SOCAR Proceedings

SOCAR Proceedings

Published by "OilGasScientificResearchProject" Institute of State Oil Company of Azerbaijan Republic (SOCAR).

SOCAR Proceedings is published from 1930 and is intended for oil and gas industry specialists, post-graduate (students) and scientific workers.

Journal is indexed in Web of Science (Emerging Sources Citation Index), SCOPUS and Russian Scientific Citation Index, and abstracted in EI’s Compendex, Petroleum Abstracts (Tulsa), Inspec, Chemical Abstracts database.

V.Yu. Kerimov1, N.Sh. Yandarbiev2, R.N. Mustaev1, S.A. Alieva3

1Sergo Ordzhonikidze Russian State University for Geological Prospecting,Moscow, Russia; 2Lomonosov Moscow State University, Moscow, Russia; 3Azerbaijan State Oil and Industry University, Baku, Azerbaijan

Features of generation, migration and accumulation of hydrocarbons in the eastern part of the Skythian plate


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.

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

  1. Konyukhov, A. I., Yandarbiev, N. Sh. (2008). Lithology and conditions of the formation of paleozoic rocks in northern areas of the Scythian plate. Lithology and Mineral Resources, 43(1), 25-42.
  2. Panina, L. V., Kostenko, N. P. (2005). Novejshie deformacii na vostoke Skifskoj plity. Vestnik Moskovskogo universiteta. Seriya 4: Geologiya, 3, 5-11.
  3. Bazhenova O. K., Fadeeva N. P., Petrichenko YU. A., Suslova E. YU. (2004). Zakonomernosti nefteobrazovaniya v osadochnyh bassejnah Kavkazsko-Skifskogo regiona. Ekologicheskij vestnik nauchnyh centrov Chernomorskogo ekonomicheskogo sotrudnichestva, 1.
  4. Rachinsky, M. Z., Kerimov, V. Y. (2015). Fluid dynamics of oil and gas reservoirs /Ed. Gorfunkel, M.V. NY, USA: Scrivener Publ. ‒ Whiley.
  5. Kerimov, V. Y., Mustaev, R. N., Osipov, A. V. (2018). Peculiarities of hydrocarbon generation at great depths in the crust. Doklady Earth Sciences, 483(1), 1413–1417.
  6. Gordadze, G. N., Kerimov, V. Y., Gaiduk, A. V., et al. (2017). Hydrocarbon biomarkers and diamondoid hydrocarbons from late Precambrian and lower Cambrian rocks of the Katanga saddle (Siberian Platform). Geochemistry International, 55(4), 360–366.
  7. Leonov, M. G., Kerimov, V. Y., Mustaev, R. N., Hai, V. N. (2020). The origin and mechanism of formation of hydrocarbon deposits of the Vietnamese Shelf. Russian Journal of Pacific Geology, 14(5), 387–398.
  8. Kerimov, V. Y., Gordadze, G. N., Lapidus, A. L., et al. (2018). Physicochemical properties and genesis of the asphaltites of Orenburg oblast. Solid Fuel Chemistry, 52(2), 128–137.
  9. Gordadze, G., Kerimov, V., Giruts, M., et al. (2018). Genesis of the asphaltite of the Ivanovskoe field in the Orenburg region, Russia. Fuel, 216, 835–842.
  10. Mustaev, R. N., Kerimov, V. Y., Shilov, G. Y., Dmitrievsky, S. S. (2016). Modeling of thermobaric conditions formation of the shale hydrocarbon accumulations in lowpermeability reservoirs khadum formation Ciscaucasia. In Geomodel 2016 - 18th Science and Applied Research Conference on Oil and Gas Geological Exploration and Development.
  11. Kerimov, V., Rachinsky, M., Mustaev, R., Serikova, U. (2018). Geothermal conditions of hydrocarbon formation in the South Caspian basin. Iranian Journal of Earth Sciences, 10, 78-89.
  12. Kerimov, V. Y., Bondarev, A. V., Mustaev, R. N. (2017). Estimation of geological risks in searching and exploration of hydrocarbon deposits. Oil Industry, 8, 36–41.
  13. Guliev, S., Mustaev, R. N., Kerimov, V. Y., Yudin, M. N. (2018). Degassing of the earth: Scale and implications. Gornyi Zhurnal, 11, 38–42.
  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.
  17. Yandarbiev, N. Sh., Bachin, S. I., Mollaev, Z. H., et al. (2014). Oil and gas potential prediction for jurassic deposits in the western part of the Tersko-Caspian depression, based on the basin modeling. Russian Oil and Gas Geology, 3, 17-26.
  18. Stupakova, A. V., Kazanin, G. S., Ivanov, G. I., et al. (2014). The modeling of hydrocarbons formation proccesses in the South-Kara depression. Prospect and protection of mineral resources, 4, 47-51.
  19. Guliyev, I. S., Kerimov, V. Yu., Mustaev, R. N., Bondarev, A. V. (2018). The estimation of the generation potential of the low permeable shale strata of the Maikop Caucasian Series. SOCAR Proceedings, 1, 4-20.
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DOI: 10.5510/OGP2021SI100504

E-mail: r.mustaev@mail.ru


B.S. Serkebayeva

Atyrau Branch of KMG Engineering, Atyrau, Kazakhstan

On the reasons for the complication of field preparation hard-to-recover oils during technogenic impact on the formation


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.

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

  1. Bajkov, N. M., Pozdnyshev, G. N., Mansurov, R. I. (1981). Sbor i podgotovka nefti, gaza i vody. Moskva: Nedra.
  2. Persiyancev, M. N. (1999). Sovershenstvovanie processov separacii nefti ot gaza v promyslovyh usloviyah. Moskva: OOO «Nedra-Biznescentr».
  3. Vinogradov, V. M., Vinokurov, V. A. (2007). Obrazovanie, svojstva i metody razrusheniya neftyanyh emul'sij. Moskva: RGU nefti i gaza im. I.M. Gubkina.
  4. Kamenshchikov, F. A., Chernyh, N. A. (2007). Bor'ba s sul'fatvosstanavlivayushchimi bakteriyami na neftyanyh mestorozhdeniyah. Moskva-Izhevsk: IKI.
  5. Hafizov. N. N. (2009). Razrabotka tekhnologii obessolivaniya nefti na promyslah. Dissertaciya na soiskanie uchenoj stepeni kandidata tekhnicheskih nauk. Ufa: UGNTU.
  6. Rozanova, E. P., Kuznecov, S. I. (1974). Mikro-flora neftyanyh mestorozhdenij. Moskva: Nauka.
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DOI: 10.5510/OGP2021SI100505

E-mail: Serkebayeva_B@kaznipi.kz


V.G. Mukhametshin1, G.S. Dubinsky2,3

1«NizhnevartovskNIPIneft» OJSC, Nizhnevartovsk, Russia; 2Ufa State Petroleum Technical University, Ufa, Russia; 3Strategy Research Institute of the Republic of Bashkortostan, Ufa, Russia

Application of polymer compositions in repair and insulation works in wells


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

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.
  3. Veliyev, E. F., Aliyev, A. A., Guliyev, V. V., Naghiyeva, N. V. (2019, October). Water shutoff using crosslinked polymer gels. In: SPE Annual Caspian Technical Conference. Society of Petroleum Engineers.
  4. Vishnyakov, V., Suleimanov, B., Salmanov, A., Zeynalov, E. (2019). Primer on enhanced oil recovery. Gulf Professional Publishing.
  5. Suleimanov, B. A., Veliyev, E. F., Azizagha, A. A. (2020). Colloidal dispersion nanogels for in-situ fluid diversion. Journal of Petroleum Science and Engineering, 193, 107411.
  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.
  9. Велиев, Э. Ф. (2021). Veliyev, E. F. (2021). Polymer dispersed system for in-situ fluid diversion. Prospecting and Development of Oil and Gas Fields, (1(78), 61–72.
  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.
  12. Satter, A., Iqbal, G. М., Buchwalter, J. L. (2008). Practical enhanced reservoir engineering: assisted with simulation software. Tulsa: PennWell Corporation.
  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.
  15. Suleimanov, B. A., Veliyev, E. F. (2016). The effect of particle size distribution and the nano-sized additives on the quality of annulus isolation in well cementing. SOCAR Proceedings, (4), 4-10.
  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.
  17. Basargin, Yu. M., Bulatov, A. I., Dadyka, V. I. (2004). Materials and reagents for repair and insulation works in oil and gas wells. Moscow: Nedra-Binescenter LLC.
  18. Akhmetov, A. A., Kiryakov, G. A., Klyusov, I. A., Yuzvitsky, V. P. (2003). Polymer cement compositions for installation of waterisolation bridging plugs in Senomansk wells. Oil Industry, 3, 68-69.
  19. Ametov, I. M., Sherstnev, N. M. (1989). Application of composite systems in process operations of wells operation. Moscow: Nedra.
  20. Suleimanov, B. A., Ismayilov, F. S., Dyshin, O. A., Veliyev, E. F. (2016). Selection methodology for screening evaluation of EOR methods. Petroleum Science and Technology, 34(10), 961-970.
  21. Suleimanov, B. A., Veliyev, E. F. (2016, November). Nanogels for deep reservoir conformance control. SPE-182534-MS. In: SPE Annual Caspian Technical Conference & Exhibition. Society of Petroleum Engineers.
  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.
  23. Suleimanov, B. A., Veliyev, E. F., Dyshin, O. A. (2015). Effect of nanoparticles on the compressive strength of polymer gels used for enhanced oil recovery (EOR). Petroleum Science and Technology, 33(10), 1133-1140.
  24. Suleimanov, B. A., Dyshin, O. A., & Veliyev, E. F. (2016, October). Compressive strength of polymer nanogels used for enhanced oil recovery EOR. SPE-181960-MS. In SPE Russian Petroleum Technology Conference and Exhibition. Society of Petroleum Engineers.
  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.
  26. Veliyev, E. F. (2020). Mechanisms of polymer retention in porous media. SOCAR Proceedings, 3, 126-134.
  27. Sakhipov, D. M., Apasov, T. C, Sakhipov, E. M., Apasov, G. T. (2012). Practical application of composition system of PGCS at oil fields of Nizhnevartovsk district. In: VIII All-Russian Scientific and Technical Conference «Geology and oil and gas content of West Siberian Megabassein» (dedicated to the 100th anniversary of Muravlenko Viktor Ivanovich). Tyumen: TyumGNSU.
  28. Lanchakov, G., Moskvichev, V., Stavitskiy, V., Griguletsky, V. (2009, October). New materials and methods of insulation repair works in gas wells on Urengoy Field. In: International Gas Union World Gas Conference Papers. 24th World Gas Conference, WGC 2009. Buenos Aires.
  29. Trotsky, V. F. (1993). Development of technology and technique for well overhaul at the late stage of gas condensate field development. PhD disseration. Moscow.
  30. Sinhurov, A. A., Nifantov, V. I., Pishchukhin, V. M., Gilfanova, E. V. (2014). Technologies and compositions for water insulation operations in gas wells. Problems of Development of Gas, Gas Condensate and Oil and Gas Condensate Fields, 4(20), 75-80.
  31. Dubinsky, G. S., Kononova, T. G. (2010, May). Study of a water-insulating composition based on alumosilicate and hydrolyzed polyacrylonitrile. In: Scientific and Practical Conferences «Problems and methods of ensuring the reliability and safety of oil, oil products and gas transportation systems. Problems and methods of rational use of associated petroleum gas». Ufa: PMT «IPTER».
  32. Akchurin, H. I., Dubinsky, G. S., Kononova, T. G., Chezlova, A. V. (2009). Method of treatment of productive formation with water-insulating composition. RU Patent 2374425.
  33. Apasov, T. C., Apasov, G. T., Mukhametshin, V. G. (2014). A method of increasing oil recovery in inhomogeneous, highly watered, porous and fractured-porous, low and high-temperature productive formations. RU Patent 2528805.
  34. Mukhametshin, V. G., Apasov, T. C., Apasov, G. T., et al. (2013). Tamponage composition based on carbamideformaldehyde resin. In: International Scientific and Technical Conference dedicated to the 50th anniversary of the Tyumen Industrial Institute. Tyumen: TIU.
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DOI: 10.5510/OGP2021SI100506

E-mail: intnm-gsd@ya.ru


V.A. Dokichev1,2, A.I. Voloshin3, N.E. Nifantiev4, M.P. Egorov4, D.R. Kireeva1, A.V. Isakov2, R.N. Bakhtizin5, R.U. Rabaev5

1Ufa Institute of Chemistry UFRC RAS, Ufa, Russia; 2USATU, Ufa, Russia; 3RN-BashNIPIneft LLC, Ufa, Russia; 4N.D.Zelinsky Institute of Organic Chemistry of the RAS, Moscow, Russia; 5USPTU, Ufa, Russia

New «green» inhibitors of gas hydrate formation for the oil and gas industry based on polysaccharides


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».

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

  1. Barker, J. W., Gomez, R. K. (1989). Formation of hydrates during deepwater drilling operations. SPE-16130-PA. Journal of Petroleum Technology, 41(3), 297–301.
  2. Mu, L., von Solms, N. (2020). Inhibition of natural gas hydrate in the system containing salts and crude oil. Journal of Petroleum Science Engineering, 188, 106940.
  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.
  7. Carpenter, C. (2019) Benefits of low-dosage hydrate inhibitors. Journal of Petroleum Technology, 71(9), 94–95.
  8. Perrin, A., Musa, O. M., & Steed, J. W. (2013) The chemistry of low dosage clathrate hydrate inhibitors. Chemical Society Reviews, 42, 1996-2015.
  9. Fu, W., Wang, Z., Chen, L., & Sun, B. (2020). Experimental investigation of methane hydrate formation in the carboxymethylcellulose (CMC) aqueous solution. SPE-199367-PA. SPE Journal, 25(03), 1042–1056.
  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.
  11. Dokichev, V. A., Koptyaeva, E. I., Ishmuratov, F. G., et al. (2016). Carbohydrates - a new class of green scale inhibitors. Oil Industry, 5, 92-94.
  12. Fraser-Reld, B. O., Tatsuta, K., Thlem, J., et al. (2008). Glycoscience. Chemistry and chemical biology. Vol. 3. Berlin, Heidelber: Springer-Verlag.
  13. Ishmuratov, F. G., Rakhimova, N. T., Ishmiyarov, E. R., et al. (2018). New "green" polysaccharidal inhibitor of gas hydrate formation on the basis of carboxymethylcellulose sodium salt. Russian Journal of Applied Chemistry, 91(4), 653−656.
  14. Altamash, T., Qureshi, M. F., Aparicio, S., et al. (2017). Gas hydrates inhibition via combined biomolecules and synergistic materials at wide process conditions. Journal of Natural Gas Science and Engineering, 46, 873-883.
  15. Antonova, G. F., Usov, A. I. (1984). Structure of arabinogalactan from siberian larch (Larix sibirica Ledeb) wood. Bioorganicheskaya Khimiya, 10(12), P. 1664-1669.
  16. Haghighi, H., Chapoy, A., Burgess, R., et al. (2009). Phase equilibria for petroleum reservoir fluids containing water and aqueous methanol solutions: measurements and modelling using the CPA equation of state. Fluid Phase Equilibria, 278(1-2), 109–116.
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DOI: 10.5510/OGP2021SI100507

E-mail: voloshinai3@mail.ru


A.N. Popov, R.A. Ismakov, F.N. Yangirov, A.R. Yakhin, Abusal Yusef, I.D. Mukhametgaliev, G.L. Gaymaletdinova

Ufa State Petroleum Technical University, Ufa, Russia

Theoretical preconditions for modeling wellbore stability and predicting hydraulic fracturing


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.

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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  3. Turchaninov, I. A., Iofis, M. A., Casparian, E`.V. (1977). Osnovy` mehaniki gorny`kh pord. Moskva: Nedra.
  4. Popov, A. N., Golovkina, N. N. (2001). Prochnostny`e raschety` stenok skvazhiny` v poristy`kh gorny`kh porodakh. Ufa: UGNTU.
  5. Sel`vashchuk, A. P., Bondarenko, A. P., Ul`ianov, M. G. (1981). Prognozirovanie gradienta davleniia otkry`tiia pogloshchenii` pri burenii skvazhin na mestorozhdeniiakh Vostochnoi` Ukrainy. Obzor informasiya. Seiya «Burenie gazovy`kh i gazokondensatny`kh skvazhin». Moskva: VNIIE`gazprom.
  6. Eaton, B. A. (1969). Fracture gradient friction and its application in oil field operations. Journal of Petroleum Technology, 21(10), 1353–1360.
  7. Lekhnitckii`, S. G. (1938). Opredelenie napriazhenii` v uprugom izotropnom massive vblizi vertikal`noi` tcilindricheskoi` vy`rabotki kruglogo secheniia. Izvestiya AN SSSR, OTN.
  8. Zheltov, Yu. P. (1966). Deformatcii gorny`kh porod. Moskva: Nedra.
  9. Ovchinnikov, V. P. (2017). Tekhnologiia bureniia neftiany`kh i gazovy`kh skvazhin: uchebnik dlia studentov vuzov. T. 1. Tiumen: TiumGNGU.
  10. Baclashov, I. V., Kartoziia, B. A. (1975). Mehanika gorny`kh porod. Moskva: Nedra.
  11. Alekseev, Yu. F. (1968). Ispol`zovanie danny`kh po mehanicheskim i abrazivny`m svoi`stvam gorny`kh porod pri burenii skvazhin. Moskva: Nedra.
  12. Ismakov, R. A., Popov, A. N., Golovkina, N. N. (2004). Opredelenie privedennogo predela tekuchesti gornoi` porody` po shtampu s uchetom masshtabnogo e`ffekta. Izvwstiya vuzov. Gorny`i` zhurnal. Ural`skoe gornoe obozrenie, 4, 127-131.
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DOI: 10.5510/OGP2021SI100508

E-mail: 9406622@mail.ru


D.A. Martyushev, I.N. Ponomareva, V.I. Galkin

Perm National Research Polytechnic University, Perm, Russian Federation

Estimation of the reliability of determination of filtering parameters of productive formations using multi-dimensional regression analysis


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.

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

  1. Davydova, A. E., Shchurenko, A. A., Dadakin, N. M., et al. (2019). Well testing design development in carbonate reservoir. Bulletin of the Tomsk Polytechnic University, Geo Assets Engineering, 330(6), с. 68-79.
  2. Elesin, A. V., Kadyrova, A. S., Nikiforov, A. I. (2018). Definition of the reservoir permeability field according to pressure measurements on wells with the use of spline function. Georesursy, 20(2), с. 102-107.
  3. Liu, Q., Lu, H., Li, L., Mu, A. (2018). Study on characteristics of well-test type curves for composite reservoir with sealing faults. Petroleum, 4(3), 309-317.
  4. Smetkina, M. A., Melkishev, O. A., Prisyashnyuk, M. A. (2020). Refining the values of permeability when adapting the hydrodynamic model. Perm Journal of Petroleum and Mining Engineering, 20(3), 223-230.
  5. Liu, X., Li, D., Zha, W., et al. (2020). Automatic well test interpretation based on convolutional neural network for infinite reservoir. Journal of Petroleum Science and Engineering, 195, 107618.
  6. Martyushev, D. A., Slushkina, A. Yu. (2019). Assessment of informative value in determination of reservoir filtration parameters based on interpretation of pressure stabilization curves. Bulletin of the Tomsk Polytechnic University, Geo Assets Engineering, 330(10), с. 26-32.
  7. Ponomareva, I. N., Martyushev, D. A. (2019). Estimating reliability of reservoir properties determination on the basis of production analysis and pressure stabilization curves. Neftyanoe Khozyaystvo - Oil Industry, 8, 111-113.
  8. 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.
  9. Wang, X., Qiao, X., Mi, N., Wang, R. (2019). Technologies for the benefit development of lowpermeability tight sandstone gas reservoirs in the Yan'an Gas Field, Ordos Basin. Natural Gas Industry B, 6(3), 272-281.
  10. Hu, W., Wei, Y., Bao, J. (2018). Development of the theory and technology for low permeability reservoirs in China. Petroleum Exploration and Development, 45(4), 685-697.
  11. Silva, T. M. D., Bela, R. V., Pesco, S., Barreto Jr., A. (2021). ES-MDA applied to estimate skin zone properties from injectivity tests data in multilayer reservoirs. Computers & Geosciences, 146, 104635. 
  12. 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 Tomsk Polytechnic University, Geo Assets Engineering, 331(4), 107-114.
  13. Iktissanov, V.A. (2020). Description of steady inflow of fluid to wells with different configurations and various partial drilling-in. Journal of Mining Institute, 243, 305-312.
  14. Kasyanov I.V., Nezdanov A.A. (2020). Role of rock carbonation in formation of hydrocarbon deposits in Western Siberia. Oil and Gas Geology, 1, 69-79.
  15. Ibatullin, R.R. (2020). The geological diversity of oil deposits is the basis for the technological development of the industry. Georesursy, Special Issue, 28-31.
  16. Grachev, S.I., Korotenko, V.A., Kushakova, N.P. (2020). Study on influence of two-phase filtration transformation on formation of zones of undeveloped oil reserves. Journal of Mining Institute, 241, 68-82.
  17. Maksimov, V.M. (2020). Generalized law of multiphase filtration and new effects of surface phenomena at two-phase flows in a porous medium. Georesursy, 21(1), 86-91.
  18. Dorfman, M.B., Sentemov, A.A. (2020). Influence of reservoir properties of the bottomhole zone on acidizing efficiency. Bulletin of the Tomsk Polytechnic University, Geo Assets Engineering, 331(2), 124-130.
  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.
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DOI: 10.5510/OGP2021SI100509

E-mail: martyushevd@inbox.ru


A.N. Popov, R.A. Ismakov, A.R. Yakhin, I.D. Mukhametgaliev

Ufa State Petroleum Technical University, Ufa, Russia

Some issues of ensuring the stability of the walls of directional wells and preventing the absorption of process fluids


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.

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

  1. Ippolitov, K. V., Shturn, D. V., Kamenskii`, L. A. (2016). Sovremenny`e tendentcii stroitel`stva skvazhin v slozhnopostroenny`kh uchastkakh nedr i innovatcionny`e tekhnologii v burenii. Nauka i tekhnika v gazovoi` promy`shlennosti, 4(68), 98-101.
  2. Jusupov, Ya. I., Kalmykov, G. A. (2020). Geomechanical modelling for well stability prediction and optimizing parameters for hydraulic fracturing design (Krasnoleninsky Arch, Western Siberia). Burenie i neft, 9, 51-56.
  3. Pyatakhin, M. V., Pyatakhina, Yu. M. (2017). A new approach in geomechanical modelling to optimize reservoir production, drilling and hydraulic fracturing. Gas Science Bulletin, 1(29), 259-266.
  4. Alimzhanov, M. T. (1982). Ustoi`chivost` ravnovesiia tel i zadachi mehaniki gorny`kh porod. Alma-Ata: Nauka.
  5. Shakurova, Al. F., Shakurova, Ai. F. (2014). Modeling of a formation hydraulic fracture. The online edition «Oil and Gas Business», 2, 33-47.
  6. Turchaninov, I. A., Iofis, M. A., Casparian, E`.V. (1977). Osnovy` mehaniki gorny`kh pord. Moskva: Nedra.
  7. Eaton, B. A. (1969). Fracture gradient friction and its application in oil field operations. Journal of Petroleum Technology, 21(10), 1353–1360.
  8. Popov, A. N., Golovkina, N. N. (2001). Prochnostny`e raschety` stenok skvazhiny` v poristy`kh gorny`kh porodakh. Ufa: UGNTU.
  9. Ismakov, R. A., Popov, A. N., Golovkina, N. N. (2004). Opredelenie privedennogo predela tekuchesti gornoi` porody` po shtampu s uchetom masshtabnogo e`ffekta. Izvwstiya vuzov. Gorny`i` zhurnal. Ural`skoe gornoe obozrenie, 4, 127-131.
  10. Zheltov, Yu. P. (1966). Deformatcii gorny`kh porod. Moskva: Nedra.
  11. Ismakov, R. A., Popov, A. N., Valitov, R. A. (2003). Obosnovanie prochnostny`kh raschetov stenok naclonnoi` skvazhiny. Neftegazovoe delo, 1, 105-109.
  12. Baclashov, I. V., Kartoziia, B. A. (1975). Mehanika gorny`kh porod. Moskva: Nedra.
  13. Alekseev, Yu. F. (1968). Ispol`zovanie danny`kh po mehanicheskim i abrazivny`m svoi`stvam gorny`kh porod pri burenii skvazhin. Moskva: Nedra.
  14. Iahin, A. R. (2015). Uluchshenie tribotekhnicheskikh svoi`stv burovy`kh promy`vochny`kh zhidkostei` primeneniem dobavok kompleksnogo dei`stviia. Dissertatciia na soiskanie uchyonoi` stepeni kandidata tekhnicheskikh nauk. Ufa: UGNTU.
  15. Sel`vashchuk, A. P., Bondarenko, A. P., Ul`ianov, M. G. (1981). Prognozirovanie gradienta davleniia otkry`tiia pogloshchenii` pri burenii skvazhin na mestorozhdeniiakh Vostochnoi` Ukrainy. Obzor informasiya. Seiya «Burenie gazovy`kh i gazokondensatny`kh skvazhin». Moskva: VNIIE`gazprom.
  16. Ismakov, R. A., Popov, A. N. (2003). Obobshchenny`e harakteristiki napriazhennogo sostoianiia gorny`kh porod stenki naclonnoi` skvazhiny. Izvestiia vuzov «Neft` i gaz», 5, 18-23.
  17. Ovchinnikov, V. P. (2017). Tekhnologiia bureniia neftiany`kh i gazovy`kh skvazhin: uchebnik dlia studentov vuzov. T. 1. Tiumen: TiumGNGU.
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DOI: 10.5510/OGP2021SI100510

E-mail: 9406622@mail.ru


L.S. Kuleshova1, I.G. Fattakhov1, Sh.Kh. Sultanov1, R.U. Rabaev1, V.V. Mukhametshin1, G.M. Siraeva2

1Ufa State Petroleum Technical University, Ufa, Russia; 2PJSC TATNEFT named after V.D.Shashin, Almetyevsk, Russia

Experience in conducting multi-zone hydraulic fracturing on the oilfield of PJSC «Tatneft»


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.

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.

References

  1. Shoupeng, Zh., Zhengwei, F. (2020). Permeability damage micro-mechanisms and stimulation of lowpermeability sandstone reservoirs: A case study from Jiyang Depression, Bohai Bay Basin, China. Petroleum Exploration and Development, 47(2), 374-382.
  2. Khayredinov, N. Sh., Popov, A. M., Mukhametshin, V.Sh. (1992). Increasing the flooding efficiency of poorproducing oil deposits in carbonate collectors. Oil industry, 9, 18–20.
  3. Gasumov, E. R., Gasumov, R. A. (2020). Innovative risk management for geological and technical (technological) measures at oil and gas fields. SOCAR Proceedings, 2, 8-16.
  4. Yaskin, S. A., Mukhametshin, V. V., Kuleshova, L. S. (2021). Geological and technological justification of the bottom-hole zone treatment of wells and formations of the Langepas group of fields. IOP Conference Series: Materials Science and Engineering, 1064, 012073, 1-5.
  5. Wang, L., Mou, J., Mo, S., et al. (2020). Modeling matrix acidizing in naturally fractured carbonate reservoirs. Journal of Petroleum Science and Engineering, 186, 106685.
  6. Mukhametshin, V. Sh. (1989). Dependence of crude-oil recovery on the well spacing density during development of low-producing carbonate deposits, Oil Industry, 12, 26–29.
  7. Rogachev, M. K., Mukhametshin, V. V., Kuleshova, L.S. (2019). Improving the efficiency of using resource base of liquid hydrocarbons in Jurassic deposits of Western Siberia. Journal of Mining Institute, 240, 711-715.
  8. Zeigman, Yu. V., Mukhametshin, V. V., Kuleshova, L. S. (2020). Differential impact on wellbore zone based on hydrochloric-acid simulation. IOP Conference Series: Materials Science and Engineering, 952, 012069, 1–6.
  9. Singh, A., Ansari, K. R., Quraishi, M. A., et al. (2018). Synthesis and investigation of pyran derivatives as acidizing corrosion inhibitors for N80 steel in hydrochloric acid: Theoretical and experimental approaches. Journal of Alloys and Compounds, 762, 347-362.
  10. 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.
  11. Rubing, H., Changbing, T., Shunming, L., Kun, L. (2016). The variance of physical properties of petroleum and the controlling factors in Fula depression, Muglad basin, Sudan. SOCAR Proceedings, 4, 28-40.
  12. Mukhametshin, V. V., Kuleshova, L. S. (2021). Using the method of canonical discriminant functions for a qualitative assessment of the response degree of producing wells to water injection during the development of carbonate deposits. IOP Conference Series: Materials Science and Engineering, 1064, 012069, 1-9.
  13. Feng, R., Chen, Sh., Bryant, St., Liu, J. (2019). Stress-dependent permeability measurement techniques for unconventional gas reservoirs: Review, evaluation, and application. Fuel, 256, 115987.
  14. 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.
  15. 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.
  16. Shen, R., Lei, X., Guo, H.K., et al. (2017). The influence of pore structure on water flow in rocks from the Beibu Gulf oil field in China. SOCAR Proceedings, 3, 32-38.
  17. Gilaev, Gen. G., Khabibullin, M. Ya., Gilaev, G. G. (2020). Basic aspects of using acid gel for propant injection during fracturing works in carbonate reservoirs in the Volga-Ural region. SOCAR Proceedings, 4, 33-41.
  18. Sergeev, V. V., Sharapov, R. R., Kudymov, A. Y., et al. (2020). Experimental research of the colloidal systems with nanoparticles influence on filtration characteristics of hydraulic fractures. Nanotehnologies in Construction, 12(2), 100–107. 75 L.S.Kuleshova et al. / SOCAR Proceedings Special Issue No. 1 (2021) 068-07
  19. Shaken, M. Sh. (2020). Problems and methods of hydraulic fracturing in multilayered oil reservoirs with the continuous perforation. SOCAR Proceedings, 3, 66-73.
  20. Kulakov, P. A., Kutlubulatov, A. A., Afanasenko, V. G. (2018). Forecasting of the hydraulic fracturing efficiency as components of its design optimization. SOCAR Proceedings, 2, 41-48.
  21. Kalia, N., Balakotaiah, V. (2009). Effect of medium heterogeneities on reactive dissolution of carbonates. Chemical Engineering Science, 64(2), 376-390.
  22. Qiua, X., Aidagulova, G., Ghommem, M., et al. (2018). Towards a better understanding of wormhole propagation in carbonate rocks: Linear vs. radial acid injection. Journal of Petroleum Science and Engineering, 171, 570-583.
  23. 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.
  24. Jia, C., Huang, Z., Sepehrnoori, K., Yao, J. (2021). Modification of two-scale continuum model and numerical studies for carbonate matrix acidizing. Journal of Petroleum Science and Engineering, 197, 107972.
  25. Nurgaliev, R. Z., Kozikhin, R. A., Fattakhov, I. G., Kuleshova, L. S. (2019). Application prospects for new technologies in geological and technological risk assessment. Mining Journal, 4 (2261), 36–40.
  26. Stoupakova, A. V., Kalmykov, G. A., Korobova, N. I., et al. (2017). Oil-Domanic deposits of the Volga-Ural basin – types of section, formation conditions and prospects of oil and gas potential. Georesources, Special Issue, Part 1, 112-124.
  27. Iskandarov, G., Gabdrakhmanov, A. T. (2016). Domanik-this is the tomorrow of Tatarstan. West Siberian Oil and Gas Congress. Innovative technologies in the oil and gas industry: a collection of scientific papers of the X International Scientific and Technical Congress of the Student Branch of the Society of Petroleum EngineersSociety of Petroleum Engineers (SPE). Tyumen: Tyumen Industrial University.
  28. 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.
  29. Rabaev, R. U., Bakhtizin, R. N., Sultanov, S. Kh., et al. (2020). Substantiation of application of the technology of acid hydraulic facing insea shelfgas condensate carbonate reservoirs. SOCAR Proceedings, 4, 60-67.
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DOI: 10.5510/OGP2021SI100511

E-mail: markl212@mail.ru


I.N. Khakimzyanov1,2, V.Sh. Mukhametshin2, R.N. Bakhtizin2, A.V. Lifantyev1, R.I. Sheshdirov1

1«TatNIPIneft» PJSC «Tatneft» named after V.D.Shashin, Bugulma, Russia; 2Ufa State Petroleum Technological University, Ufa, Russia

Justification of necessity to consider well interference in the process of well pattern widening in the Bavlinskoye oil field pashiyan formation


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.

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.

References

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  2. Muslimov, R. Kh. (2016). A new strategy for the development of oil fields in modern Russia is to optimize production and maximize KIN. Oil. Gas. Novation’s, 4, 8-17.
  3. Mukhametshin, V. V. (2020). Oil production facilities management improving using the analogy method. SOCAR Proceedings, 4, 42-50.
  4. Economides, J. M., Nolte, K. I. (2000). Reservoir stimulation. West Sussex, England: John Wiley and Sons.
  5. Pirverdyan, A. M. (1954). Displacement of oil by water from a porous medium. Proceedings AzNII for oil production. Issue 1. Baku: Aznefteizdat.
  6. 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.
  7. Dmitrievsky, A. N., Eremin, N. A. (2015). Modern scientific and technological revolution and a paradigm shift in the development of hydrocarbon resources. Problems of Economics Project: Digital Fields and Wells, 6, 10-16.
  8. Rogachev, M. K., Mukhametshin, V. V., Kuleshova, L. S. (2019). Improving the efficiency of using resource base of liquid hydrocarbons in Jurassic deposits of Western Siberia. Journal of Mining Institute, 240, 711-715.
  9. 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.
  10. Ivanova, M. M., Dementyev, L. F., Cholovsky, I. P. (2014). Oil and gas field geology and geological bases of oil and gas field development. Moscow: Alliance.
  11. Banerjee, S. (2020). Understanding well interference and parent-child well relationships with liquid molecular chemical tracer technology. SPE Journal of Petroleum Technology, 72 (07), 45–47.
  12. Igba, S., Akanji, L. T., Onwuliri, T. (2018). Horizontal versus vertical wells interference in hydraulically fractured shale reservoirs. Journal of Oil, Gas and Petrochemical Sciences, 2(2), 56-68.
  13. Alvarado, V., Thyne, G., Murrell, G. R. (2008, September). Screening Strategy for Chemical Enhanced Oil Recovery in Wyoming Basin. SPE-115940-MS. In SPE: Annual Technical Conference and Exhibition.
  14. 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.
  15. Shaohua, G., Zhihong, N., Xinbin, Y., et al. (2020). Study on the interference law of staged fracturing crack propagation in horizontal wells of tight reservoirs. ACS Omega, 5, 10327−10338.
  16. Redutskiy, Yu. V. (2011). Consideration of oil well interference when solving control problems for well operating regimes. Oil and Gas Territory, 5, 16-20.
  17. Mukhametshin, V. V. (2017). Eliminating uncertainties in solving bottom hole zone stimulation tasks. Bulletin of the TPU. Geo Assets Engineering, 328(7), 40–50.
  18. Qin, J., Cheng, S., Li, P., et al. (2019). Interference well-test model for vertical well with double-segment fracture in a multi-well system. Journal of Petroleum Science and Engineering, 183, 106412.
  19. Mukhametshin, V. V. (2018). Rationale for trends in increasing oil reserves depletion in Western Siberia cretaceous deposits based on targets identification. Bulletin of the TPU. Geo Assets Engineering, 329(5), 117–124.
  20. Alvarado, V., Reich, E.-M., Yunfeng, Yi., Potsch, K. (2006, June). Integration of a risk management tool and an analytical simulator for assisted decision-making in IOR. SPE-100217-MS. In: SPE Europec/EAGE Annual Conference and Exhibition (Vienna, Austria, 12-15 June 2006). Society of Petroleum Engineers.
  21. 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.
  22. Weijermars, R., van Harmelen, A., Zuo, L., et al. (2018). Flow interference between hydraulic fractures. SPE Reservoir Evaluation and Engineering, 21, 942–960.
  23. 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.
  24. Zatsarina, L. V., Khakimzyanov, I. N., Kemaeva, U. P., et al. (2017). Aspects of tournaisian reservoir development in Korobkovsky area of Bavlinskoye oilfield. Oil Industry, 1, 40-43.
  25. Mukhametshin, V. V., Kuleshova, L. S. (2019). Justification of low-productive oil deposits flooding systems in the conditions of limited information amount. SOCAR Procеedings, 2, 16–22.
  26. Guofeng, H., Yuewu, L., Wenchao, L., Dapeng, G. (2019). Investigation on interference test for wells connected by a large fracture. Applied Sciences, 9, 206.
  27. Mukhametshin, V. V., Andreev, V. E., Dubinsky, G. S., et al. (2016). The usage of principles of system geological-technological forecasting in the justification of the recovery methods. SOCAR Proceedings, 3, 46–51.
  28. Khakimzyanov, I. N., Khisamov, R. S., Bakirov, I. M., et al. (2014). Issues of optimization and improvement of the efficiency of operation of wells with horizontal termination on the basis of mathematical modeling of fields in Tatarstan. Kazan: FEN.
  29. Kerimov, N. S., Huseynova, D. F., Yusifova, Sh. F. (2013). Estimation of the initial recoverable reserves of the top chalk horizon of «Muradkhanli» oilfield using modeling methods. SOCAR Proceedings, 2, 56-59.
  30. 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.
  31. Zeigman, Yu. V., Mukhametshin, V. V., Kuleshova, L. S. (2020). Management of flooding of low-production deposits according to geological and field data. IOP: Earth and Environmental Science, 579, 012019, 1–6.
  32. Kuliyev, А. М., Jamalbekov, M. A. (2017). The prediction of the development indicators of creeping reservoirs of light oils. SOCAR Proceedings, 3, 51-57.
  33. Zeigman, Yu. V., Mukhametshin, V. Sh., Khafizov, A. R., Kharina, S. B. (2016). Prospects of Application of Multi-Functional Well Killing Fluids in Carbonate Reservoirs. SOCAR Procеedings, 3, 33–39.
  34. Xiao, C., Dai, Y., Tian, L., et al. (2018). A semianalytical methodology for pressure-transient analysis of multiwall-pad-production scheme in shale gas reservoirs, part 1: New insights into flow regimes and multiwall interference. SPE Journal, 23, 1–21.
  35. Yartiev, A. F., Khakimzyanov, I. N., Petrov, V. N., Idiyatullina, Z. S. (2016). Improving technologies for the development of oil reserves from heterogeneous and complex reservoirs of the Republic of Tatarstan: monograph. Kazan: Ikhlas.
  36. Khisamov, R. S., Ganiev, G. G., Khannanov, R. G., et al. (2006). Scientific and practical significance of the discovery and development of the Bavlinskoye oil field. Georesursy, 3(20), 8-10.
  37. Muslimov, R. Kh. (2006). The outstanding role of the Bavlinskoye oil field in the formation of hightech production of productive layers. Georesources, 3 (20), 3-7.
  38. Chemodanov, V. S., Sultanov, S. A., Poluyan, I. G., Zinatullina, A. M. (1965). Changes in the oil recovery of the flooded part of the D1 formation of the Bavlinskoye field during an industrial experiment. Proceedings of the TatNII, Vol. VIII. Moscow: Nedra.
  39. Khisamov, R. S., Ibatullin, R. R., Khakimzyanov, I. N., Kiyamova, D.. (2013). Search for alternatives to improve the efficiency of wells operation with horizontal end at Korobkovsky and Bavlinsky fields using geotechnical model. Georesources, 4(54), 2-9.
  40. 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.
  41. Hammadeev, F. M., Sultanov, S. A., Poluyan, I. G. (1975). Experimental development of the D1 formation. Rarefaction of the grid by stopping half of the operational fund of wells. Kazan: Tatknigoizdat.
  42. Sazonov, B. F. (1973). Improving the technology of oil field development under water-pressure conditions. Moscow: Nedra.
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DOI: 10.5510/OGP2021SI100512

E-mail: ilgizar@nayka.su


V.Sh. Mukhametshin1, I.N. Khakimzyanov1,2, R.N. Bakhtizin1, L.S. Kuleshova1

1Ufa State Petroleum Technological University, Ufa, Russia; 2«TatNIPIneft» PJSC «Tatneft» named after V.D.Shashin, Bugulma, Russia

Differentiation and grouping of complex-structured oil reservoirs in carbonate reservoirs in development management problems solving


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.

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.

References

  1. Muslimov, R. Kh. (2005). Modern methods of oil recovery increasing: design, optimization and performance evaluation. Kazan: FEN.
  2. 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. Georesources, 21(3), 55-61.
  3. Kerimov, N. S., Huseynova, D. F., Yusifova, Sh. F. (2013). Estimation of the initial recoverable reserves of the top chalk horizon of «Muradkhanli» oilfield using modeling methods. SOCAR Proceedings, 2, 56-59.
  4. Mukhametshin, V. Sh. (2020). Rationale for the production of hard-to-recover deposits in carbonate reservoirs. IOP: Earth and Environmental Science (EES) (International Symposium «Earth sciences: history, contemporary issues and prospects»), 579(1), 1-5.
  5. Economides, J. M., Nolte, K. I. (2000). Reservoir stimulation. West Sussex, England: John Wiley and Sons.
  6. Beaudette-Hodsman, C., MacLeod, B., Venkatadri, R. (2008, October). Production of high quality water for oil sands application. SPE-117840-MS. In: International Thermal Operations and Heavy Oil Symposium. Society of Petroleum Engineers.
  7. Yakupov, R. F., Mukhametshin, V. Sh., Tyncherov, K. T. (2018). Filtration model of oil coning in a bottom water-drive reservoir. Periodico Tche Quimica, 15(30), 725-733.
  8. Alvarado, V., Thyne, G., Murrell, 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.
  9. Mukhametshin, V. V., Kuleshova, L. S. (2019). Justification of low-productive oil deposits flooding systems in the conditions of limited information amount. SOCAR Procеedings, 2, 16-22
  10. Dmitrievsky, A .N. (2017). Resource-innovative strategy for the development of the Russian economy. Oil Industry, 5, 6-7.
  11. Zeigman, Yu. V., Mukhametshin, V. Sh., Khafizov, A. R., Kharina, S. B. (2016). Prospects of application of multifunctional well killing fluids in carbonate reservoirs. SOCAR Procеedings, 3, 33–39.
  12. Rogachev, M. K., Mukhametshin, V. V., Kuleshova, L. S. (2019). Improving the efficiency of using resource base of liquid hydrocarbons in Jurassic deposits of Western Siberia. Journal of Mining Institute, 240, 711-715.
  13. Ramazanzade, E.N. (2010). Revealing of potential resources and efficient development of Absheron polybedal fields, being at the late stage operation. SOCAR Proceedings, 1, 24-28.
  14. Alvarado, V., Stirpe, M., La Roque, C., et al. (2002). Streamline simulation for enhanced-oil recovery: review and laboratory tests. Proceedings of INGEPET, EXPL-4- VA-84. Lima.
  15. 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 Tomsk Polytechnic University. Geo Assets Engineering, 329(8), 30-36.
  16. Mukhametshin, V. V. (2020). Oil production facilities management improving using the analogy method. SOCAR Proceedings, 4, 42-50.
  17. Mirzadzhanzade, A. Kh., Khasanov, M. M., Bakhtizin, R. N. (2004). Modeling of oil and gas production processes. Nonlinearity, nonequilibrium, uncertainty. Moscow-Izhevsk: Institute of Computer Research.
  18. 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.
  19. Khasanov, M. M., Mukhamedshin, R. K., Khatmullin, I. F. (2001). Computer technologies for solving multi-criteria tasks of monitoring the development of oil fields. Bulletin of the YUKOS Engineering center, 2, 26-29.
  20. Kudryashov, S. I., Khasanov, M. M., Krasnov, V. A., et al. (2007). Technologies application patterns - an effective way of knowledge systematization. Oil Industry, 11, 7-9.
  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.
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DOI: 10.5510/OGP2021SI100513

E-mail: vsh@of.ugntu.ru


G.G. Ismayilov1, F.B. Ismayilova1, S.F. Musaev2

1Azerbaijan State Oil and Industrial University, Baku, Azerbaijan; 2British Petroleum (ВР), United Kingdom

Forecasting the viscosity properties of water-oil systems


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.

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.
  2. Evdokimov, I.N., Losev, A.P. The problem of inversion in oil-field petroleum emulsions. Bureniye i Neft, 3, 16-17.
  3. Gumbatov, G. G. (1996). Izuchenie processa sbora, transporta i podgotovki neftej v usloviyah morskih mestorozhdenij Azerbajdzhana. Baku: Elm.
  4. Evdokimov, I. N., Losev, A. P., Fesan, A. A. (2013). Otsutstvie additivnosti neftyanyh smesej. «Novye tekhnologii v neftegazodobyche». Baku.
  5. Ismayilov, Q. Q., Safarov, N. M., Kelova, I. N. New approach to rheological and structural properties of water – oil emulsions. Herald of the Azerbaijan Engineering Academy, 3(2), 81-94.
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DOI: 10.5510/OGP2021SI100514

E-mail: musasf@bp.com


R.R. Khuzin1, R.N. Bakhtizin2, V.E. Andreev2, L.S. Kuleshova2, V.V. Mukhametshin2, Sh.Kh. Sultanov2

1LLC «Karbon-Oil», Almetyevsk, Russia; 2Ufa State Petroleum Technological University, Ufa, Russia

Oil recovery enhancement by reservoir hydraulic compression technique employment


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.

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.
  4. Economides, J. M., Nolte, K. I. (2000). Reservoir stimulation. West Sussex, England: John Wiley and Sons.
  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.
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DOI: 10.5510/OGP2021SI100522

E-mail: vv@of.ugntu.ru


S.R. Alimbekov1, F.G. Ishmuratov1, V.V. Nosov2, A.I. Voloshin2, R.I. Alimbekov1, S.S. Zlotsky3, V.A. Dokichev1

1Ufa State Aviation Technical University, Ufa, Russia; 2RN-BashNIPIneft LLC, Ufa, Russia; 3Ufa State Petroleum Technological University, Ufa, Russia

Influence of the electromagnetic field on the corrosion of low-carbon steel in aqueous mineralized media and on the crystallization of calcium carbonate in the presence of iron(II) ions


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 CaCOfrom 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.

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 CaCOfrom 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

  1. Voloshin, A. I., Gusakov, V. N., Fakhreeva, A. V., Dokichev, V. A. (2018). Scaling prevention inhibitors in oil production. Oilfield engineering, 11, 60-72.
  2. Crabtree, M., Eslinger, D., Fletcher, P., et al. (1999). Fighting scale: removal and prevention. Oilfield Review, 11(3), 30–45.
  3. Kashchavtsev, V. E., Mishchenko, I. T. (2004). Scale formation in oil production. Moscow: Orbita-M.
  4. Brikov, A. V., Markin, A. N. (2018). Oilfield chemistry: A practical guide to combating salt formation. Moscow: De'libri.
  5. Sharipov, S. Sh., Akshentsev, V. G., Shulakov, A. S., et al. (2015). Electromagnetic emitter, device and method for inhibiting the formation of deposits and corrosion of borehole equipment. RU Patent 2570870.
  6. Alimbekova, S. R., Alimbekov, R. I., Grekov, S. N., et al. (2016). The first experience of using the RVC-1 resonant-wave complex to combat salt deposition in wells equipped with electric centrifugal pumps. Problems of collection, preparation and transport of oil and petroleum products, 106(4), 85-92.
  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.
  8. Alimbekova, S. R., Bakhtizin, R. N., Voloshin, A. I., Dokichev, V. A. (2019). Physical methods for preventing salt deposition in oil production. Oil and Gas Business, 6, 31-38.
  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.
  10. Cho, Y. I., Kim, H.-S. (2015). Nonchemical methods to control scale and deposit formation. Mineral Scales and Deposits. 9, 193-221.
  11. Chibowski, E., Hołysz, L., Terpiłowski, K. (2003). Effect of magnetic field on deposition and adhesion of calcium carbonate particles on different substrates. Journal of Adhesion Science and Technology, 17(15), 2005-2021.
  12. Hua, Y., Xu, S., Wang, Y., et al. (2019). The formation of FeCO3 and Fe3O4 on carbon steel and their protective capabilities against CO2 corrosion at elevated temperature and pressure. Corrosion Science, 157, 392–405.
  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.
  22. Alimi, F., Tlili, M., Ben, A. M., et al. (2009). Influence of magnetic field on calcium carbonate precipitation in the presence of foreign ions. Surface. Engineering and Applied Electrochemistry, 45(1), 56-62.
  23. Wagterveld, R. M., Miedema, H., Yu., M., Witkamp, G. J. (2014). Polymorphic change from vaterite to aragonite under influence of sulfate: The “morning star” habit. Journal of Crystal Growth, 387, 29-35.
  24. Di Lorenzo, F., Burgos-Cara, A., Ruiz-Agudo, E., et al. (2017). Effect of ferrous iron on the nucleation and growth of CaCO3 in slightly basic aqueous solutions. CrystEngComm, 19(3), 447-460.
  25. Schlomach, J., Quarch, K., Kind, M. (2006). Investigation of precipitation of calcium carbonate at high supersaturations. Chemical Engineering & Technology, 29, 215–220.
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DOI: 10.5510/OGP2021SI100515

E-mail: voloshinai3@mail.ru


P.A. Khlyupin1, R.T. Khazieva1, A. Vahedi2

1Ufa State Petroleum Technological University, Ufa, Russia; 2Electrical Engineering Department, Iran University of Science and Technology, Tehran, Iran

Development of new electrical technological systems and complex in the production of hard-to-remove oil reserves


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.

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

  1. Brilev, C. (2011). Tyazhelaya neft'. http://vseonefti.ru/ neft/tyazhelaya-neft.html
  2. Korshak, A. A., Nechval', A. M. (2005). Truboprovodnyj transport nefti, nefteproduktov i gaza. Ufa: DPServis.
  3. Maksutov, R., Orlov, G., Osipov, A. (2006). Osvoenie zapasov vysokovyazkih neftej v Rossii. http://www.oilcapital. ru/technologies/2006/01/101226_82677.shtml
  4. Zhakisheva, A. A. (2012). Ways of rational use of hydrocarbonic resourcesto oil-extracting regions. Fundamental research, 2012, 6, 218-223.
  5. Polishchuk, YU. M., YAshchenko, I. G. (2005). Vysokovyazkie nefti: analiz prostranstvennyh i vremennyh izmenenij fiziko-himicheskih svojstv. Neftegazovoe delo, 1. http://www.ogbus.ru/authors/PolishukYu/PolishukYu_1.pdf
  6. Salimov, M. Obrazovanie organicheskih otlozhenij. http://msalimov.narod.ru/Aspo.html
  7. Musavirova, G. A., Mukhametova, E. M. (2005). Research into impact of thermal effect and cooling rate on paraffining process. Environment Protection in Oil and Gas Complex, 6, 50-52.
  8. Gafarov, Sh. A. (2006). Povyshenie effektivnosti razrabotki mestorozhdenij s anomal'no-vyazkimi neftyami v karbonatnyh otlozheniyah. Avtoreferat dissertacii na soiskanie uchenoj stepeni doktora tekhnicheskih nauk. Ufa: UGNTU.
  9. Shakhmelikyan, M. G., Nwizug-bee, L. K. (2018). Analysis of the application of technology of the steam cyclic method of intensification of viscous and highly viscous oils production. Otraslevye nauchnye i prikladnye issledovaniya: Nauki o zemle. http://www.id-yug.com/images/ id-yug/SET/2018/4/2018-4-217-242.pdf.
  10. Nagrev podvodnyh truboprovodov. Aker Solution. http://intsok.com/style/downloads/Aker%20S_PDF_015.%20 Aker%20Solutions-.pdf
  11. Arzamasov, V.L. (2013). Razrabotka i issledovanie preobrazovatelej chastoty dlya ustanovok elektronagreva nefteskvazhin. Avtoreferat dissertacii na soiskanie uchenoj stepeni kandidata tekhnicheskih nauk. Cheboksary.
  12. Heat Management Solutions for Upstream Sector / Tyco Thermal Controls. http://www.petroleumclub.ro/ downloads/ROupstream/Valentin%20Ilie.pdf.
  13. Teplolyuks-servis. Samoreguliruyushchayasya nagrevatel'naya lenta FSU/FSU. http://www.promobogrev.ru/katalog-produkcii/nagrevatelnye-kabeli / samoregulirujushhijjsja-kabel/samoreg-kabel-fsu.html.
  14. Fonarev, Z. I. (1984). Elektropodogrev truboprovodov, rezervuarov i tekhnologicheskogo oborudovaniya v neftyanoj promyshlennosti. Leningrad: Nedra.
  15. Chistyakov, S. I. (1973). O primenenii elektromagnitnogo polya dlya intensifikacii dobychi vysokovyazkih neftej. Avtoreferat dissertacii na soiskanie uchenoj stepeni kandidata tekhnicheskih nauk. Ufa: UGNTU.
  16. Badamshin, R. A., Mel'nikov, V. I. (2004). Opytnoe skvazhinnoe oborudovanie dlya obrabotki prizabojnoj zony plasta i likvidacii otlozhenij po vsej glubine ih obrazovaniya. Sovremennye naukoemkie tekhnologii, 2004, 5, 35-38.
  17. Sluhockij, A. E., Ryskin, S. E., (1974). Induktory dlya indukcionnogo nagreva. Leningrad: Energiya.
  18. Zavod indukcionnyh elektricheskih nagrevatelej «ZIEN». http://www.zien.ru
  19. ZAO «Zavod sibirskogo tekhnologicheskogo mashinostroeniya «SIBTEKHNOMASH». www.zstm.ru
  20. Danilushkin, A. I., Danilushkin, V. A., Krivoscheev, V. E., Maksimova, M. A. (2020). Electrotechnical modular complex for heating viscous liquids in pipeline transport facilities. Urban construction and architecture, 10(2) (39), 160-167.
  21. Danilushkin, A. I, Danilushkin, V. A., Maximova, M. A., Surkov, D. V. (2019). Development and research of a three-phase induction device for heating and mixing liquids. Vestnik of Samara State Technical University (Technical Sciences Series), 3(63), 120–132.
  22. Konesev, S. G., Khlyupin, P. A. (2019). Prospects for the use of electro-technological heating systems in the arctic conditions. Power and Autonomous Equipment, 2(2), 86-101.
  23. Konesev, S. G., Khlyupin, P. A., Greb, A. V., Kondratiev, E. Yu. (2018). Induction technology in highviscosity oil production at Tazovskoye field. Periodico Tche Quimica, 15(30), 520-526.
  24. Belousov, V. D. (1988). Truboprovodnyj transport nefti i gaza. Moskva: Nedra.
  25. Konesev, S. G., Alekseev, V. J., Khljupin, P. A. (2008). Electrohydroimpulsive downhole device. RU Patent 2337237.
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DOI: 10.5510/OGP2021SI100516

E-mail: khlupinpa@mail.ru


A.R. Khafizov, V.V. Chebotarev, A.A. Mugatabarova

Ufa State Aviation Technical University, Ufa, Russia

Estimation of corrosion aggression of aquatic media and corrosion resistance of steels of equipment of oil and gas condensate deposits


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.

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

  1. Polnikov, V. V., Khafizov, A. R., Chebotarev, V. V., Mugatabarova, A. A. (2019). Assessment of the effect of the composition of the produced media and operating conditions on the corrosion of gas production equipment. Problems of Collection, Preparation and Transportation of Oil and Oil Products, 1, 81-94.
  2. Pavlyuchenko, V. I., Chebotarev, V. V., Mugatabarova, A. A. (2018). Investigation of the properties of chemical reagents that increase the efficiency of corrosion inhibitors in gravity water conduits. Oilfield business, 3, 62-67.
  3. GOST R 9.905-2007. (2020). Unified system of protection against corrosion and aging. Corrosion test methods. General requirements. Moscow: Standartinform RF.
  4. GOST R 9.502-82. (1983). Unified system of protection against corrosion and aging. Metal corrosion inhibitors for water systems. Corrosion test methods. Moscow: Standartinform RF.
  5. GHOST 9.908-85. (2021). Metals and alloys. Methods for determination of indicators of corrosion and corrosion resistance. Moscow: Standartinform RF.
  6. Khaidarova, G. R., Tyusenkov, A. S., Bugay, D. E., et al. (2018). Development and testing of properties of corrosion inhibitors based on quaternary ammonium compounds. Izvestiya Universities. Chemistry and Chemistry Technology, 61( 7), 130-136.
  7. Ponomarev, A. I., Sitdikov, R. F., Ibatulin, A. A., et al. (2019). Complex solutions to improve the efficiency of development of multilayer gas and gas condensate fields. Bulletin of the TPU. Engineering of georesources, 330(12), 44-53.
  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
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DOI: 10.5510/OGP2021SI100517

E-mail: hafizov57@mail.ru


G.G. Ismayilov1, R.A. Ismailov1, F.N. Аhmadzada2

1Azerbaijan State Oil and İndustry University, Baku, Azerbaijan; 2«OilGasScientificResearchProject» institute, SOCAR, Baku, Azerbaijan

Diagnosing of the presence of liquid inclusions in the gas pipelines


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.

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

  1. Mirzadzhanzade, A. Kh. (1970). On the motion of two-phase systems in a porous medium taking account of heat- and mass transport processes. Journal of Engineering Physics and Thermophysics, 18(6), 702-706.
  2. Entov, V. M., Mirzadzhanzade, A. Kh., Mishevich, V. I. (1971). Curvature of oil well indicator charts in fractured porous reservoirs. Journal of Applied Mechanics and Technical Physics, 12(4), 566-570.
  3. Bolotov, A. A., Mirzadzhanzade, A. Kh., Nesterov, I. I. (1988). Reologicheskie svojstva rastvorov gazov v zhidkosti v oblasti davleniya nasyshcheniya. Izvestiya AN SSSR. Mekhanika zhidkosti i gaza, 1, 172-175.
  4. Sattarov, R. M. (1981). Diagnostirovanie reologicheskih svojstv vyazko-uprugoplastichnyh sred pri ih dvizhenii v trubah. Inzhenerno-fizicheskij zhurnal, 41(6), 1016-1026.
  5. Frenkel, Ya. I. (1975). Kinetic theory of liquids. Moscow: Nauka.
  6. Ismajylov, G. G., Ismajlov, R. A., Sejfullaev, G. H. (2016, fevral). Diagnostirovanie strukturnyh izmenenij v potokah kondensiruyushchih gazov na osnove fraktal'nogo analiza. Materialy mezhdunarodnogo seminara Rassohinskie chteniya. Chast 2. Uhta: UGTU.
  7. Hodanovich, I. E., Tempel', F. G. (1959). Modelirovanie nestacionarnyh processov dvizheniya gaza v magistral'nom truboprovode. Gazovaya promyshlennost', 6.
  8. Charnyj, I. A. (1975). Neustanovivsheesya dvizhenie real'noj zhidkosti v trubah. Moskva: Nedra.
  9. Seleznev, V. E., Aleshin, V. V., Pryalov, S. N. (2009). Osnovy chislennogo modelirovaniya magistral'nyh truboprovodov. Moskva: MAKS Press.
  10. Herran-Gonzalez, A., De La Kruz, J. M., De AndresToro, B., Risco-Martin, J. L. (2009). Modelling and simulation of a gas distribution pipeline network. Applied Mathematical Modelling, 33, 1584-1600.
  11. Ismayilov, R. A. (2017). Study of nonequilibrium properties of natural gases. Oil and Gas Business, 15(3), 85-90.
  12. Ismailov, R. A. (2004). Influence of viscoelastik properties of pipes material on transmission of waves of pressure disturbance at movement of non-equilibrium gases. ANAS Transactions. Series of Physical-Technical & Mathematical Sciences, XXIV(1), 223-226.
  13. Sattarov, R. M., Ismajlov, R. A. (2001). Nekotorye voprosy mekhaniki neravnovesnyh gazov pri dvizhenii v uprugovyazkih trubah. Mekhanika i mashinostroenie, 1, 12-14.
  14. Ismailov, R. A. (2008). Analysis of relaxation processes on movement of non-equilibrium gases in the pipeline systems. Azerbaijan Oil Industry, 8, 47-49.
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DOI: 10.5510/OGP2021SI100518

E-mail: ramismaylov@mail.ru


P.A. Revel-Muroz, R.N. Bakhtizin, R.M. Karimov, B.N. Mastobaev

Ufa State Petroleum Technological University, Ufa, Russia

About the effectiveness of hydrocarbon diluents for pipeline transportation of high viscosity heavy and waxy oil


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.

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

  1. Bakhtizin, R. N., Gallyamov, A. K., Mastobaev, B. N., et al. (2004). Transport and storage of high-viscosity oils and petroleum products. Application of electric heating. Мoscow: Publishing house «Chemistry».
  2. Rebinder, P. A., Babalyan, G. A., Kravchenko, I. I. (1965). The use of surfactants and other chemical reagents in the oil industry. Moscow: Nedra.
  3. Lisin, Yu. V., Mastobaev, B. N., Shammazov, A. M., Movsumzade, E. M. (2012). Chemical agents at pipeline transportation of oil and oil products. Saint Petersburg: Nedra.
  4. Novoselov, V. F., Mastobaev, B. N. (1998). Application of high-molecular additives to improve the efficiency of oil pipelines. Proceedings of the symposium on geochemical and physico-chemical issues of exploration and oil and gas. Vol. III. Hungary: Szolnok.
  5. Novosyolov, V. V., Tugunov, P. I., Zabaznov, A. I., et al. (1991). Joint transportation of high-viscosity oil and gas condensate through the main condensate pipeline Novy Urengoy - Surgut. Overview information. Series «Transport and Underground Storage of Oil and Gas». Moscow: VNIIEGAZPROM.
  6. Babalyan, G. A. (1965). Struggle with paraffin deposits. Moscow: Nedra.
  7. Babalyan, G. A. (1974). Physicochemical processes in oil production. Moscow: Nedra.
  8. (1981). New oil of Kazakhstan and their use. The Oil of Mangyshlak. Alma-Ata: Science.
  9. Tronov, V. P. (1970). Mechanism of formation of tarparaffin deposits and their control. Moscow: Nedra.
  10. Ty Tkharn Ngia, Bakhtizin, R. N., Veliev, M. M., et sl. (2015). Transportation and storage of heavy oil. Saint Petersburg: Nedra.
  11. Karimov, R. M., Mastobaev, B. N. (2011). Rheological features of the West Kazakhstan oil blend. Transport and Storage of Oil Products and Hydrocarbons, 2, 3-7.
  12. Karimov, R. M, Mastobaev, B. N. (2012). Joint transportation of high viscosity and pour point oil of Western Kazakhstan through the «Uzen-Atyrau-Samara» pipeline. Transport and Storage of Oil Products and Hydrocarbons, 1, 3-6.
  13. Karimov, R. M, Mastobaev, B. N. (2012). Peculiarities of pipeline transportation of multicomponent oil systems. Azerbaijan Oil Industry, 1, 60-63.
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DOI: 10.5510/OGP2021SI100521

E-mail: karimov_rinat@mail.ru


R.I.Shevchenko1, V.M.Strelets1, V.M.Loboichenko1, A.V.Pruskyi2, O.N.Myroshnyk3, G.V.Kamyshentsev4

1National University of Civil Defence of Ukraine, Kharkiv, Ukraine; 2Institute of Public Administration and Research in Civil Protection, Kyiv, Ukraine; 3ChIFS named after the Heroes of Chernobyl, Cherkasy, Ukraine; 4ASBGS of Ukraine, Kyiv, Ukraine

Review of up-to-date approaches for extinguishing oil and petroleum products


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.

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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DOI: 10.5510/OGP2021SI100519

E-mail: vloboichm@gmail.com


R.N. Bahtizin1, S.N. Zubin1, A.B. Laptev2, D.A. Laptev3, D.E. Bugai1, A.V. Golubev1

1Ufa State Petroleum Technological University, Ufa, Russia; 2All-Russian Scientific Research Institute of Aviation Materials, Moscow, Russia; 3Lomonosov Moscow State University, Moscow, Russia

Monitoring of technological environments at petrochemical plants as a means of ensuring their safe operation


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.

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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DOI: 10.5510/OGP2021SI100520

E-mail: debugai@mail.ru