops) and J55LT (tubing) of 2 types (old, after operation in a well, and new, not operated). Studies have shown that steels used at OGCF (steel 20, J55LT and 09G2S) are not resistant to carbon dioxide corrosion. All items of equipment made of these steels will be potentially weakly resistant to corrosion in the oil and gas condensate field. It is proposed to conduct tests of corrosion inhibitors from various manufacturers in laboratory and field conditions. Recommendations are given for the corrosion inhibitor selected according to the test results.

Keywords: local corrosion; aggressiveness of the environment; metal resistance; well piping; plume; tubing; laboratory tests; autoclave tests.

References

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8. Izmaylova, G. R. (2019). Mathematical modeling of high-viscosity index oil formation with a sonic field at various frequencies. Journal of Physics: Conference Series, 1333(3), 032030

Due to the insufficiently effective gas drying in preparing it for further transport on the main pipeline in the composition of the gas remains a sufficient amount of fluid. The presence of liquid inclusions in the transported streams causes a nonequilibrium behavior of such systems, which is not taken into account in traditional calculation methods and increases the calculation error. Therefore, to select an adequate transfer mode, it is necessary to diagnose the internal structure of natural gas systems, which is the main task of studying this article. In working on the basis of a generalized model of motion of the relaxation medium in the pipeline by the introduction of the equation of the state for nonequilibrium gases, the calculated ratios are obtained to estimate the hydraulic and nonequilibrium parameters of the gas flow. In order to numerically implement these relations, a computational algorithm was drawn up and on the basis of the operational data of the actual gas pipeline obtained appropriate estimates. The results of the calculations were shown that both the density and the pressure relaxation times are rather significant. This indicates the presence of liquid inclusions in the transport stream. Thus, the authors proposed a numerically implemented procedure for diagnosing the presence of liquid inclusions in natural gases, which can be recommended for the use of services engaged in the operation of main gas pipelines.

Keywords: natural gas; gas pipeline; liquid inclusions; model; diagnostics.

References

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Deposits of tight high viscosity heavy and waxy oil are becoming increasingly important in the world economy. They are also of particular importance in Russia, where the fields of easy accessible oil are practically depleted, and the newly discovered ones are located mainly in the northern latitudes of the country, which complicates their delivery to places of consumption, and use of so-called "special methods" (heating, chemical reagents) leadsytanb to an increase Cost. Despite the abundance of such methods, one can distinguish one of the most accessible and understandable from the point of view of the physico-chemical effect - dilution with hydrocarbon diluents, as can be effectively used by adding ready-made motor fuels and light distillates of oil, as well as - cheaper stable gas condensate, also co-produced in oil fields.In the present work, the experience of blending high viscosity heavy and congealing waxy oil with various types of hydrocarbon diluents has been considered with the aim of improving the operational properties of hydrocarbon crude, the transport and processing of which are associated with high costs due to the peculiarities of the composition and properties of the oil. The results of laboratory experiments on dilution of heavy and congealing oils with diesel fuel and stable gas condensate are given, on the basis of which recommendations on the effective usage these special methods.

Keywords: oil; rheology; effective viscosity; pour point; hydrocarbon diluent; stable gas condensate.

References

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The paper provides a review of up-to-date approaches for extinguishing oil and petroleum products. The variability of extinguishing methods and fire extinguishing agents is noted. Fire extinguishing agents used in extinguishing petroleum products are considered in more detailed way, and their environmental characteristics are discussed. The ambiguity of using various foams for extinguishing the fire is shown. A new method for extinguishing oil and petroleum products, based on the acoustic effect, and the capabilities of acoustic fire extinguishers for preventing and eliminating the combustible hydrocarbon fires, and their identification are analyzed. The further development of known approaches and the simultaneous emergence of innovative methods for extinguishing oil and petroleum products are shown.

Keywords: oil; petroleum products; extinguishing agent; environmental characteristics; extinguishing foam; acoustic method.

References

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The cooling recycled water of petrochemical enterprises is characterized by high corrosion activity, unstable composition and, due to the evaporation of water in cooling towers, a constant increase in the concentration of dissolved salts, suspended particles and organic pollutants. Some of the salts formed by divalent metal ions fall out in the form of deposits, and the water is satu-rated with chlorine, sulfate, phosphate, and carbonations and becomes corrosive. At the same time, the corrosion activity of reservoir water varies widely depending on the saturation of cer-tain ions and other ingredients. It is established that monitoring the composition of recycled water and determining the corrosion rate of equipment and pipelines, carried out within 1-2 months, allow us to build a regression model of the dependence of the corrosion rate on the technical parameters of water, with which we can accurately calculate the values of the corrosion rate on the evaporation coefficient. Monitoring of technological environments and optimization of their composition through mathematical modeling will significantly improve the safety of equipment and pipelines operation at oil refining enterprises.

Keywords: corrosion inhibitor; scale inhibitor; biocide; water circulation system; evaporation coefficient; monitoring; cooling water; regression model.

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