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.

S.A. Punanova

Oil and Gas Research Institute of the Russian Academy of Sciences, Moscow, Russia

On the classification diversity of oil and gas trappers and geochemical criteria for the productivity of shale formations


The article considers the classification attributes of non-anticlinal traps on the basis of analytical research and critical analysis of literary sources. A certain excess of classification definitions and characteristics of traps, used by researchers both to describe universal schemes and for specific oil and gas basins, and their frequent discrepancies reasonably lead ultimately to an enlargement of types and subtypes of traps, combining them into three main classes of accumulations: continuous and quasi-continuous (unconventional) and discontinuous (conventional). It is noted that in combination with geophysical, seismostratigraphic, paleogeographic, paleotectonic, hydrogeological and other methods of studying the genesis and morphology of traps, and their search, geochemical methods of forecasting and searching for hydrocarbon accumulations at all stages of prospecting and exploration are now widely introduced. The practical possibilities of geochemical methods for evaluating the effective productivity of thin traps of carbonaceous formations are shown on the example of the Bazhenov and Domanik deposits of Russia, as well as the shale plays of the Bakken, Eagle and others in the United States.

Keywords: non-anticlinal traps; thin traps; reservoirs; oil and gas; classification of traps; carbonaceous formations; geochemical studies.

The article considers the classification attributes of non-anticlinal traps on the basis of analytical research and critical analysis of literary sources. A certain excess of classification definitions and characteristics of traps, used by researchers both to describe universal schemes and for specific oil and gas basins, and their frequent discrepancies reasonably lead ultimately to an enlargement of types and subtypes of traps, combining them into three main classes of accumulations: continuous and quasi-continuous (unconventional) and discontinuous (conventional). It is noted that in combination with geophysical, seismostratigraphic, paleogeographic, paleotectonic, hydrogeological and other methods of studying the genesis and morphology of traps, and their search, geochemical methods of forecasting and searching for hydrocarbon accumulations at all stages of prospecting and exploration are now widely introduced. The practical possibilities of geochemical methods for evaluating the effective productivity of thin traps of carbonaceous formations are shown on the example of the Bazhenov and Domanik deposits of Russia, as well as the shale plays of the Bakken, Eagle and others in the United States.

Keywords: non-anticlinal traps; thin traps; reservoirs; oil and gas; classification of traps; carbonaceous formations; geochemical studies.

References

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DOI: 10.5510/OGP2021SI200538

E-mail: punanova@mail.ru


E.B. Rile, A.V. Ershov

Oil and Gas Research Institute of the Russian Academy of Sciences, Moscow, Russia

Middle devonian-lower frasnian natural hydrocarbon reservoirs of the Pechora Sea shelf and Timan-Pechora oil and gas province adjacent area


The research is based on the three-layer natural hydrocarbon reservoirs theory, which allocates 3 layers in a natural reservoir – the genuine seal, the productive part and the intermediate layer situated between them - the false seal. The Middle Ordovician-Lower Frasnian terrigenous complex variable in thickness, composition and stratigraphic completeness sub-regional natural reservoir was identified in the northern part of the Timan-Pechora oil and gas province adjacent to the Pechora Sea. It includes several zonal and local natural reservoirs (Middle Ordovician-Lower Devonian, Middle Ordovician-Eiffelian, Zhivetian-Lower Frasnian and others). The distribution areas of these natural reservoirs were extrapolated to the Pechora Sea offshore. The areas with the highest prospects of oil and gas potential of the Pechora Sea offshore were delineated, basing on the Timan-Pechora oil and gas potential analysis. These are the northwest extensions into the Pechora Sea of the Denisov trough, the Kolva megaswell, as well as the Varandei-Adzva structural zone and the Karotaiha depression.

Keywords: natural reservoir; genuine seal; false seal; field; pool; hydrocarbons.

The research is based on the three-layer natural hydrocarbon reservoirs theory, which allocates 3 layers in a natural reservoir – the genuine seal, the productive part and the intermediate layer situated between them - the false seal. The Middle Ordovician-Lower Frasnian terrigenous complex variable in thickness, composition and stratigraphic completeness sub-regional natural reservoir was identified in the northern part of the Timan-Pechora oil and gas province adjacent to the Pechora Sea. It includes several zonal and local natural reservoirs (Middle Ordovician-Lower Devonian, Middle Ordovician-Eiffelian, Zhivetian-Lower Frasnian and others). The distribution areas of these natural reservoirs were extrapolated to the Pechora Sea offshore. The areas with the highest prospects of oil and gas potential of the Pechora Sea offshore were delineated, basing on the Timan-Pechora oil and gas potential analysis. These are the northwest extensions into the Pechora Sea of the Denisov trough, the Kolva megaswell, as well as the Varandei-Adzva structural zone and the Karotaiha depression.

Keywords: natural reservoir; genuine seal; false seal; field; pool; hydrocarbons.

References

  1. Rile, E. B., Ershov, A. V. (2019). Middle ordovician-upper devonian natural reservoirs of the Pechora sea shelf and adjacent Timan-Pechora oil and gas province. Actual Problems of Oil and Gas, 4(27).
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DOI: 10.5510/OGP2021SI200539

E-mail: lenailinka@yandex.ru


I.Ya. Chebotareva

Oil and Gas Research Institute of the Russian Academy of Sciences, Moscow, Russia

Experimental capabilities of seismic emission tomography for solving the problems of searching and exploration of deep hydrocarbon accumulations


The standard seismic prospecting has been designed to investigate thin layering at shallow depths. At depths more than 4 km the rocks are significantly compacted, change their properties and it is often impossible to trace clear horizons by reflected waves. In the crystalline basement and lower horizons of the sedimentary cover the block structure of rocks is clearly manifested. Taking this into account geological models should be developed and other predictive indicators should be used when searching for hydrocarbon accumulations. For the study of great depths more informative seismic methods are emission and transmission tomography which have been developed in detail in seismology. This article discusses prognostic indicators different from seismic prospecting and presents experimental results confirming the success of emission tomography in their detection using the example of field studies at developed hydrocarbon deposit and other geophysical objects. The range of working depths of research covers the entire crust of the Earth including the crust-mantle transition zone.

Keywords: seismic emission; emission tomography; rocks; hydrocarbon deposits.

The standard seismic prospecting has been designed to investigate thin layering at shallow depths. At depths more than 4 km the rocks are significantly compacted, change their properties and it is often impossible to trace clear horizons by reflected waves. In the crystalline basement and lower horizons of the sedimentary cover the block structure of rocks is clearly manifested. Taking this into account geological models should be developed and other predictive indicators should be used when searching for hydrocarbon accumulations. For the study of great depths more informative seismic methods are emission and transmission tomography which have been developed in detail in seismology. This article discusses prognostic indicators different from seismic prospecting and presents experimental results confirming the success of emission tomography in their detection using the example of field studies at developed hydrocarbon deposit and other geophysical objects. The range of working depths of research covers the entire crust of the Earth including the crust-mantle transition zone.

Keywords: seismic emission; emission tomography; rocks; hydrocarbon deposits.

References

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DOI: 10.5510/OGP2021SI200540

E-mail: irinache@inbox.ru


А.P. Shilovsky

Institute of Oil and Gas Problems of the Russian Academy of Sciences, Moscow, Russia

The influence of trap magmatism on the creation of oil and gas deposits


The need to maintain the level of production and an acceptable cost of developing oil and gas fields forces us to rely primarily on the existing reserve, that is, to maximize the potential of traditional oil and gas production regions and adjacent territories - the marginal zones. At the same time, it is necessary to develop unexplored sedimentary complexes at depths of more than 3-5 km. Against this background, it is necessary to highlight a special phenomenon that increases the oil and gas potential of the subsoil associated with trap magmatism. The insufficient level of knowledge of the subsoil makes it possible to predict the discovery of large oil and gas deposits of the traditional type, which will ensure their high profitabilitye.

Keywords: trap magmatism; profitability of oil and gas resources; marginal zones; hornfels; transformation of carbonates; rocks of trap formations; regional seals.

The need to maintain the level of production and an acceptable cost of developing oil and gas fields forces us to rely primarily on the existing reserve, that is, to maximize the potential of traditional oil and gas production regions and adjacent territories - the marginal zones. At the same time, it is necessary to develop unexplored sedimentary complexes at depths of more than 3-5 km. Against this background, it is necessary to highlight a special phenomenon that increases the oil and gas potential of the subsoil associated with trap magmatism. The insufficient level of knowledge of the subsoil makes it possible to predict the discovery of large oil and gas deposits of the traditional type, which will ensure their high profitabilitye.

Keywords: trap magmatism; profitability of oil and gas resources; marginal zones; hornfels; transformation of carbonates; rocks of trap formations; regional seals.

References

  1. (2020). Energeticheskaya strategiya Rossijskoj Federacii na period do 2035 goda. Utverzhdena rasporyazheniem Pravitel'stva Rossijskoj Federacii ot 9 iyunya 2020 g. № 1523-r.
  2. Shilovsky, A. P. (2018). Draft project of the program «revival of the old oil and gas producing regions of Russia». Actual Problems of Oil and Gas, 4(23), 14.
  3. Shilovsky, A. P. (2011). Problems of geophysical data interpretation obtained within the limits of Moscow-Mezen sedimentary basin. Geology, Geophysics and Development of Oil and Gas Fields, 12, 42-48.
  4. Blyuman, B. A. (2011). Zemnaya kora okeanov po materialam mezhdunarodnyh programm glubokovodnogo bureniya v Mirovom okeane. SPb: VSEGEI.
  5. Chersky, N. V., Tsarev, V. P., Soroko, T. I., Kuznetsov, O. L., et al. (1985). Effect of tectonoseismic processes on hydrocarbon generation and accumulation. Novosibirsk: Nauka.
  6. Shilovsky, A. P. (2018). Zones of oil and gas accumulation in the territory of Moscow syneclise and the volumes of geological resources depending on the nature of the endogenic and geodynamic processes. Geology, Geophysics and Development of Oil and Gas Fields, 11, 34-39.
  7. Barenbaum, A. A., Zakirov, S. N., Zakirov, S.,et al. (2015, January). Physical and chemical processes during the carbonated water flooding in the oilfields. SPE-176729-RU. In: SPE Russian Petroleum Technology Conference. Society of Petroleum Engineers.
  8. Shilovsky, A. P. (2016). West Siberian plate: analysis of the structure of intermediate stratigraphic stage. Geology, Geophysics and Development of Oil and Gas Fields, 9, 25-29.
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DOI: 10.5510/OGP2021SI200541

E-mail: ashilovsky08@gmail.com


V.L. Shuster

Oil and Gas Research Institute of the Russian Academy of Sciences, Moscow, Russia

Principal scheme of step-by-step study of non-anticlinal traps of oil and gas (types of work and research methods)


The article scientifically substantiates and systematizes the types of work and research methods to identify and search for hydrocarbon accumulations associated with non-anticlinal traps, consistently at all stages of geological exploration. The tasks and criteria for forecasting and identifying non-anticlinal traps at each stage of geological exploration are formulated. New research methods are proposed.

Keywords: oil; gas; non-anticlinal traps; study scheme; types of work; research methods; forecast criteria; stages of geological exploration.

The article scientifically substantiates and systematizes the types of work and research methods to identify and search for hydrocarbon accumulations associated with non-anticlinal traps, consistently at all stages of geological exploration. The tasks and criteria for forecasting and identifying non-anticlinal traps at each stage of geological exploration are formulated. New research methods are proposed.

Keywords: oil; gas; non-anticlinal traps; study scheme; types of work; research methods; forecast criteria; stages of geological exploration.

References

  1. Aleksin, A. G., Gogonenkov, G. N., Khromov, V. T., et al. (1992). The methodology for the search for oil and gas deposits in traps of complex screened type. Moscow: VNIIOENG.
  2. Varlamov, A. I., Shimansky, V. V., Taninskaya, N. V., et al. (2019). Search and prospects of discovery of non-structural hydrocarbon traps in major petroleum provinces of Russia. Oil and Gas Geology, 3, 9–22.
  3. Shimansky, V. V., Taninskaya, N. V.,  Raevskaya, E.G. (2019). Identification of combination traps in jurassic and lower cretaceous series of western siberia based on paleogeography reconstructions. Oil and Gas Geology, 3, 39–46.
  4. Schuster, V. L., Dziublo, A. D., Shnip, O. A. (2020). Hydrocarbon deposits in non-anticlinal traps of the yamal peninsula of Western Siberia. Georesursy, 1, 39-45.
  5. Dolson, J., He, Zh., Horn, B. W. (2018). Advances and perspectives on stratigraphic trap exploration-making the subtle trap obvious. search and discovery. http://www.searchanddiscovery.com/pdfz/documents/2018/ 60054dolson/ndx_dolson.pdf.html
  6. Halbouly, M. T. (1973). Geologyof giant oil and gas fields. Moscow: Mir.
  7. Guseinov, A. A., Geiman, B. M., Shik, N. S., Surtsukov, G. V. (1988). Methods of forecasting and prospecting for lithological, stratigraphic and combined oil and gas traps. Moscow: Nedra.
  8. Shuster, V. L. (2020). Methodical approach to forecasting zones in oil and gas bearing basins favorable for the formation of non-anticlinal traps. Actual Problems of Oil and Gas, 2(29), 64-71.
  9. Shuster, V. L. (2020). Prognoz i poiski neftegazovyh skoplenij v neantiklinal'nyh lovushkah-vazhnyj element novoj strategii razvitiya neftegazovoj geologii. Materialy mezhdunarodnoj nauchno-prakticheskoj konferencii «O novoj paradigme razvitiya neftegazovoj geologii». Kazan': IHLAS.
  10. (1983). Polozhenie ob etapah i stadiyah geologorazvedochnyh  rabot na neft' i gaz. Moskva: VNIGNI.
  11. Abukova, L. A., Karcev, A. A. (1999). Flyuidnye sistemy osadochnyh neftegazonosnyh bassejnov (tipy, osnovnye processy, prostranstvennoe rasprostranenie). Otechestvennaya geologiya, 2, 11-16.
  12. Levyant, V. B., Shuster, V. L. (2002). Vydelenie v fundamente treshchinovatyh porod metodami sejsmorazvedki 3D. Geologiya nefti i gaza, 2, 21-26.
  13. Zhemchugova, V. A., Rybalchenko, V. V., Shardanova, T. A. Sequence-stratigraphic model of the west siberia lower cretaceous. Georesursy, 23(2), 179-191.
  14. Kurysheva, N. K. (2005). Prognozirovanie, kartirovanie zalezhej nefti i gaza v verhnej chasti doyurskogo kompleksa po sejsmologicheskim dannym v SHaimskom neftegazonosnom rajone i na prilegayushchih uchastkah. Avtoreferat dissertacii na soiskanie uchenoj stepeni kandidata geologo-mineralogicheskih nauk. Tyumen'.
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DOI: 10.5510/OGP2021SI200542

E-mail: tshuster@mail.ru


E.A. Sidorchuk, M.E. Seliverstova

Oil and Gas Research Institute of the Russian Academy of Sciences, Moscow, Russia

Evaporite rocks as a factor in formation of non-structural traps


The paper considers the improvement in classification of oil and gas traps formed in non-anticlinal conditions. The relevant aim is to expand the areas where hydrocarbon accumulations are searched for and to take into account the new search attributes. Evaporite rocks, widely developed in many oil and gas basins, have properties that contribute to the preservation of hydrocarbon deposits. Depending on the structural features of the salt formations, their impact on the location of oil and gas deposits varies. The deposits associated with the evaporite rocks are analyzed. Types of traps, the main factor in formation of which are evaporites, are defined. Such traps are proposed to be treated as a separate category.

Keywords: evaporite rocks; non-structural and combined traps; hydrocarbon accumulations; classifications of traps; tectonic style; sealed reservoirs.

The paper considers the improvement in classification of oil and gas traps formed in non-anticlinal conditions. The relevant aim is to expand the areas where hydrocarbon accumulations are searched for and to take into account the new search attributes. Evaporite rocks, widely developed in many oil and gas basins, have properties that contribute to the preservation of hydrocarbon deposits. Depending on the structural features of the salt formations, their impact on the location of oil and gas deposits varies. The deposits associated with the evaporite rocks are analyzed. Types of traps, the main factor in formation of which are evaporites, are defined. Such traps are proposed to be treated as a separate category.

Keywords: evaporite rocks; non-structural and combined traps; hydrocarbon accumulations; classifications of traps; tectonic style; sealed reservoirs.

References

  1. Kulibakina, I. B. (1982). Factors determining the confinement of hydrocarbon deposits to salt accumulation
  2. basins /In: Oil and gas potential of the regions of ancient saline accumulation. Novosibirsk: Nauka.
  3. Gaev, A. Ya., Shchugorev, V. D., Butolin, A. P. (1986). Underground storage tanks: Construction and development conditions and operation technology. Leningrad: Nedra.
  4. Selley, R. C. (1976). An introduction to sedimentology. London: Academic Press.
  5. Perrodon, A. (1980). Géodynamique pétrolière: Genèse et répartition des gisements d’hydrocarbures. Paris: Elf Aquitaine.
  6. Polyakov, A. A., Koloskov, V. N., Fonchikova, M. N. (2015). On the classification of petroleum accumulations. Neftegazovaya Geologiya. Teoriya i Praktika, 10(1), 10.
  7. Kiryukhin, L. G., Kapustin, I. N., Komissarova, I. N. (1982). Paleogeographic and paleotectonic formation conditions of the Kungur saline formation of the Pre-Caspian basin and its influence on the location of oil and gas deposits /In: Oil and gas potential of the regions of ancient saline accumulation. Novosibirsk: Nauka.
  8. Nikolaev, Yu. D., Sivkov, S. N. (1982). Interrelation of evaporite sediments of the Timan-Pechora province with oil and gas deposits /In: Oil and gas potential of the regions of ancient saline accumulation. Novosibirsk: Nauka.
  9. Grunis, E. B., Rostovschikov, V. B., Bogdanov, B. P. (2016). Ordovician salts and their role in the structure and oil and gas potential of the northeast of the Timan-Pechora province. Georesursy, 18(1), 13–23.
  10. Vinogradov, L. D., Sakhibgareev, R. S., Kitsis, N. A. (1982). Catagenic sealing of oil and gas deposits by halite /In: Oil and gas potential of the regions of ancient saline accumulation. Novosibirsk: Nauka.
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DOI: 10.5510/OGP2021SI200547

E-mail: elena_sidorchuk@mail.ru


O. P. Abramova, D. S. Filippova

Institute of Oil and Gas Problems of the Russian Academy of Sciences, Moscow, Russia

Geobiological features of storage hydrogen-methane mixtures in underground reservoirs


Taking into account the world and domestic experience of studying the ontogenesis of lithospheric hydrogen a combination of coupled hydrochemical, geochemical and microbiological factors of the accumulation of this natural gas together with methane in the terrigenous formations of the sedimentary cover is justified. It is predicted that various hydrochemical and microbiological processes that cause the development of carbon dioxide and sulfate corrosion of engineering structures, as well as cement of reservoir rocks and tires, can occur together with methane at industrial facilities of underground storage of hydrogen. The risks of reducing the volume of injected hydrogen in underground storage in addition to diffusion losses can be associated with geobiological factors, including the conversion of hydrogen into CH4 and H2S due to microbial activity, chemical interaction of hydrogen with minerals of reservoirs and tires, accompanied by changes in filtration-capacity and geomechanical properties, hydrogen embrittlement of metal structures of ground and underground well equipment.

Keywords: geobiology; hydrogen; methane; underground storage; methanogenesis; acetogenesis; sulfate reduction.

Taking into account the world and domestic experience of studying the ontogenesis of lithospheric hydrogen a combination of coupled hydrochemical, geochemical and microbiological factors of the accumulation of this natural gas together with methane in the terrigenous formations of the sedimentary cover is justified. It is predicted that various hydrochemical and microbiological processes that cause the development of carbon dioxide and sulfate corrosion of engineering structures, as well as cement of reservoir rocks and tires, can occur together with methane at industrial facilities of underground storage of hydrogen. The risks of reducing the volume of injected hydrogen in underground storage in addition to diffusion losses can be associated with geobiological factors, including the conversion of hydrogen into CH4 and H2S due to microbial activity, chemical interaction of hydrogen with minerals of reservoirs and tires, accompanied by changes in filtration-capacity and geomechanical properties, hydrogen embrittlement of metal structures of ground and underground well equipment.

Keywords: geobiology; hydrogen; methane; underground storage; methanogenesis; acetogenesis; sulfate reduction.

References

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  2. Subbota, M. I., Sardonnikov, N. M. (1968). O genezise gaza, sostoyashchego iz azota, okisi ugleroda i vodoroda nekotoryh mezhgornyh vpadin severnogo Tyan'-SHanya. Geohimiya, 5, 612-617.
  3. (1963). Plastovye vody paleozojskih otlozhenij Kujbyshevskogo Povolzh'ya. Trudy «KujbyshevNIINP» /pod red. Zajdel'sona, M. I., Kozina, A. N. Kujbyshev: KujbyshevNII NP.
  4. (1989). Waters of oil and gas deposits of the USSR /ed. L.M.Zorkina. Moscow: Nedra.
  5. Kudel'skij, A. V., Buraki, V.M. (1982). Gazovyj rezhim Pripyatkogo progiba. Minsk: Nauka i tekhnika.
  6. Molchanov, V. I. (1981). Hydrogen. generation in lithogenesis. Novosibirsk: Nauka,
  7. Korcenshtejn, V. N. (1976). Gidrogeologiya neftegazovyh mestorozhdenij i razvedochnyh ploshchadej YUzhnogo Mangyshlaka i sopredel'nyh rajonov Ustyurta. Moskva: Nedra.
  8. Betelev, N. P. (1961). O nalichii vodoroda v sostave prirodnogo gaza na yugo-vostochnom Ustyurte. Doklady Akademii Nauk SSSR, 161(6), 1422–1426.
  9. Sokolov, V. A. (1971). Geochemistry of natural gases. Moscow: Nedra.
  10. Zgonnik, V. (2020). The occurrence and geoscience of natural hydrogen: A comprehensive review. Earth-Science Reviews, 203, 103140.
  11. Larin, V. N., Hunt, C. W. (1993). Hydridic Earth: the new geology of our primordially hydrogenrich planet. Calgary, Alberta, Canada: Polar Publishing.
  12. Dmitriev, L. V., Bazylev, B. A., Silantiev, S. A., et al. (1999). Hydrogen and methane formation with serpentization of mantle hyperbasite of the ocean and oil generation. Russian Journal of Earth Sciences, 1(6), 511–519.
  13. McCollom, T. M., Donaldson, C. D. (2016). Generation of hydrogen and methane during experimental low-temperature reaction of ultramafic rocks with water. Astrobiology, 16(6), 389-406.
  14. Raznitsin, Yu. N., Gogonenkov, G. N., Zagorovsky, Yu. A., et al. Serpentization of mantle peridotites as fundamental source of deep-seating hydrocarbons in the West Siberian basin. Bulletin of Kamchatka Regional Association «Educational-Scientific Center». Earth Sciences, 1(45), 66-88.
  15. Lein, A. Yu., Bogdanov, Yu. A., Sagalevich, A. M., et al. (2004). A new type of vent field in the Mid-Atlantic ridge (Lost City vent field, 30°N). Doklady Earth Sciences, 394(1), 92-95.
  16. Vovk, I. F. (1979). Radiolysis of groundwater and its geochemical role. Moscow: Nedra.
  17. Smetannikov, A. F. (2011). Hydrogen generation during the radiolysis of crystallization water in carnallite and possible consequences of this process. Geochemistry International, 49(9), 916-924.
  18. Rogozina, E. A., Nalivkin, V. D., Neruchev, S. G. i dr. (1977). Etapy gazoobrazovaniya i ih vliyanie na raspredelenie nefti i gaza /v sb. «Genezis uglevodorodnyh gazov i formirovanie mestorozhdenij». Moskva: Nauka.
  19. Panfilov, M., Gravier, G., Fillacier, S. (2006, September). Underground storage of H2 and H2-CO2-CH4 mixtures, Netherlands. In: 10th European Conference on the Mathematics of Oil Recovery.
  20. Ranchou-Peyruse, M., Auguet, J., Mazière, C., et al. (2019). Geological gas-storage shapes deep life. Environmental Microbiology, 21(10), 3953–3964.
  21. Cord-Ruwisch, R., Kleinitz, W., Widdel, F. (1987). Sulfate-reducing bacteria and their activities in oil production. Journal of Petroleum Technology, 39, 97-106.
  22. Panfilov, M. (2010). Underground storage of hydrogen: natural methane generation and in-situ self-organisation. Special issue: Gazovaya Promyshlennost, 98-105.
  23. Pichler, M. P. (2013, September). Assesment of hydrogen rock interaction during geological storage of CH4-H2 mixtures. In: Second EAGE Sustainable Earth Sciences (SES) Conference and Exhibition.
  24. Hemme, C., Berk, W. (2018). Hydrogeochemical modeling to identify potential risks of underground hydrogen storage in depleted gas fields. Applied Sciences, 8, 2282.
  25. Hagemann, B., Rasoulzadeh, M., Panfilov, M., et al. (2015). Hydrogenization of underground storage of natural gas. Computational Geosciences, 20, 595-606.
  26. Reitenbach, V., Ganzer, L. J., Albrecht, D., Hagemann, B. (2015). Influence of added hydrogen on underground gas storage: a review of key issues. Environmental Earth Sciences, 73, 6927-6937.
  27. Matusevich, V. M., Kovyatkina, L. A. (2010). Oil and gas hydrogeology. Part I. Theoretical foundations of oil and gas hydrogeology. Tyumen: TSOGU.
  28. Kaszuba, J., Yardley, B., Andreani, M. (2013). Experimental perspectives of mineral dissolution and precipitation due to carbon dioxide-water-rock interactions. Reviews in Mineralogy and Geochemistry, 77, 153-188.
  29. Isaev, V. P. (2010). Geochemistry of oil and gas. Irkutsk: Irkutsk State University.
  30. Truche, L., Jodin-Caumon, M., Lerouge, C., et al. (2013). Sulphide mineral reactions in clay-rich rock induced by high hydrogen pressure. Application to disturbed or natural settings up to 250 °C and 30 bar. Chemical Geology, 351, 217-228.
  31. Krainov S. R., Shvets, V. M. (1993) Hydrogeochemistry. Moscow: Nedra.
  32. Lassin, A., Dymitrowska, M., Azaroual, M. (2011). Hydrogen solubility in pore water of partially saturated argillites: Application to Callovo-Oxfordian clayrock in the context of a nuclear waste geological disposal. Physics and Chemistry of The Earth, 36, 1721-1728.
  33. Yekta, A. E., Pichavant, M., Audigane, P. (2018). Evaluatio n of geochemical reactivity of hydrogen in sandstone: Application to geological storage. Applied Geochemistry, 95, 182-194.
  34. Shi, Z., Jessen, K., Tsotsis, T. T. (2020). Impacts of the subsurface storage of natural gas and hydrogen mixtures. International Journal of Hydrogen Energy, 45, 8757-8773.
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DOI: 10.5510/OGP2021SI200548

E-mail: abramova@bk.ru


I. F. Yusupova

Oil and Gas Research Institute of the Russian Academy of Sciences, Moscow, Russia

The role of concentrations variability of organic matter in kerogenic shale defluidisation on the catagenic depths


The Baltic kerogenic shale – kukersites (О2kk) were considered high-carbon marls which consist of three rock-forming components: organic matter (kerogen), carbonates and terrigenous material. As example used are data of the other high-carbon rocks. It is shown that increased concentrations of organic matter predetermine a number of features of these rocks (reduced density, reduced strength, etc.). The concentrations variability of the organic matter makes conditions the heterogeneity of the intraformational space, the anisotropy of many parameters, as well as the manifestation unevenness of the fluid-generation and evacuation capabilities. It was found that in kukersite shales fluid-generating properties can appear at the earliest stages of catagenesis. The role of areas with the maximum qualities of organic matter in the defluidisation of the shale coals is emphasized: here the more intensive generation of gas-liquid products and increased strength contribute to the earlier formation of drainage microcracks and fluid fractures. The appearance of shrinkage cracks due to catagenic losses of organic matter and usually uneven volume contraction and due to fluidgenerating shale coals is substantiated. The possibility of fluid-generating shale coals losing it lithological individuality during of it defluidisation is found out.

Keywords: organic matter; oil shale; kukersite; defluidization; catagenesis; hydrocarbons.

The Baltic kerogenic shale – kukersites (О2kk) were considered high-carbon marls which consist of three rock-forming components: organic matter (kerogen), carbonates and terrigenous material. As example used are data of the other high-carbon rocks. It is shown that increased concentrations of organic matter predetermine a number of features of these rocks (reduced density, reduced strength, etc.). The concentrations variability of the organic matter makes conditions the heterogeneity of the intraformational space, the anisotropy of many parameters, as well as the manifestation unevenness of the fluid-generation and evacuation capabilities. It was found that in kukersite shales fluid-generating properties can appear at the earliest stages of catagenesis. The role of areas with the maximum qualities of organic matter in the defluidisation of the shale coals is emphasized: here the more intensive generation of gas-liquid products and increased strength contribute to the earlier formation of drainage microcracks and fluid fractures. The appearance of shrinkage cracks due to catagenic losses of organic matter and usually uneven volume contraction and due to fluidgenerating shale coals is substantiated. The possibility of fluid-generating shale coals losing it lithological individuality during of it defluidisation is found out.

Keywords: organic matter; oil shale; kukersite; defluidization; catagenesis; hydrocarbons.

References

  1. Il’in, V. D., Kleshchev, K. A., Maksimov, S. P. (1986). Formations of oil shales in the zone of catagenesis and metamorphism: an Important source of hydrocarbons. Moscow: VIEMS.
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  6. Yusupova, I. F. (2019). The role of organic matter in formation of the properties of a shale deposit. Doklady Akademii Nauk, 484(2), 32–34.
  7. Yusupova, I. F., Fadeeva, N. P., Shardanova, T. A. (2019). The effect of increased concentration of organic matter on the rock properties. Georesursy, 21(2), 183–188.
  8. Fertel', V. H. (1980). Ocenka goryuchih slancev s pomoshch'yu karotazha /v kn. «Goryuchie slancy», pod red. Iena, T. F., CHilingaryana, Dzh. V. Leningrad: Nedra.
  9. Dyni, J. R. (2003). Geology and resources of some world oil-shale deposit. Oil Shale, 20(3), 193–252.
  10. Hrustaleva, G. K. (1991). Atlas goryuchih slancev SSSR. Rostov-na-Donu: Izdatel'stvo Rostovskogo Universiteta.
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  17. Abukova, L. A., Abramova, O. P., Yusupova, I. F. (2014). Role of the organic matter of a shale layer in the formation of its permeability at the early catagenic stage. Solid Fuel Chemistry, 48(2), 92-97.
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  22. Abbasov, O. R., Ibadzade, A. D., Hasaeva, A. B. i dr. (2015). Uglevodorodnyj potencial grubokopogruzhennyh otlozhenij Gobustana (Azerbajdzhan) (na osnove goryuchih slancev i neftenosnyh porod, vybrosov gryazevyh vulkanov) /v sb. «Resursovosproizvodyashchie, maloothodnye i prirodoohrannye tekhnologii osvoeniya nedr». Moskva: RUDN.
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DOI: 10.5510/OGP2021SI200553

E-mail: abukova@ipng.ru


V. Yu. Kerimov1, E. A. Lavrenova2, R. N. Mustaev1, Yu. V. Shcherbina1

1Russian State Geological Prospecting University, Moscow, Russia; 2OOO «ASAP Service», Gelendzhik, Russia

Hydrocarbon potential and prospects for exploration of Eastern Arctic oil and gas deposits


Conditions for the formation of hydrocarbon systems and prospects for searching for accumulations of oil and gas in the waters of the Eastern Arctic are considered. Significant hydrocarbon potential is predicted in the sedimentary basins of this region. All known manifestations of oil hydrocarbons are installed on land adjacent to the south, as well as on the east of the shelf. The East Arctic waters are included in a single model in order to perform an adequate comparative analysis of the evolution of hydrocarbon systems. The purpose of the research was to build space-time digital models of sedimentary basins and hydrocarbon systems, and to quantify the volume of generation, migration, and accumulation of hydrocarbons for the main horizons of source rocks. To achieve this goal, a spatiotemporal numerical basin simulation was carried out, based on which the distribution of probable hydrocarbon systems was determined and further analyzed. Following to the data obtained the most probable HC accumulation zones and types of fluids contained in potential traps were predicted.

Keywords: numerical space-time basin modeling; modeling of hydrocarbon systems; evidence of oil and gas presence; Eastern Arctic; elements of hydrocarbon systems; oil and gas reservoirs; migration; accumulation; perspective objects.

Conditions for the formation of hydrocarbon systems and prospects for searching for accumulations of oil and gas in the waters of the Eastern Arctic are considered. Significant hydrocarbon potential is predicted in the sedimentary basins of this region. All known manifestations of oil hydrocarbons are installed on land adjacent to the south, as well as on the east of the shelf. The East Arctic waters are included in a single model in order to perform an adequate comparative analysis of the evolution of hydrocarbon systems. The purpose of the research was to build space-time digital models of sedimentary basins and hydrocarbon systems, and to quantify the volume of generation, migration, and accumulation of hydrocarbons for the main horizons of source rocks. To achieve this goal, a spatiotemporal numerical basin simulation was carried out, based on which the distribution of probable hydrocarbon systems was determined and further analyzed. Following to the data obtained the most probable HC accumulation zones and types of fluids contained in potential traps were predicted.

Keywords: numerical space-time basin modeling; modeling of hydrocarbon systems; evidence of oil and gas presence; Eastern Arctic; elements of hydrocarbon systems; oil and gas reservoirs; migration; accumulation; perspective objects.

References

  1. Kerimov, V. Yu., Bondarev, A. V., Sizikov, E. A., et al. (2015). The conditions of formation and evolution of hydrocarbon systems in Sakhalin shelf, the Sea of Okhotsk. Oil Industry, 8, 22-27.
  2. Kerimov, V. Y., Gorbunov, A. A., Lavrenova, E. A., Osipov, A. V. (2015). Models of hydrocarbon systems in the Russian Platform–Ural junction zone. Lithology and Mineral Resources, 50(5), 394-406.
  3. Kerimov, V. Yu., Mustaev, R. N., Serikova, U. S., et al. (2015). Hydrocarbon generationaccumulative system on the territory of Crimea Peninsula and adjacent Azov and Black Seas. Oil Industry, 3, 56-60.
  4. Bogoyavlensky, V. I., Kerimov, V. Yu., Olkhovskaya, O. O. (2016). Dangerous gas-saturated objects in the world ocean: The Sea of Okhotsk. Oil Industry, 11, 43-47.
  5. Lazurkin, D. V. (2004). Prospects for oil and gas potential of the Laptev, East Siberian, and Chukotka seas. Atlas: Geology and minerals of the Russian shelf. Moscow: GIN RAS.
  6. 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.
  7. Ivanova, N. M., Sekretov, S. B., Skarubo, S. I. (1989). Data on the geological structure of the shelf of the Laptev Sea based on seismic data. Oceanology, 1989, 29(5), 789-793.
  8. Guliyev, I. S., Kerimov, V. Yu., Osipov, A. V., Mustaev, R. N. (2017). Generation and accumulation of hydrocarbons at great depths under the Earth's Crust. SOCAR Proseedings, 1, 4-16.
  9. Kerimov, V. Y., Bondarev, A. V., Osipov, A. V., Serov, S. G. (2015). Evolution of petroleum systems in the territory of Baikit anticlise and Kureiskaya syneclise (Eastern Siberia). Oil Industry, 5, 39-42.
  10. 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.
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DOI: 10.5510/OGP2021SI200556

E-mail: r.mustaev@mail.ru


V.A. Sudakov1, M.S. Shipaeva1, D.K. Nurgaliev1, Z.M. Rizvanova1, M.I. Amerhanov2

1Kazan Federal University, Kazan, Russia; 2PJSC «Tatneft», Almetyevsk, Russia

Geochemical characteristics and localization of heavy oil fields in the Republic of Tatarstan, Russia


High-viscosity oil belong to unconventional sources of hydrocarbon raw materials, the share of which is growing every year. The development of this complex type of raw material requires modern scientific technologies in order to maintain the production of hydrocarbons at the same level. Technologies for the extraction and processing of heavy oil are different from traditional ones. First of all, these deposits are located at a shallow depth, but are classified as difficult to recover due to the complex geological structure and high anomalous oil viscosity. The objective of this work is a deeper understanding of the geochemical composition of heavy oil deposits, taking into account the peculiarities of their geological structure. This is important for the successful development of new and improvement of existing technologies for the extraction and processing of heavy oil and the implementation of the resource potential of heavy oils in the Republic of Tatarstan.

Keywords: heavy oil; unconventional oil; biodegradation; GC-MS; geochemical methods.

High-viscosity oil belong to unconventional sources of hydrocarbon raw materials, the share of which is growing every year. The development of this complex type of raw material requires modern scientific technologies in order to maintain the production of hydrocarbons at the same level. Technologies for the extraction and processing of heavy oil are different from traditional ones. First of all, these deposits are located at a shallow depth, but are classified as difficult to recover due to the complex geological structure and high anomalous oil viscosity. The objective of this work is a deeper understanding of the geochemical composition of heavy oil deposits, taking into account the peculiarities of their geological structure. This is important for the successful development of new and improvement of existing technologies for the extraction and processing of heavy oil and the implementation of the resource potential of heavy oils in the Republic of Tatarstan.

Keywords: heavy oil; unconventional oil; biodegradation; GC-MS; geochemical methods.

References

  1. Cheng, L., Shi, Sh.-B., Yang, L., et al. (2019). Preferential degradation of long-chain alkyl substituted hydrocarbons in heavy oil under methanogenic conditions. Organic Geochemistry, 138, 103927.
  2. Giacchetta, G., Leporini, M., Marchetti, B. (2015). Economic and environmental analysis of a Steam Assisted Gravity Drainage (SAGD) facility for oil recovery from Canadian oil sands. Applied Energy, 142, 1-9.
  3. Niu, J., Huang, H., Jiang, W. (2018). Geochemical characteristics and correlation of continuous charge mixing and biodegradation of heavy oil in southeastern Dongying Sag, Bohai Bay basin, China. Journal of Petroleum Science and Engineering, 166, 1-12.
  4. Aitken, C. M., Head, I. M., Jones, D. M. (2017). Comprehensive two-dimensional gas chromatographymass spectrometry of complex mixtures of anaerobic bacterial metabolites of petroleum hydrocarbons. Journal of Chromatography, 1536, 96-109.
  5. Guo, T., Wang, J., Gates, I. (2018). Pad-scale control improves SAGD performance. Petroleum, 227, 318-328.
  6. Lanxiang, S. D, Ma, P. L, Xiuluan, L. C, Xia, C. W. (2019). Experimental and numerical simulation studies on effects of viscosity reducers for steam assisted gravity drainage performances in extra-heavy oil reservoirs. Journal of Petroleum Science and Engineering,173, 146-157.
  7. Uspenskiy, B. V., Sharipova, N. S., Khaliullina, S. V. (2017). Ranking of the superviscous oils. by the peculiarities of the hydrocarbon composition as exemplified by the Cheremshano-Bastrykskaya area. In: Bulatovskiye Chteniya.
  8. Adgamova, G. Sh., Gataullin, R. I., Grin'ko, Yu. A. (2017). Geokhimicheskiye issledovaniya v pripoverkhnostnoy zone razrabotki Yuzhnoashal'chinskoy zalezhi SVN. Kazan: AN RT.
  9. Kalimullin, A. M., Safarov, A. F. (2017). Osobennosti geologicheskogo stroyeniya i usloviya formirovaniya bobrikovskogo gorizonta Sirenevskogo mestorozhdeniya. Kazan: AN RT.
  10. Kayukova, G. P., Petrov, S. M., Uspenskiy, B. V. (2015). Svoystva tyazhelykh neftey i bitumov Permskikh otlozheniyTatarstana v prirodnykh i tekhnogennykh protsessakh. Moscow: GEOS.
  11. Kashirtsev, V. A., Kontorovich, A. E., Ivanov, V. L., Safronov, A. F. (2010). Natural bitumen fields in the northeast of the Siberian Platform (Russian Arctic sector). Russian Geology and Geophysics, 51, 72-82.
  12. Saeedi Dehaghani, A., H., Hasan Badizad, M. (2016). Experimental study of Iranian heavy crude oil viscosity reduction by diluting with heptane, methanol, toluene, gas condensate and naphtha. Petroleum. 2, 415-424.
  13. Shipaeva, M. S., Sudakov, V. A, Lomonosov, А. T., et al. (2019). Integrated approach for monitoring of SAGD wells efficiency basing on the optical fiber temperature sensing and geochemical monitoring of production. In: EAGE Conference Proceedings, Horizontal Wells 2019 Challenges and Opportunities.
  14. Shipaeva, M. S., Sudakov, V.A., Akhmadullin, R. R. (2019). Analysis of the results of tracer tests for the monitoring of the development of super-viscous oil deposit. IOP Conference Series: Earth Environment, 282, 012042.
  15. Zhu, G., Zhang, S., Jay, B., Jin, K. (2014). Geochemical features and origin of natural gas in heavy oil area of the Western Slope, Songliao Basin, China. Journal Geochemistry, 74, 63-75.
  16. Abitova, A. Zh. (2011). Rheological features of certain non-newtonian oils of Western Kazakhstan fields. SOCAR Proceedings, 2, 48-51.
  17. Mukhtanov, B. M., Bektasov, A. A., Khazhitov, V. Z. (2018). Overview of the operating technology for continuous steam injection in Kazakhstan. SOCAR Proceedings, 3, 45-53.
  18. Jalalov, G. I., Aslanov, M. S. (2011). Concerning the determination of the temperature field in a multilayer oil reservoir using heat source injection. SOCAR Proceedings, 2, 35-37.
  19. Muslimov, R. Kh., Ananyev, V. V., Smelkov, V. M., Tukhvatullin, R. (2007). Metody prognoza, poiska i razvedki neftyanykh i gazovykh mestorozhdeniy:uchebnoye posobiye. Kazan: Kazan University.
  20. Abusalimova, R. R., Kostina, A. A., Panin, S. A. (2017). Types of sections of the sandy member of the Sheshminsky horizon and the patterns of their distribution on the territory of the Republic of Tatarstan. Oil Province, 2, 83–94.
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DOI: 10.5510/OGP2021SI200558

E-mail: mariasipaeva@gmail.com


B.V. Uspensky1, N.G. Nurgalieva1, S.E. Valeeva1,2, E.E. Andreeva2

1Kazan Federal University, Kazan, Russia; 2Institute of Ecology and Subsoil Use of the Tatarstan Academy of Sciences, Kazan, Russia

Tectonic aspects of super-viscous oil deposits formation and placement within the Volga-Ural anteclise


The article discusses the tectonics and developmental features of the Volga-Ural anteclise during the Baikalian, Caledonian, Hercynian and Alpine tectogenesis cycles. In this paper, particular attention is paid to stages and directional development during the evolution of geological structures. The main factors of the formation and destruction of Permian viscous oil and natural bitumen reservoirs are presented in the provisions of oil ontogenesis. It was noted the cyclical nature of these phenomena.

Keywords: Volga-Ural anteclise; super-viscous oil; tectonic; reservoir; oil.

The article discusses the tectonics and developmental features of the Volga-Ural anteclise during the Baikalian, Caledonian, Hercynian and Alpine tectogenesis cycles. In this paper, particular attention is paid to stages and directional development during the evolution of geological structures. The main factors of the formation and destruction of Permian viscous oil and natural bitumen reservoirs are presented in the provisions of oil ontogenesis. It was noted the cyclical nature of these phenomena.

Keywords: Volga-Ural anteclise; super-viscous oil; tectonic; reservoir; oil.

References

  1. Voitovich, E. D. (2013). Tectonics of Tatarstan. Kazan: Publishing house of Kazan University.
  2. Muslimov, R. Kh. (2007). Petroleum potential of the Tatarstan Republic. Geology and development of oil fields. Kazan: Fen.
  3. Khachatryan, R. O. (1979). Tectonic development and oil potential of the Volga-Kama anteclise. Moscow: Nauka.
  4. Chizhov, A. P., Rabaev, R. U., Andreev, V. E., et al. (2020) Theoretical features of improving the oil recovery efficiency from carbonate reservoirs in the Volga-Ural Province. SOCAR Proceedings, 4, 9-14.
  5. Osipov, A. V., Kerimov, V. Yu., Vasilenko, E. I., Monakova, A. S. (2019). Petroleum systems formation conditions in the deeply sediments in South-East part of the Volga-Ural oil and gas province. SOCAR Proceedings, 1, 4-18.
  6. Clubov, V. A. (1973). Paleostructural analysis of the eastern regions of the Russian platform. Moscow: Nedra.
  7. Larochkina, I. A. (2008). Geological basis of prospecting and exploration of oil and gas fields in the Republic of Tatarstan. Kazan: PF Gart LLC publishing house.
  8. Troepolsky, V. I. (1964). Geological structure and oil content of the Aksubaevo-Melekess depression. Kazan: Publishing house of Kazan University.
  9. Ignatiev, V. I. (1976). The formation of the Volga-Ural anteclise in the Permian period. Kazan: Publishing house of Kazan University.
  10. Uspensky, B. V. (1996). The influence of tectonics on the formation and distribution of hydrocarbons in the central regions of the Volga-Ural region. Tectonic and paleogeomorphological aspects of oil and gas potential. Ukraine: Abstracts of the International Conference.
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DOI: 10.5510/OGP2021SI200559

E-mail: ssalun@mail.ru


I.Yu. Chernova, D.K. Nourgaliev, O.S. Chernova, O.V. Luneva

Kazan Federal University, Kazan, Russia

Applying the combination of GIS tools with upgraded structural and morphological methods for studying neotectonics


Structural and geomorphological methods are often applied to the search for small oil-producing structures. Morphometric analysis of digital elevation models has proved to be the most informative one. Morphometric surfaces can be used to evaluate the direction and amplitude of vertical movements, to outline local and regional neotectonic structures and assess their petroleum saturation. This paper shows how to enhance the traditional morphometric analysis with GIS (geographic information systems) tools. A manifold increase in the efficiency of morphometric analysis takes it to a qualitatively new level. Setting specific parameters for some geoprocessing tools (for example, stream network tools) can be very important when studying local structures in small areas. In case of large territories, the output result is almost independent of the calculation errors. The improved technique proposed in this paper was tested on a large territory located in the Volga region. As a result, high-order morphometric surfaces were obtained, which was not possible before. In addition, a statistically significant relationship was discovered between morphometric surfaces and distribution of oil deposits, which can be considered a reliable prospecting indicator in the Volga-Ural petroleum province.

Keywords: neotectonics; structural and morphological methods; geoinformation systems; hydrocarbon potential assessment.

Structural and geomorphological methods are often applied to the search for small oil-producing structures. Morphometric analysis of digital elevation models has proved to be the most informative one. Morphometric surfaces can be used to evaluate the direction and amplitude of vertical movements, to outline local and regional neotectonic structures and assess their petroleum saturation. This paper shows how to enhance the traditional morphometric analysis with GIS (geographic information systems) tools. A manifold increase in the efficiency of morphometric analysis takes it to a qualitatively new level. Setting specific parameters for some geoprocessing tools (for example, stream network tools) can be very important when studying local structures in small areas. In case of large territories, the output result is almost independent of the calculation errors. The improved technique proposed in this paper was tested on a large territory located in the Volga region. As a result, high-order morphometric surfaces were obtained, which was not possible before. In addition, a statistically significant relationship was discovered between morphometric surfaces and distribution of oil deposits, which can be considered a reliable prospecting indicator in the Volga-Ural petroleum province.

Keywords: neotectonics; structural and morphological methods; geoinformation systems; hydrocarbon potential assessment.

References

  1. Lastochkin, A. N. (1974). Neotektonicheskie dvizheniya i razmeshchenie zalezhej nefti i gaza. Leningrad: Nedra.
  2. Lastochkin, A. N. (1971). O formah proyavleniya razryvnyh narushenij v rel'efe Zapadno-Sibirskoj ravniny i strukturno-geomorfologicheskom metode ih obnaruzheniya. Izvestiya VGO, 1, 48-56.
  3. Filosofov, V. P., Denisov, S. V. (1963). O poryadke rechnyh dolin i ih svyazi s tektonikoj. Morfometricheskij metod pri geologicheskih issledovaniyah. Saratov: Izdatelstvo Saratovskogo Universiteta.
  4. Filosofov, V. P. (1975). Osnovy morfometricheskogo metoda poiskov tektonicheskih struktur. Saratov: Izdatelstvo Saratovskogo Universiteta.
  5. Golodovkin, V. D. (1964). Tektonicheskoe stroenie Stavropol'skoj depressii po dannym morfometricheskogo analiza. Kujbyshev: Trudi Kujbyshevskogo NII Neftyanoj promyshlennosti, Geologiya, geohimiya, geofizika, 27, 45-47.
  6. Muzychenko, N. M. (1962). Sovremennaya tektonika kamennougol'nyh otlozhenij Volgogradsko-Saratovskogo Povolzh'ya v svyazi s ocenkoj perspektiv ih neftenosnosti. Materialy po tektonike Nizhnego Povolzh'ya. Leningrad: Gostoptekhizdat.
  7. Nourgaliev, D. K., Chernova, I. Yu., Nurgalieva, N. G., et al. (2013). Spatial variability of oil properties within oil fields of the Republic of Tatarstan. Oil Industry, 6, 8-11.
  8. Horton, R. E. (1945). Erosional development of streams and their drainage basins Hydrophysical approach to quantitative morphology. Bulletin of the Geological society of America, 56.
  9. McCoy, J., Johnston, K. (2001). Using arcgis spatial analyst. U.S.A.: Environmental Systems Research Institute Inc.
  10. Hutchinson, M. F., Dowling, T. I. (1991). A continental hydrological assessment of a new gridbased digital elevation model of Australia. Hydrological Processes, 5, 45-58
  11. Hutchinson, M. F. (1988). Calculation of hydrologically sound digital elevation models. In: Third International Symposium on Spatial Data Handling at Sydney, Australia.
  12. Hutchinson, M. F. (1989). A new procedure for gridding elevation and streamline data with automatic removal of spurious pits. Journal of Hydrology, 106, 211-232.
  13. Strahler, A. N. (1957). Quantitative Analysis of Watershed Geomorphology. Transactions of the American Geophysical Union, 8(6), 913-920.
  14. Tarboton, D. G., Bras, R. L., Rodriguez-Iturbe, I. (1991). On the extraction of channel networks from digital elevation data. Hydrological Processes, 5, 81-100.
  15. Fairfield, J., Leymarie, P. (1991). Drainage networks from grid digital elevation models. Water Resources Research, 27(5), 709-717.
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  17. Burba, V. I. (1972). Neotektonika Kazanskogo Zakam'ya. Kazan': Izdatelstvo Kazanskogo Universiteta.
  18. Nelidov, N. N. (1960). Neotektonika Kazanskogo Zakam'ya. Geomorfologiya i novejshaya tektonika Volgo-Ural'skoj oblasti i Yuzhnogo Urala. Ufa.
  19. Nugmanov, I. I. (2013). Vliyanie neotektonicheskih dvizhenij na razmeshchenie i sohrannost' zalezhej nefti i gaza (na primere Tatarskogo svoda i sklonov prilegayushchih vpadin). Dissertasiya na soiskaniye uchenoy stepeni kandidata geologo-mineralogicheskix nauk. Kazan': Kazanskij (Privolzhskij) Federal'nyj Universitet.
  20. Travina, L. M. (1963). Primenenie morfometricheskogo metoda k poiskam struktur v severozapadnoj chasti Orenburgskoj oblasti. Voprosy Morfometrii, 2, 201-207.
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DOI: 10.5510/OGP2021SI200560

E-mail: inna.chernova@kpfu.ru


V.Е. Kosarev1, E.R. Ziganshin1, I.P. Novikov2, A.N. Dautov1, E.A. Yachmeneva1, E.S. Bystrov1

1Kazan (Volga region) Federal University, Kazan, Russia; 2JSC «Tatnefteprom», Kazan, Russia

Geomechanical properties of carbonate reservoir rocks and middle carbon cap rocks of the Ivinskoe oilfield


Laboratory studies of the geomechanical properties of rocks are an important and integral part in building a geomechanical model. This study resulted in a set of data on geomechanical and elastic properties of the rocks that compose the lower part of the Middle Carboniferous section of the Ivinskoye oilfield (Russia). Relationships between various elastic parameters were also established. The distribution of geomechanical properties correlates with structural/textural features of the rocks under study and their lithological type. This information can be used as a basis for geomechanical modeling and in preparation for hydraulic fracturing.

Keywords: geomechanics; elastic properties; carbonate rock; laboratory core studies.

Laboratory studies of the geomechanical properties of rocks are an important and integral part in building a geomechanical model. This study resulted in a set of data on geomechanical and elastic properties of the rocks that compose the lower part of the Middle Carboniferous section of the Ivinskoye oilfield (Russia). Relationships between various elastic parameters were also established. The distribution of geomechanical properties correlates with structural/textural features of the rocks under study and their lithological type. This information can be used as a basis for geomechanical modeling and in preparation for hydraulic fracturing.

Keywords: geomechanics; elastic properties; carbonate rock; laboratory core studies.

References

  1. Zoback, M. D. (2007). Reservoir geomechanics. Cambridge: Cambridge University Press.
  2. Mavko, G., Mukerji, T., Dvorkin, J. (2009). The rock physics handbook. Cambridge University Press.
  3. ASTM D2845-08. (2008). Standard test method for laboratory determination of pulse velocities and ultrasonic elastic constants of rock (Withdrawn 2017). PA, West Conshohocken: ASTM International. www.astm.org
  4. ASTM D3967-08. (2008). Standard test method for splitting tensile strength of intact rock core specimens. PA, West Conshohocken: ASTM International. www.astm.org
  5. ASTM D7012-14. (2014) Standard test methods for compressive strength and elastic moduli of intact rock core specimens under varying states of stress and temperatures. , PA, West Conshohocken: ASTM International. www.astm.org
  6. (2015). The ISRM suggested methods for rock characterization, testing and monitoring: 2007–2014 / ed. Ulusay, R. Switzerland: Springer International Publishing.
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DOI: 10.5510/OGP2021SI200561

E-mail: eduard-ziganshin@mail.ru


D.K. Nurgaliev1, I.Yu. Chernova1, D.I. Khassanov1, B.I. Gareev1, G.A. Batalin1, D.Ya. Khabibullin2

1Kazan Federal University, Kazan, Russia; 2PJSC «Gazprom», Moscow, Russia

Comparing the results of lineament analysis with isotope geochemistry data


This article presents the results of a geochemical survey carried out in the southwestern part of the Siberian platform, within the Sayan-Yenisei (Angara) syneclise (a superorder Riphean-Middle Paleozoic structure). The object of research was hydrocarbon gases contained in the subsoil rocks (clays). The subsoil samples were taken from the bottom of boreholes (40 mm in diameter) made with an electric drill. The sampling depth was 0.6–1 m. Further laboratory studies included chromatographic and isotope analysis. Lineament analysis of the digital elevation model was carried out as a complementary study. One of the lineament analysis results was a lineament density map, which reflects the permeability (macro-fracture density) of the sedimentary cover. This allowed a comparison of the macro-fracture density with the gas content and isotopic composition. The study revealed that gases with a high content of heavy isotopes tend to gather in the low permeability areas. This can be explained by the fact that the gases disperse quickly within fractured zones, and deep gases should be expected only in the areas with strong cap rocks, i.e. in the areas with low macrofracture density where stable hydrocarbon deposits have already formed.

Keywords: hydrocarbons; geochemical survey; isotope geochemistry; lineament analysis.

This article presents the results of a geochemical survey carried out in the southwestern part of the Siberian platform, within the Sayan-Yenisei (Angara) syneclise (a superorder Riphean-Middle Paleozoic structure). The object of research was hydrocarbon gases contained in the subsoil rocks (clays). The subsoil samples were taken from the bottom of boreholes (40 mm in diameter) made with an electric drill. The sampling depth was 0.6–1 m. Further laboratory studies included chromatographic and isotope analysis. Lineament analysis of the digital elevation model was carried out as a complementary study. One of the lineament analysis results was a lineament density map, which reflects the permeability (macro-fracture density) of the sedimentary cover. This allowed a comparison of the macro-fracture density with the gas content and isotopic composition. The study revealed that gases with a high content of heavy isotopes tend to gather in the low permeability areas. This can be explained by the fact that the gases disperse quickly within fractured zones, and deep gases should be expected only in the areas with strong cap rocks, i.e. in the areas with low macrofracture density where stable hydrocarbon deposits have already formed.

Keywords: hydrocarbons; geochemical survey; isotope geochemistry; lineament analysis.

References

  1. Yudovich, Ya. E., Ketris, M. P. (2010). Carbon isotope ratios in the stratisphere and biosphere: four scenarios. Interdisciplinary Scientific and Applied Journal «Biosphere», 2(2), 231-246.
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  11. Randazzo, A., Asensio-Ramos, M., Melián, G. V., et al. (2020). Volatile organic compounds (VOCs) in solid waste landfill cover soil: Chemical and isotopic composition vs. degradation processes. Science of the Total Environment, 726, 138326.
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  14. Zlatopolsky, A. A. (2008). Technique for measuring the orientation characteristics of remote sensing data (LESSA technology). In: Fifth Anniversary Open All-Russian Conference «Modern problems of remote sensing of the Earth from space», LLC "Azbuka", Moscow.
  15. Zlatopolsky, A. A. (2007). Features of determining the direction of natural objects and textures using raster remote data. In: Modern problems of remote sensing of the Earth from space, Physical foundations, methods and technologies for monitoring the environment, potentially dangerous objects and phenomena. Moscow: LLC «Azbuka-2000».
  16. Zlatopolsky, A. A. (2011). New possibilities of LESSA technology and analysis of digital elevation model. Methodological aspect. Modern problems of remote sensing of the Earth from space, 8(3), 38-46.
  17. Malkin, B. V., Zlatopolsky, A. A. (2004) Southern Angola Lineament Tectonics Features Analysis via Image Processing (LESSA). IGC- Florence, 199, 42.
  18. Zlatopolsky, A. A. (1996). Texture orientation description of remote sensing data using LESSA (Lineament Extraction and Stripe Statistical Analysis). Computers & Geosciences, 23(1), 45-62.
  19. Borovikov, V. (2003). STATISTICA. The art of data analysis on a computer: For professionals. Saint Petersburg: Piter.
  20. Mitchell, A. (1999). ESRI guide to GIS analysis. Volume 1: Geographic patterns geographic patterns & relationships. New York: ESRI Press.
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DOI: 10.5510/OGP2021SI200562

E-mail: khassanov.damir@mail.ru


E. A. Korolev1, V. P. Morozov1, A. A. Eskin1, A. N. Kolchugin1, E. R. Barieva2, A. S. Khayuzkin1

1Kazan Federal University, Kazan, Russia; 2Kazan State Power Engineering University, Kazan, Russia

Diagenetic stages of oil-saturated sandstones of the pashyisky horizon at the Romashkinskoye oil field


It was identified three stages of reservoir rock formation of the Pashyisky horizon of the Frasnian stage of the Upper Devonian at the Romashkinskoye field, based on optical microscopic studies. The first stage, associated with clastic deposits sedimentation and marked by clastic grains dense structural packing formation, close to cubic. The second diagenetic stage of quartz sandstones is associated with the subsidence stage of sediments into the burial zone. During this period were actively proceeding the processes of grains mechanical deformation, blastesis of quartz clasts, the formation of siderite fragments, and fibrous chalcedony, partially metasomatic replacing clay layers in sandstones. The third diagenetic stage in quartz sandstones is associated with the migration of underground gas-water solutions. Analysis of the transformation degree of the Pashyisky horizon quartz sandstones at different areas of the Romashkinskoye field revealed the relationship between the intensity of secondary diagenetic processes and the degree of rocks oil saturation.

Keywords: pashyisky horizon; oil; sandstone; reservoir; diagenesis.

It was identified three stages of reservoir rock formation of the Pashyisky horizon of the Frasnian stage of the Upper Devonian at the Romashkinskoye field, based on optical microscopic studies. The first stage, associated with clastic deposits sedimentation and marked by clastic grains dense structural packing formation, close to cubic. The second diagenetic stage of quartz sandstones is associated with the subsidence stage of sediments into the burial zone. During this period were actively proceeding the processes of grains mechanical deformation, blastesis of quartz clasts, the formation of siderite fragments, and fibrous chalcedony, partially metasomatic replacing clay layers in sandstones. The third diagenetic stage in quartz sandstones is associated with the migration of underground gas-water solutions. Analysis of the transformation degree of the Pashyisky horizon quartz sandstones at different areas of the Romashkinskoye field revealed the relationship between the intensity of secondary diagenetic processes and the degree of rocks oil saturation.

Keywords: pashyisky horizon; oil; sandstone; reservoir; diagenesis.

References

  1. Yapaskurt, O. V. (2016). The staged analysis of mineral witnesses of the dynamics of the formation and evolution of sedimentary rocks is a promising scientific direction in lithology and oil and gas geology. Georesursy, 18(31), 64-68.
  2. Isgandarov, M. M., Abuzarova, A. H. (2013). Substantiation of criteria for oil & gas content in heterogeneous sandy-siltstone reservoirs (on an example of deposits of the Baku archipelago). SOCAR Proceedings, 4, 6-10.
  3. Vinogradov, L. D., Sakhibgareev, P. C., Kisis, H. A. (1982). Catagenetic healing of oil and gas deposits with halite. Oil and Gas Content of the Regions of Ancient Salt Accumulation, 112-121.
  4. Lukin, A. E., Garipov, O. M. (1994). Lithogenesis and oil-bearing capacity of Jurassic terrigenous deposits of the mid-latitude Ob region. Lithology and mineral resources, 5, 65-85.
  5. Nemova, V. D. Koloskov, V. N., Gavrilov, S. S., Pokrovsky, B. G. (2010). Staging and direction of secondary transformations of reservoir rocks of the Lower Tutleim Subformation in the west of the Shirotnoye Ob region. Geology of Oil and Gas, 6, 22-28.
  6. Loscheva, Z. A., Magdeev, M. Sh., Agafonov, S. G., et al. (2017). A new look at the geological structure of the Pashi horizon (D3ps) of the Aznakaevskaya area of the Romashkinskoye oil field. Georesursy, 19(1), 21-26.
  7. Melnikov, I. A. (2019). The intensity of superimposed epigenesis processes as an indicator of oil saturation in sandy reservoirs. Bulletin of the Tomsk Polytechnic University. Engineering of Georesources, 330(6), 90-97.
  8. Korolev, E. A. (2014). Stages of transformation of the Tulsky-Bobrikovsky sandstone reservoirs in erosion cuts in the territory of Tatarstan. Scientific notes of Kazan University, 156 (3), 87-97.
  9. Korolev, E. A., Bakhtin, A. I., Eskin, A. A., Khanipova, R. R. (2016). Diagenetic changes of sandstone reservoir of Ashalchinskoye bitumen deposit. Oil Industry, 10, 26-28.
  10. Khisamov, R. S., Voitovich, E. D., Liberman, V. B., et al. (2006). Tectonic and oil-geological zoning of the territory of Tatarstan. Kazan: FEN.
  11. Baranov, V. A. (2014). Microdeformations of quartz in Carboniferous sandstones of Donbas. PNRPU Bulletin. Geology. Oil and Gas and Mining, 12, 75-86.
  12. Boeva, M., Novikov, V. M., Boeva, N. M., et al. (2016). The first find of biogenic nanosiderite in oxidized ferruginous quartzites of the Lebedinsky deposit. Reports of the Academy of Sciences, 466(5), 569-573.
  13. Naimark, E. B., Eroshchev-Shak, V. A., Chizhikova, N. P., Kompantseva, E. I. (2009). Interaction of clay minerals with microorganisms: a review of experimental data. Journal of General Biology, 70(2), 155-167.
  14. Katz, M. Ya., Simanovich, I. M. (1974). Quartz of crystalline rocks (mineralogical features and density properties). Moscow: Nauka.
  15. Taranenko, E. I., Bezborodov, R. S., Khakimov, M. Yu. (2001). Converting reservoirs to oil reservoirs. Geology of Oil and Gas, 2, 18-22.
  16. Sakhibgareev, R. S. (1989). Secondary reservoir changes during the formation and destruction of oil deposits. Leningrad: Nedra.
  17. Semeikin, I. N., Sheveleva, N. N. (2011). Facies rows of marine carbonate sediments and their ore content. Bulletin of the Siberian Branch. Geosciences Section of the Russian Academy of Natural Sciences, 38(1), 139-150.
  18. Korolev, E. A., Kolchugin, A. N., Bakhtin, A. I., et al. (2021). Features of the transformation of Visean quartz sandstones under the influence of water-oil fluids. Lithosphere (Russian Federation), 198-206.
  19. Kolchugin, A., Immenhauser, A., Morozov, V., et al. (2020). A comparative study of two Mississippian dolostone reservoirs in the Volga-Ural Basin, Russia. Journal of Asian Earth Sciences, 199, 104465.
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DOI: 10.5510/OGP2021SI200563

E-mail: anton.kolchugin@gmail.com


B.V. Platov, A.N. Kolchugin, E.A. Korolev, D.S. Nikolaev, A.I. Kadirov

Kazan Federal University, Kazan, Russia

Application of geophysical methods in the extrapolation of sedimentological data on unmastered areas of deposits (on the example of Pennsylvanian carbonate reservoir, Akanskoye oilfield, east of Russian Platform)


A feature of the oil-bearing carbonate deposits of the lower Pennsylvanian in the east of the Russian platform is their rapid vertical and horizontal change. It is often difficult to make correlations between sections, especially in the absence of core data when using only geophysical data. In addition, not all facies are reliably identified and traceable from log data and not all have high reservoir properties. Authors made an attempt to trace the promising facies both to adjacent wells and, in general, to the entire field area using core study results and translation of these results using log and seismic data. The data showed pinching of rocks with high reservoir characteristics in the direction of the selected profile (from south to north within the field). Coastal shallow water facies, represented by Grainstones and Packstones, with high reservoir properties in the south of the field, are replaced by lagoon facies and facies of subaerial exposures, represented by Wakestones and Mudstones with low reservoir characteristics, in the north of the field. The authors suggest that this approach can be applicable for rocks both in this region and for areas with a similar structure.

Keywords: pinch-out; well data; seismic data; limestone; facies; reservoir rocks.

A feature of the oil-bearing carbonate deposits of the lower Pennsylvanian in the east of the Russian platform is their rapid vertical and horizontal change. It is often difficult to make correlations between sections, especially in the absence of core data when using only geophysical data. In addition, not all facies are reliably identified and traceable from log data and not all have high reservoir properties. Authors made an attempt to trace the promising facies both to adjacent wells and, in general, to the entire field area using core study results and translation of these results using log and seismic data. The data showed pinching of rocks with high reservoir characteristics in the direction of the selected profile (from south to north within the field). Coastal shallow water facies, represented by Grainstones and Packstones, with high reservoir properties in the south of the field, are replaced by lagoon facies and facies of subaerial exposures, represented by Wakestones and Mudstones with low reservoir characteristics, in the north of the field. The authors suggest that this approach can be applicable for rocks both in this region and for areas with a similar structure.

Keywords: pinch-out; well data; seismic data; limestone; facies; reservoir rocks.

References

  1. Kochneva, O. E., Koskov, V. N. (2013). Lithological and facial correlation of Bashkirian carbonate deposits according to the data of field-geophysical research: Oilfield business, 9, 32-38.
  2. Andreev, A. V., Mukhametshin, V. Sh., Kotenev, Yu. A. (2016). Deposit productivity forecast in carbonate reservoirs with hard to recover reserves. SOCAR Proceedings, 3, 40-45.
  3. Kolchugin, A. N., Porta, G. D., Morozov, V. P., et al. (2020). Facies variability of pennsylvanian oilsaturated carbonate rocks (constraints from Bashkirian reservoirs of the South-East Tatarstan). Georesursy, 22(2), 29-36.
  4. Long, S., You, Y., Jiang, S., et al. (2020). Integrated characterization of ultradeep reef-shoal reservoir architecture: A case study of the Upper Permian Changxing Formation in the giant Yuanba gas field, Sichuan Basin, China. Journal of Petroleum Science and Engineering, 195, 107842.
  5. Sfidari, E., Sharifi, M., Amini, A., et al. (2021). Reservoir quality of the Surmeh (Arab-D) reservoir in the context of sequence stratigraphy in Salman Field, Persian Gulf. Journal of Petroleum Science and Engineering, 198, 108180.
  6. Soleimani, B., Zahmatkesh, I., Sheikhzadeh, H. (2020). Electrofacies analysis of the Asmari reservoir, Marun oil field, SW Iran. Geosciences Journal, 24(2), 195-207.
  7. Penna, R., Moreira Lupinacci, W. (2021). 3D modelling of flow units and petrophysical properties in brazilian presalt carbonate. Marine and Petroleum Geology, 124, 104829.
  8. Voytovich, E. D., Gatiyatullin, N. S. (2003). Tectonics of Tatarstan. Kazan University Press.
  9. Mkrtchyan, O. M. (1980). Regularities of structural forms in the east of the Russian Plate. Moscow: Science Pub.
  10. Kolchugin, A. N., Immenhauser, A., Walter, B. F., Morozov, V. P. (2016). Diagenesis of the palaeo-oilwater transition zone in a Lower Pennsylvanian carbonate reservoir: Constraints from cathodoluminescence microscopy, microthermometry, and isotope geochemistry. Marine and Petroleum Geology, 72, 45-61.
  11. Gordadze, G. N., Tikhomirov, V. I. (2005). Geochemical characteristics of oils and dispersed organic matter from the rocks of the central Volga-Ural basin: hydrocarbon biomarker data. Geochemistry International, 43(11), 1108-1123.
  12. Galimov, E. M., Kamaleeva, A. I. (2015). Source of hydrocarbons in the supergiant romashkino oilfield (Tatarstan): recharge from the crystalline basement or source sediments? European Spine Journal, 24, 95-112.
  13. Aizenshtat, Z., Feinstein, S., Miloslavski, I., et al. (1998). Oil-oil correlation and potential source rocks for oils in paleozoic reservoir rocks in the tataria and perm basins, Russia. Organic Geochemistry, 29, 701-712.
  14. Yudina, A. B., Racki, G., Savage, N.M., et al. (2002). The frasnian- famennian events in a deep-shelf succession, subpolar urals: biotic, depositional, and geochemical records. Acta Palaeontologica Polonica, 47, 355-372.
  15. Kolchugin, A. N., Morozov, V. P., Korolev, E. A., Eskin, A. A. (2014). Carbonate formation of the Lower Carboniferous in central part of Volga-Ural basin. Current Science, 107(12), 2029-2035.
  16. Proust, J. N., Chuvashov, B. I., Vennin, E., Boisseau, T. (1998). Carbonate platform drowning in a foreland setting: the mid-carboniferous platform in western Urals (Russia). Journal of Sediment Research, 68, 1175-1188.
  17. Heckel, P. (1986). Sea-level curve for Pennsylvanian eustatic marine transgressive-regressive depositional cycles along midcontinent outcrop belt, North America. Geology, 14(4), 330-334.
  18. Soreghan, G., Giles, K. (1994). Amplitudes of late Pennsylvanian glacioeustasy. Geology, 27(3), 255-258.
  19. Bishop, J. W., Montañez, I. P., Gulbranson, E. L., Brenckle, P. L. (2009). The onset of mid-Carboniferous glacio-eustasy: Sedimentologic and diagenetic constraints, Arrow Canyon, Nevada. Palaeogeography, Palaeoclimatology, Palaeoecology, 276(1-4), 217-243.
  20. Mii, H.-S., Grossman, E. L., Yancey, T. E., et al. (2001). Isotopic records of brachiopod shells from the Russian platform - evidence for the onset of mid-carboniferous glaciation. Chemical Geology, 175(1-2), 133-147.
  21. Dunham, R. J. (1962). Classification of carbonate rocks according to depositional texture. Classification of carbonate rocks /ed. Ham, W.E. In: Simposium American Association of Petroleum Geologists Members.
  22. Lucia, F. J. (2007). Carbonate reservoir characterization. Springer.
  23. Bagmanov, I., Safina, R., Platov, B., Usmanov, S. (2018). Integration of the seismic and geochemistry data to evaluate hydrocarbon potential of the carbonate reservoirs in Tatarstan, Russia. In: International Multidisciplinary Scientific GeoConference Surveying Geology and Mining Ecology Management, SGEM-18.
  24. Platov, B., Kozhevnikova, N., Shipaeva, M. (2019). The example of neural net algorithm applying for seismic facies analysis. Example from the republic of Tatarstan. In: International Multidisciplinary Scientific GeoConference Surveying Geology and Mining Ecology Management, SGEM-19.
  25. Platov, B., Safina, R., Zinjukov, R. (2018). Seismic facies analysis of the carboniferous reservoir. Case study from the Tatarstan, Russia. In: International Multidisciplinary Scientific GeoConference SGEM-18.
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DOI: 10.5510/OGP2021SI200564

E-mail: swborispl@mail.ru


I.N. Ognev, E.V. Utemov, D.K. Nurgaliev

Kazan Federal University, Kazan, Russia

The use of «native» wavelet transform for determining lateral density variation of the Volgo-Uralian subcraton


In the last two decades in conjunction with the development of satellite gravimetry, the techniques of regional-scale inverse and forward gravity
modeling started to be more actively incorporated in the construction of crustal and lithospheric scale models. Such regional models are usually built as a set of layers and bodies with constant densities. This approach often leads to a certain difference between the initially used measured gravity field and a gravity field that is produced by the model. One of the examples of this kind of models is a recent lithospheric model of the Volgo-Uralian subcraton. In the current study, we are applying the method of «native» wavelet transform to the residual gravity anomaly for defining the possible lateral density variations within the lithospheric layers of Volgo-Uralia.

Keywords: wavelet transform; gravity field inversion; forward gravity modeling; Volgo-Uralian subcraton; satellite gravimetry.

In the last two decades in conjunction with the development of satellite gravimetry, the techniques of regional-scale inverse and forward gravity
modeling started to be more actively incorporated in the construction of crustal and lithospheric scale models. Such regional models are usually built as a set of layers and bodies with constant densities. This approach often leads to a certain difference between the initially used measured gravity field and a gravity field that is produced by the model. One of the examples of this kind of models is a recent lithospheric model of the Volgo-Uralian subcraton. In the current study, we are applying the method of «native» wavelet transform to the residual gravity anomaly for defining the possible lateral density variations within the lithospheric layers of Volgo-Uralia.

Keywords: wavelet transform; gravity field inversion; forward gravity modeling; Volgo-Uralian subcraton; satellite gravimetry.

References

  1. Bogdanova, S. V., Gorbatschev, R., Garetsky, R. G. (2016). EUROPE|East European Craton /in book: Reference module in earth systems and environmental sciences. Elsevier.
  2. Bogdanova, S. V. (1986). The Earth’s crust of the Russian platform in the early precambrian (as exemplified by the Volgo-Uralian segment). Moscow: Nauka.
  3. Lozin, E. V. (2002). Depth structure and oil and gas potential of the Volga-Ural region and adjacent territories. Lithosphere, 3, 46–68.
  4. Artemieva, I. M., Thybo, H. (2013). EUNAseis: A seismic model for Moho and crustal structure in Europe, Greenland, and the North Atlantic region. Tectonophysics, 609, 97–153.
  5. Mints, M. V., Suleimanov, A. K., Babayants, P. S., et al. (2010). Deep structure, evolution and minerals of the Early Precambrian basement of the East European Platform: Interpretation of materials on the reference profile 1-EU, profiles 4B and TATSEIS. GEOKART: GEOS.
  6. Trofimov, V. A. (2006). Deep CMP seismic surveying along the Tatseis-2003 geotraverse across the Volga-Ural petroliferous province. Geotectonics, 40(4), 249-262.
  7. Ognev, I., Ebbing, J., Haas, P. (2021). Crustal structure of the Volgo-Uralian subcraton revealed by inverse and forward gravity modeling [preprint]. Solid Earth Discussions, 1-27.
  8. Haas, P., Ebbing, J., Szwillus, W. (2020). Sensitivity analysis of gravity gradient inversion of the Moho depth—A case example for the Amazonian Craton. Geophysical Journal International, 221(3), 1896–1912.
  9. Götze, H. J., Lahmeyer, B. (1988). Application of three-dimensional interactive modeling in gravity and magnetics. Geophysics, 53(8), 1096–1108.
  10. Schmidt, S., Anikiev, D., Götze, H.-J., et al. (2020). IGMAS+ – a tool for interdisciplinary 3D potential field modelling of complex geological structures. EGU General Assembly Conference Abstracts, 8383.
  11. Bouman, J., Ebbing, J., Meekes, S., et al. (2015). GOCE gravity gradient data for lithospheric modeling. International Journal of Applied Earth Observation and Geoinformation, 35, 16–30.
  12. Kerimov, V. Yu., Yandarbiev, N. Sh., Mustaev, R. N., Alieva, S. A. (2021). Features of generation, migration and accumulation of hydrocarbons in the eastern part of the Skythian Plate. SOCAR Proceedings, SI1, 4–16.
  13. Osipov, A. V., Kerimov, V. Yu., Vasilenko, E. I., onakova, A. S. (2019). Petroleum systems formation conditions in the deeply sediments in the south-east part of the Volga-Ural oil and gas province. SOCAR Proceedings, 1, 4–18.
  14. Utemov, E., Nurgaliev, D. (2004). Natural Wavelet Transformations of Gravity Data: Theory and Applications. Izvestia Physics of the Solid Earth, 41(4), 88–96.
  15. Matveeva, N., Utemov, E., Nurgaliev, D. (2015). «Native» wavelet transform for solution inverse problem of gravimetry on the spherical manifold. In: International Multidisciplinary Scientific GeoConference Surveying Geology and Mining Ecology Management, SGEM 2015.
  16. Zingerle, P., Pail, R., Gruber, T., Oikonomidou, X. (2019). The experimental gravity field model XGM2019e. GFZ Data Services.
  17. Moreau, F., Gibert, D., Holschneider, M., Saracco, G. (1997). Wavelet analysis of potential fields. Inverse Problems, 13(1), 165–178.
  18. Moreau, F., Gibert, D., Holschneider, M., Saracco, G. (1999). Identification of sources of potential fields with the continuous wavelet transform: Basic theory. Journal of Geophysical Research: Solid Earth, 104(B3), 5003–5013.
  19. Matveeva, N. A., Utemov, E. V., Nurgaliev, D. K. (2017). Determination of deep sources of anomalies of the gravitational potential of the earth on the basis of a continuous «natural» wavelet transform. In: Questions of the theory and practice of geological interpretation of geophysical fields, materials of the 44th session of the International Seminar named after D.G. Uspensky.
  20. Rabbel, W., Kaban, M., Tesauro, M. (2013). Contrasts of seismic velocity, density and strength across the Moho. Tectonophysics, 609, 437–455.
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DOI: 10.5510/OGP2021SI200565

E-mail: IgNOgnev@kpfu.ru


A.D. Dzyublo, V. V. Maslov, V. V. Sidorov, O.A. Shnip

Gubkin Russian State University of Oil and Gas, Moscow, Russia

Forecast and assessment of hydrocarbon potential of cretaceous and jurassic deposits of the Kara Sea shelf based on the results of geological exploration


According to the oil and geological zoning, the water area of the Kara Sea, including the Ob and Taz Bays, is located on the border of three oil and gas-bearing regions: Yamal, Gydan and Nadym-Purskaya, having different characteristics of oil and gas potential by section and by area. As a result of geological exploration carried out in the water area and on the adjacent land, a wide age range of oil and gas potential was revealed. Seven fields have been discovered in the waters of the Yuzhno-Kara NGO: six gas condensate fields in Cretaceous Cenomanian-Albian deposits and one oil and gas condensate field in Cretaceous and Jurassic deposits. Large gas condensate fields have been explored in the Ob and Taz bays
in the Cenomanian-Alb-Apt complex. The water area of the lips is one of the most important areas in terms of the growth of economically viable natural gas resources. According to the research results, it has been established that the UV potential of the Jurassic and Lower Cretaceous complexes of the Ob and Taz Bays is characterized as highly promising.

Keywords: Kara Sea; shelf; cretaceous and jurassic deposits.

According to the oil and geological zoning, the water area of the Kara Sea, including the Ob and Taz Bays, is located on the border of three oil and gas-bearing regions: Yamal, Gydan and Nadym-Purskaya, having different characteristics of oil and gas potential by section and by area. As a result of geological exploration carried out in the water area and on the adjacent land, a wide age range of oil and gas potential was revealed. Seven fields have been discovered in the waters of the Yuzhno-Kara NGO: six gas condensate fields in Cretaceous Cenomanian-Albian deposits and one oil and gas condensate field in Cretaceous and Jurassic deposits. Large gas condensate fields have been explored in the Ob and Taz bays
in the Cenomanian-Alb-Apt complex. The water area of the lips is one of the most important areas in terms of the growth of economically viable natural gas resources. According to the research results, it has been established that the UV potential of the Jurassic and Lower Cretaceous complexes of the Ob and Taz Bays is characterized as highly promising.

Keywords: Kara Sea; shelf; cretaceous and jurassic deposits.

References

  1. Dzyublo, A. D., Maslov, V. V., Evstafiev, I. L. (2019). Geological structure and prospects for the discovery of oil deposits in the Lower Cretaceous and Jurassic sediments of the water area of the Ob and Taz bays of the Kara Sea. Oil Industry, 1, 11-15.
  2. Kazanenkov, V. A., Ershov, S. V., Ryzhkova, S. V., et al. (2014). Geological structure and oil and gas content of regional reservoirs of the Jurassic and Cretaceous in the Kara-Yamal region and the forecast of the distribution of hydrocarbons in them. Geology of Oil and Gas, 1, 27-30.
  3. Kiryukhina, T. A., Zonn, M. S., Dzyublo, A. D. (2004). Geological and geochemical prerequisites for the oil and gas content of the Lower-Middle Jurassic and pre-Jurassic deposits in the north of Western Siberia. Geology, Geophysics and Development of Oil and Gas Fields, 8, 22-30.
  4. Melnikov, P. N., Skvortsov, M. B., Kravchenko, M. N., et al. (2019). Results of geological exploration work on the Arctic shelf of Russia in 2014–2019 and the prospects for work in the near future. Geology of Oil and Gas, 6, 5-18.
  5. Mordasova, A. B., Stupakova, A. V., Suslova, A. A., et al. (2019). Oil and gas content of the Arctic seas. Upper Jurassic and Lower Cretaceous clinoform complexes of the Barents-Kara shelf. Neftegaz.ru, 5, 26-33.
  6. Nikitin, B. A., Vovk, V. S., Zakharov, E. V., et al. (1999). Preparation of the resource base on the Arctic shelf. Gas Industry, 7, 6-10.
  7. Raikevich, A. I., Parasyna, V. S., Kholodilov, V. A., et al. (2008). Features of the geological structure and oil and gas potential of the water area of the Ob and Taz bays. Geology, Geophysics and Development, 5, 21-34.
  8. Skorobogatov, V. A., Stroganov, V. A., Kopeev, V. D. (2003). Geological structure and oil and gas content of Yamal. Moscow: Nedra.
  9. Stupakova, A. V. (2011). Structure and oil and gas content of the Barents-Kara shelf and adjacent territories. Geology of Oil and Gas, 6, 99-115.
  10. Shuster, V. L., Dzyublo, A. D., Shnip, O. A. (2020). Hydrocarbon deposits in non-anticlinal traps of the Yamal Peninsula of Western Siberia. Georesources, 22(1), 39-45.
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DOI: 10.5510/OGP2021SI200607

E-mail: dzyublo.a@gubkin.ru


A. O. Shigin1, D. A. Boreyko2, N. D. Tskhadaya2, D. Yu. Serikov3

1Siberian Federal University, Krasnoyarsk, Russia; 2Ukhta State Technical University, Ukhta, Russia; 3I.M.Gubkin Russian State University of Oil and Gas, Moscow, Russia

Comparative analysis of roller drill bit performance


Currently, roller bits are widely used in rock drilling, which are devices with rotating rollers armed with teeth. There are various approaches in assessing the effectiveness of rock destruction by a roller drilling tool, which can be conditionally divided into structural and technological ones. In addition, all the efficiency factors of the roller bit are related to the correspondence of its characteristics and the drilling process to the properties of the rock it destroys. The article analyzes the operating conditions of the roller bit during drilling of rocks of various hardness. On the example of operation of a two-screw drill bit, the process of power interaction of the toothed weapon with rock is considered depending on various factors, such as the shape and pitch of the teeth, angle of inclination, sharpness of the tooth and others. It is shown that kinematic characteristics of interaction of toothed armament with drilled rock have a significant influence on efficiency of process of face destruction.

Keywords: drill bit; drilling tool; destruction; drilling; roller cutter; rock.

Currently, roller bits are widely used in rock drilling, which are devices with rotating rollers armed with teeth. There are various approaches in assessing the effectiveness of rock destruction by a roller drilling tool, which can be conditionally divided into structural and technological ones. In addition, all the efficiency factors of the roller bit are related to the correspondence of its characteristics and the drilling process to the properties of the rock it destroys. The article analyzes the operating conditions of the roller bit during drilling of rocks of various hardness. On the example of operation of a two-screw drill bit, the process of power interaction of the toothed weapon with rock is considered depending on various factors, such as the shape and pitch of the teeth, angle of inclination, sharpness of the tooth and others. It is shown that kinematic characteristics of interaction of toothed armament with drilled rock have a significant influence on efficiency of process of face destruction.

Keywords: drill bit; drilling tool; destruction; drilling; roller cutter; rock.

References

  1. Bogomolov, R. M., Nosov, N. V. (2015). Drilling tools. Encyclopedia of inventions. Moscow: Innovative Engineering.
  2. Serikov, D. Yu. (2018). Povyshenie effektivnosti sharoshechnogo burovogo instrumenta s kosozubym vooruzheniem. Dissertaciya na soiskanie uchenoj stepeni doktora tekhnicheskih nauk. Uhta: UGTU.
  3. Egorov, N. G. (2006). Drilling wells in difficult geological conditions. Tula: IPP «Vulture and K».
  4. Tskhadaya, N. D., Khegay, V. K. (2018). On the problem of stability of rotation of the drill string in the process of destruction of rock. Construction of Oil and Gas Wells on-Land and Off-Shore, 6, 5-10.
  5. Bogomolov, R. M., Serikov, D. Yu. (2018). Improvement of the cutting structures of the rolling cutter drill bits. Equipment and Technologies for Oil And Gas Complex, 5, 24-28
  6. Serikov, D. Yu., Ishchuk, A. G., Serikova, U. S. (2018). Novaya konstrukciya opory skol'zheniya sharoshechnogo burovogo dolota. Sfera neft' i gaz, 6, 32–34.
  7. Kryukov, G. M. (2006). Physics of destruction of rocks during drilling and blasting. Moscow: Publishing house of the Moscow State Mining University, Gornaya Kniga.
  8. Neskoromnykh, V. V. (2021). Destruction of rocks during geological exploration. Krasnoyarsk: SFU.
  9. Mavlyutov, M. R. (1979). Destruction of rocks during well drilling. Moscow: Nedra.
  10. Shigin, A. O. (2015). Metodologiya proektirovaniya adaptivnyh vrashchatel'no–podayushchih organov burovyh stankov i tekhnologij ih primeneniya v slozhnostrukturnyh porodnyh massivah. Dissertaciya na soiskanie uchenoj stepeni doktora tekhnicheskih nauk. Irkutskij nacional'nyj issledovatel'skij tekhnicheskij universitet.
  11. Maniraki, A. A., Serikov, D. Yu., Ghaffanov, R. F., Serikova, U. S. (2019). The problems of selecting methods for industrial enterprises modernization. Equipment and Technologies for Oil And Gas Complex, 1, 28-33.
  12. Borejko, D. A. (2015). Povyshenie effektivnosti ocenki tekhnicheskogo sostoyaniya neftegazopromyslovyh konstrukcij neteplovymi passivnymi metodami diagnostiki. Avtoreferat dissertacii na soiskanie uchenoj stepeni kandidata tekhnicheskih nauk. Uhta: UGTU.
  13. Krec, V. G., Saruev, L. A. (2011). Burovoe oborudovanie. Tomsk: TPU.
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DOI: 10.5510/OGP2021SI200536

E-mail: diacont_dboreyko@mail.ru


S. N. Popov

Institute of Oil and Gas Problems of the Russian Academy of Sciences, Moscow, Russia

Determination of the safety factor of cement stone based on numerical modeling of the stress-strain state of the near-wellbore zone, taking into account the change in the elastic-strength properties of cement during its hardening and under the influence of an acid reagent


The results of laboratory studies of the elastic-strength properties of cement stone samples depending on the hardening time and the effect of an acid reagent, and approximated dependences of the change in the elastic modulus, Poisson's ratio and strength properties, depending on the time characteristics for two types of plugging materials are presented. A finite element scheme of the nearwellbore zone has been developed, taking into account the cement stone and the production casing. The results of numerical modeling of the stress-strain state of columns with a diameter of 146 and 178 mm, cement stone and reservoir rocks near the well based on an elastic model are presented. The analysis of the stress field for the occurrence of zones of destruction in the cement stone using the Coulomb-Mohr criterion is carried out. It is shown that, depending on the time of hardening and the effect of an acidic reagent, cement does not collapse and retains a sufficient safety factor.

Keywords: cement stone; plugging material; elastic-strength properties; near-wellbore zone; numerical model; finite element method; stress-strain state; safety factor.

The results of laboratory studies of the elastic-strength properties of cement stone samples depending on the hardening time and the effect of an acid reagent, and approximated dependences of the change in the elastic modulus, Poisson's ratio and strength properties, depending on the time characteristics for two types of plugging materials are presented. A finite element scheme of the nearwellbore zone has been developed, taking into account the cement stone and the production casing. The results of numerical modeling of the stress-strain state of columns with a diameter of 146 and 178 mm, cement stone and reservoir rocks near the well based on an elastic model are presented. The analysis of the stress field for the occurrence of zones of destruction in the cement stone using the Coulomb-Mohr criterion is carried out. It is shown that, depending on the time of hardening and the effect of an acidic reagent, cement does not collapse and retains a sufficient safety factor.

Keywords: cement stone; plugging material; elastic-strength properties; near-wellbore zone; numerical model; finite element method; stress-strain state; safety factor.

References

  1. Bulatov,A. I., Danyushevskiy, V. S. (1987). Well slurry materials. Moscow: 
  2. Kunitskikh, A. A., Chernyshov, S. E., Rusinov, D. Yu. (2014). Influence of mineral additives on the strength characteristics of the cement stone. Oil Industry, 4, 20-23.
  3. Chernyshov, S. E., Krapivina, T. N. (2010). Vliyanie rasshiryayushchih dobavok na svojstva cementnogo rastvora-kamnya. Vestnik PNIPU. Geologiya, geoinformacionnye sistemy, gorno-neftyanoe delo, 9(5), 31-33.
  4. Korobov, I. Yu., Popov, S. N. (2019). Cement types which are used during well construction and variation of physical and mechanical cement properties under experiments. Oilfield Engineering, 7, 48-56.
  5. Popov, S. N., Korobov, I. Yu. (2020). An experimental study of the variations in the physical-mechanical properties of cements, used in well construction, depending on the hardening time and influence of the clay acid reagent. Geology, Geophysics and Development of Oil and Gas Fields, 7, 55-61.
  6. Popov, S. N., Korobov, I. Yu. (2019). Experiments related to changing of elastic and strength properties of cement stone for well construction during its hardening in acid-cut clay mud. Bureniyev I Neft, 9, 34-40.
  7. Agzamov, F. A., Makhmutov, A. N., Tokunova, E. F. (2019). Study of corrosion stability of a cement stone in magnesia aggressive environment. Georesursy, 21(3), 73-78.
  8. Popov, S. N. Kusaiko, A. S. (2021). Experimental study of the effect of filtration for low-mineralized water with high temperature on changes in elastic and strength properties of reservoir rock. Springer Geology, 2, 343-349.
  9. Popov, S. N. (2015). Influence of mechanochemical effects on elastic and strength properties of reservoir rocks. Oil Industry, 8, 77-79.
  10. Zhou, S., Li, G. (2014). Research on the corrosion mechanism of CO2/H2S mixture to cement stone. SOCAR Proceedings, 2014, 2, 12-20.
  11. Kazimov, E. A., Aliyev, N. M. (2011). Research of chisel solutions interaction mechanism on rock mechanical characteristics. SOCAR Proceedings, 1, 27-29.
  12. Suleymanov, E. M., Qamidov, N. S. (2010). Problems of fastening of chinks. SOCAR Proceedings, 1, 20-23.
  13. Chuanliang, Y., Jingen, D., Baohua, Y., Jinxiang, L. (2013). Rock mechanical characteristic and wellbore stability in «Kingfisher» oilfield of Uganda. SOCAR Proceedings, 3, 25-31.
  14. Zoback, М. (2007). Reservoir geomechanics. Cambridge University Press.
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DOI: 10.5510/OGP2021SI200544

E-mail: popov@ipng.ru


N.A. Skibitskaya, I.O. Burkhanova, M.N. Bolshakov, V.A. Kuzmin, O.O. Marutyan

Oil and Gas Research Institute of the Russian Academy of Sciences, Moscow, Russia

Carbonate oil and gas source rocks wettability alteration due to influence of polymer-colloidal drilling mud


Evaluation of rock wettability is an important task, since this parameter determines the distribution of water and oil in the reservoirs and their relative and phase permeability. The reliability of evaluation the wettability of rock samples depends on the drilling-in conditions during core sampling and core sample preparation methods. The investigation of the surface properties of the core from the Orenburg oil and gas condensate field showed that using of polymer-colloidal drilling mud leads to hydrophilization of the samples' surface. To obtain information on the actual wettability values of rock samples taken from wells drilled with polymer-colloidal drilling mud a method for estimating the relative (predominant) wettability of rocks based on petrophysical and lithological studies data is proposed. The authors suggest that the extraction of oil and gas source rock samples leads to irreversible changes in surface properties that cannot be restored.

Keywords: selective wettability; relative wettability; predominant wettability; polymer-colloidal drilling mud; residual gas saturation; trapped gas saturation; pore space structure; extraction.

Evaluation of rock wettability is an important task, since this parameter determines the distribution of water and oil in the reservoirs and their relative and phase permeability. The reliability of evaluation the wettability of rock samples depends on the drilling-in conditions during core sampling and core sample preparation methods. The investigation of the surface properties of the core from the Orenburg oil and gas condensate field showed that using of polymer-colloidal drilling mud leads to hydrophilization of the samples' surface. To obtain information on the actual wettability values of rock samples taken from wells drilled with polymer-colloidal drilling mud a method for estimating the relative (predominant) wettability of rocks based on petrophysical and lithological studies data is proposed. The authors suggest that the extraction of oil and gas source rock samples leads to irreversible changes in surface properties that cannot be restored.

Keywords: selective wettability; relative wettability; predominant wettability; polymer-colloidal drilling mud; residual gas saturation; trapped gas saturation; pore space structure; extraction.

References

  1. Mihajlov, N. N., Motorova, K. A., Sechina, L. S. (2016). Geologicheskie faktory smachivaemosti porod-kollektorov nefti i gaza. Delovoj zhurnal Neftegaz.RU, 3, 80-90.
  2. Gaisin, M. R., Folomeev, A. E., Makatrov, A. K.1, et al. The measurement of Val Gamburtzeva oil field core's wettability by different methods. Oil and Gas Territory, 4, 46-53.
  3. Gudok, N. S., Bogdanovich, N. N., Martynov, V. G. (2007). Determination of the physical properties of oil-water bearing rocks. Moscow: Nedra-Business Center LLC.
  4. Gurbatova, I. P., Melekhin, S. V., Chizhov, D. B., Fairuzova, Iu. V. (2016). Features of study complex carbonate reservoir rocks` wetting using laboratory methods. Perm Journal of Petroleum and Mining Engineering, 15(20), 240-245.
  5. Kuznetsov, A. M., Kuznetsov, V. V., Bogdanovich, N. N. (2011). On the question of preserving natural wettability of a core taken from wells. Oil Industry, 1, 21-23.
  6. Latyshova, M. G., Martynov, V. G., Sokolova, T. F. (2007). Prakticheskoe rukovodstvo po interpretacii dannyh GIS. Moskva: OOO «Nedra–Biznescentr».
  7. Burkhanova, I. O. (2012). Razrabotka metodiki vyyavleniya i ocenki zapasov vysokomolekulyarnyh komponentov (VMK) zalezhej uglevodorodov po kompleksu geologo-geofizicheskih dannyh. Avtoreferat dissertacii na soiskanie uchenoj stepeni kandidata geologo-mineralogicheskih nauk. Moskva: RGU nefti i gaza im. I.M. Gubkina.
  8. Navrotskiy, O. K., Skibitskaya, N. A. (2009). Generaciya zhidkih uglevodorodov v karbonatnyh formaciyah na nizkih stadiyah katageneza. Geologiya, geografiya i global'naya energiya, 4, 6-8.
  9. Dmitrievsky, A. N., Efimov, A. G., Gutman, I. S., et al. (2018). Matrix oil and residual gas reserves of orenburg oil-gas condensate field and prospects of their development. Actual Problems of Oil and Gas, 4(23), 22.
  10. Skibitskaya, N. A., Burkhanova, I. O., Kuz'min, V. A., et al. (2016). Structure of hydrocarbon reserves of oil and gas source carbonate strata. Georesources, Geoenergetics, Geopolitics, 1(13).
  11. Khisamov, R. S., Bazarevskaya, V. G., Skibitskaya, N. A., et al. (2020). Influence of the pore space structure and wettability on residual gas saturation. Georesursy, 22(2), 2-7.
  12. Skibitskaya, N. A., Bolshakov, M. N., Kuzmin, V. A., Marutyan, O. O. (2018). The behaviours of direct-flow capillary imbibition processes in Orenburg oil-gas-condensate field productive carbonate deposits. Actual Problems of Oil and Gas, 3(22), 13.
  13. Kuz'min, V. A. (1984). Metodika i osnovnye rezul'taty izucheniya porod – kollektorov slozhnogo stroeniya na rastrovom elektronnom mikroskope. Avtoreferat dissertacii na soiskanie uchenoj stepeni kandidata geologo-mineralogicheskih nauk. Moskva: MINH i GP im. I.M. Gubkina.
  14. Bolshakov, M. N., Skibitskaya, N. A., Kuzmin, V. A. (2007). Investigation of the pore space structure by a scanning electron microscope using the computer program collector. Journal of Surface Investigation: X-Ray, Synchrotron and Neutron Techniques, 1(4), 493-496.
  15. Bagrintseva, K. I. (1982). Fracturing of sedimentary rocks. Moscow: Nedra.
  16. Khisamov, R., Skibitskaya, N., Kovalenko, K., et al. (2018, October). Well logging data interpretation in oil and gas source rock sections based on complex petrophysical and geochemical analysis results. SPE-191675-18RPTC-MC. In: SPE Russian Petroleum Technology Conference. Society of Petroleum Engineers.
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DOI: 10.5510/OGP2021SI200545

E-mail: skibitchka@mail.ru


D.S. Klimov, S.S. Ostapchuk, E.S.Zakirov

Oil and Gas Research Institute of the Russian Academy of Sciences, Moscow, Russia

Review of studies on plugging compositions creation with controlled rheological properties and the ability to restore fluidity for completion, workover and abandonment of oil and gas wells


The main purpose of cementing oil and gas wells is zonal isolation of the formations exposed by the wellbore. During the entire life of the well, there should be no uncontrolled hydraulic communication between the developed formations and the surface, regardless of the composition and type of fluid (water, oil or gas). During the operation of the well, in addition to constant static ones, the casing and cement stone also experience various dynamic loads. The article presents an up-to-date review of experimental studies on the modification of grouting compositions and cement composites capable of autonomous selfhealing due to the introduction of various additives and nanomaterials. Such modification technologies significantly increase the tightness and resistance of cement to the effects of dynamic loads, the integrity of the cement stone. As a replacement for traditional cement materials, the authors propose the creation of grouting compositions with controlled physical and mechanical properties and the possibility of their re-liquefaction under the influence of temperature on the basis of bitumen or bitumen composites.

Keywords: well plugging and abandoning; self-healing materials; autonomous self-healing; casing durability; impermeability of the cement stone; self-healing cement; bitumen and bitumen composites.

The main purpose of cementing oil and gas wells is zonal isolation of the formations exposed by the wellbore. During the entire life of the well, there should be no uncontrolled hydraulic communication between the developed formations and the surface, regardless of the composition and type of fluid (water, oil or gas). During the operation of the well, in addition to constant static ones, the casing and cement stone also experience various dynamic loads. The article presents an up-to-date review of experimental studies on the modification of grouting compositions and cement composites capable of autonomous selfhealing due to the introduction of various additives and nanomaterials. Such modification technologies significantly increase the tightness and resistance of cement to the effects of dynamic loads, the integrity of the cement stone. As a replacement for traditional cement materials, the authors propose the creation of grouting compositions with controlled physical and mechanical properties and the possibility of their re-liquefaction under the influence of temperature on the basis of bitumen or bitumen composites.

Keywords: well plugging and abandoning; self-healing materials; autonomous self-healing; casing durability; impermeability of the cement stone; self-healing cement; bitumen and bitumen composites.

References

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  14. Salehi, S., Ali, N., Khattak, M. J., Rizvi, H. (2016, September). Geopolymer composites as efficient and economical plugging materials in peanuts price oil market. SPE-181426-MS. In: SPE Annual Technical Conference and Exhibition. Society of Petroleum Engineers.
  15. Yıldırım, G., Khiavi, A. H., Yeşilmen, S., Şahmaran, M. (2018). Self-healing performance of aged cementitious composites. Cement & Concrete Composites, 87, 172-186.
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  17. Yan, P., Zhou, Y., Yang, Z., et al. (2007). Microstructure formation and degradation mechanism of cementitious plugging agent slurries. Journal of Wuhan University of Technology-Mater. Sci. Ed., 22, 61–65.
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  19. Araújo, M., Chatrabhuti, S., Gurdebeke, S., et al. (2018). Poly(methyl methacrylate) capsules as an alternative to the “proof-of-concept” glass capsules used in self-healing concrete. Cement and Concrete Composites, 89, 260-271.
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  21. Van Tittelboom, K., De Belie, N., Van Loo, D., Jacobs, P. (2011). Self-healing efficiency of cementitious materials containing tubular capsules filled with healing agent. Cement and Concrete Composites, 33(4), 497–505.
  22. Thao, T. D. P. (2011). Quasi-brittle self-healing materials: numerical modelling and applications in civil engineering. Ph.D. dissertation. Singapore: National University of Singapore.
  23. Yuan, B., Yang, Y., Wang, Y., Zhang, K. (2017). Self-healing efficiency of EVA-modified cement for hydraulic fracturing wells. Construction and Building Materials, 146, 563-570.
  24. Abdulfarraj, M., Imqam, A. (2020). The potential of using micro-sized crosslinked polymer gel to remediate water leakage in cement sheaths. Journal of Petroleum Exploration and Production Technology, 10, 871–881.
  25. Hu, M., Guo, J. (2019). Application of ion-responsive hydrogel in self-healing of oil well cement sheath. In: Proceedings of the International Petroleum and Petrochemical Technology Conference. IPPTC 2019. Singapore: Springer.
  26. Lu, Z., Kong, X., Yang, R., et al. (2016). Oil swellable polymer modified cement paste: Expansion and crack healing upon oil absorption. Construction and Building Materials, 114, 98-108.
  27. Zhang, R., Mao, X., Zhao, Z. (2019). Synthesis of oil-swelling material and evaluation of its selfhealing effect in cement paste. Polymer-Plastics Technology and Materials, 58(6), 618-629.
  28. Cavanagh, P. H., Johnson, C. R., Le Roy-Delage, et al. (2007, February). Self-healing cement – novel technology to achieve leak-free wells. SPE-105781-MS. In: SPE/IADC Drilling Conference. Society of Petroleum Engineers.
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  31. Jia, H., Chen, H., Zhao, J.-Z. (2020). Development of a highly elastic composite gel through novel intercalated crosslinking method for wellbore temporary plugging in high-temperature reservoirs. SPE Journal, 25, 2853–2866.
  32. Soliman, A. H., Fathallah, M. O., Tobeh, S. M., et al. (2015, October). A cross link polymer sealant for curing severe lost circulation events in fractured limestone formations. SPE-176533-MS. In: SPE Russian Petroleum Technology Conference. Society of Petroleum Engineers
  33. Ziad, A. B., Gromakovskii, D., Al-Sagr, A., et al. (2016, February). First successful application of temporary gel plug replacing calcium carbonate chips to isolate depleted reservoir, case study from Saudi Arabia gas field. SPE-178986-MS. In: SPE International Conference and Exhibition on Formation Damage Control. Society of Petroleum Engineers.
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  35. Singh, A. K., Patil, B., Kishore, K., et al. (2015, April). Casing leak investigation & successful repair by application of pressure activated liquid sealant in a newly completed well in offshore environment—a case study. SPE-173826-MS. In: SPE Bergen One Day Seminar. Society of Petroleum Engineers.
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DOI: 10.5510/OGP2021SI200546

E-mail: seydem@mail.ru


M. I. Korabelnikov1, S. N. Bastrikov2, N. A. Aksenova1

1Tyumen Industrial University, Branch in Nizhnevartovsk, Russia; 2Tyumen Industrial University, Tyumen, Russia

The technical solution to reduce the cost of eliminating the seizure of the drill string in the well


The analysis of the nonproductive time when drilling wells is conducted in the paper. it is established that the most of it is associated with the accidents and complications, with the main share (60%)-seizures. The statistical analysis of the reasons for the occurrence of seizures and the effectiveness of methods for their elimination is presented. A drill string disconnector (RBC) developed at the Tyumen Industrial University is proposed for unscrewing drill pipes and freeing them from trapped pipes.

Keywords: well; drill pipes; accidents; seizure; drilling tool; drill string break.

The analysis of the nonproductive time when drilling wells is conducted in the paper. it is established that the most of it is associated with the accidents and complications, with the main share (60%)-seizures. The statistical analysis of the reasons for the occurrence of seizures and the effectiveness of methods for their elimination is presented. A drill string disconnector (RBC) developed at the Tyumen Industrial University is proposed for unscrewing drill pipes and freeing them from trapped pipes.

Keywords: well; drill pipes; accidents; seizure; drilling tool; drill string break.

References

  1. (2018). «Tools for sidetracking» «BITTEKHNIKA» LLC. www.bittekhnika.ru
  2. Serikov, D. J., Jasashin, V. A., Mikhajlov, J. V., et al. (2011). Disconnector. RU Patent 2428557.
  3. Nagumanov, M. M., Aminev, M. Kh. (2011). Disconnecting device of string in well. RU Patent 2437999.
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DOI: 10.5510/OGP2021SI200555

E-mail: na-acs@yandex.ru


A.K. Raptanov1, V.V. Ruzhenskyi1, B.I. Kostiv1, M.A. Myslyuk2, V.M. Charkovskyy2

1LLC DTEK Oil & Gas, Kyiv, Ukraine; 2Ivano-Frankivsk National Technical University of Oil and Gas, Ivano-Frankivsk, Ukraine

Analysis of the deep drilling technology in unstable formations at the Semyrenky gas condensate field


The paper presents a general overview of deep drilling in unstable formations at the Semyrenky gas condensate field of the Dnipro-Donetsk Trough, including well design, bottom hole assemblies (BHA), drilling conditions, and drilling muds. Problems encountered during drilling for production casing of Wells 72- and 75-Semyrenky using high-speed drilling methods are analyzed. The relationships between the rate of penetration and disturbed rock stability, volume excess and depth, as well as consistent empirical patterns in changes in mud properties and depth are established. With these technical and economic performance indicators for well drilling are given, elements of a borehole stability management strategy were defined, the principles of mud selection for drilling through problem zones are validated. The paper discusses the requirements to a mud hydraulics program to reduce the erosion of borehole walls, specific borehole preparation techniques, such as reaming and gauging, for drilling in problem zones, and alternative options to ensure borehole stability.

Keywords: borehole stability; statistical models; hole gauging; hole geometry; drilling mud; BHA.

The paper presents a general overview of deep drilling in unstable formations at the Semyrenky gas condensate field of the Dnipro-Donetsk Trough, including well design, bottom hole assemblies (BHA), drilling conditions, and drilling muds. Problems encountered during drilling for production casing of Wells 72- and 75-Semyrenky using high-speed drilling methods are analyzed. The relationships between the rate of penetration and disturbed rock stability, volume excess and depth, as well as consistent empirical patterns in changes in mud properties and depth are established. With these technical and economic performance indicators for well drilling are given, elements of a borehole stability management strategy were defined, the principles of mud selection for drilling through problem zones are validated. The paper discusses the requirements to a mud hydraulics program to reduce the erosion of borehole walls, specific borehole preparation techniques, such as reaming and gauging, for drilling in problem zones, and alternative options to ensure borehole stability.

Keywords: borehole stability; statistical models; hole gauging; hole geometry; drilling mud; BHA.

References

  1. Voytenko, V. S. (1990). Applied geomechanics in drilling. Moscow: Nedra.
  2. Seid-Rza, M. K., Faradzhev, T. G., Gasanov, R. A. (1991). Prevention of complications in the kinetics of drilling processes. Moscow: Nedra.
  3. Mitchell, R. F. (2007). Petroleum engineering handbook. Volume II: Drilling Engineering. Houston: SPE.
  4. Kazimov, E. A., Aliyev, N. M. (2011). Research of chisel solutions interaction mechanism on rock mechanical characteristics. SOCAR Proceedings, 1, 27-29.
  5. Chuanliang, Y., Jingen, D., Baohua, Y., Jinxiang, L. (2013). Rock mechanical characteristic and wellbore stability in «Kingfisher» oilfield of Uganda. SOCAR Proceedings, 3, 25-30.
  6. Shirali, I. Y. (2020). Assessment of the stability of wellbore rocks during their dynamic loading. SOCAR Proceedings, 2, 17-22.
  7. Luban, Yu. V., Luban, S. V. (2017). «Geosynthesis engineering» scientific developments for increasing drilling efficiency and wells productivity. Internetional Conference GeoDrilling II. Drilling and Reservoir Opening. Poltava: FOP Govorov S.V.
  8. Myslyuk, M. A., Dolyk, R. N., Raptanov, А. К., Lazarenko, А. G. (2016). Estimation of bottom-hole assemblies efficiency when drilling deep wells on the Semerenky gas-condensate field. Bureniye i neft, 12, 022 – 027.
  9. Myslyuk, M. A., Salyzhyn I. (2012). The evaluation of rheological parameters of non-Newtonian fluids by rotational viscosimetry. Applied Rheology, 22(3), 32381.
  10. Myslyuk, M. A., Raptanov, А. К., Bogoslavets, V. V., et al. (2020). About the change in drilling fluids technological properties when drilling wells in unstable deposits. Construction of Oil and Gas Wells on-Land and off-Shore, 11(335), 023-030.
  11. Ganjumyan, R. A. (1986). Practical calculations in exploratory drilling. Moscow: Nedra.
  12. Zoback, M. D. (2006). Reservoir geomechanics. NewYork: Cambridge University Press.
  13. Myslyuk, M. A., (2009). On the assessment of the removal ability of the drilling fluid when drilling wells. Construction of Oil and Gas Wells on-Land and off-Shore, 2, 29–32.
  14. Mims M., Krepp T., Williams H. (1999). Design and drilling for wells with large deviations from vertical and complex wells. Houston: K&M Technology Group, LLK.
  15. Myslyuk, M. A., Rybchych, І.J., Yaremіychuk, R.S. (2004). Drilling of the wells. V. 5. Problems. Fishing. Ecology. Kyiv: Іnterpres LTD.
  16. Ishchenko, I.M., Selvashchuk, A.P., Luzhkov, L.L. (1989). Wellbore buckling prediction in plastic rock on gas condensate fields of Eastern Ukraine. Moskow: VNIIEGazprom.
  17. Griguleckiy, V.G., Lukyanov, V.T. (1990). Designing the bottom hole assembly. Moskow: Nedra.
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DOI: 10.5510/OGP2021SI200573

E-mail: mmyslyuk@ukr.net


R.I. Ganiev1, Luc Deboer2, A.H. Agliullin3, R.A. Ismakov1

1Ufa State Petroleum Technological University, Ufa, Russia; 2Dual Gradient Systems LLC, Texas, USA; 3Center for Engineering Technologies LLC, Moscow, Russia

Dual gradient drilling: a pilot test of decanter centrifuge for CAPM technology


The article is about problem of drilling deepwater oil and gas wells that consists in complicating and increasing cost of their well design due to narrowing mud window at different depths. The authors analyse drilling technology developed and applied in practice of offshore drilling with a dual gradient drilling, which allows drilling significant intervals without overlapping an intermediate casing string. Based on analysis of these technologies and taking into account their disadvantages the authors proposed and tested a new drilling technology of dual gradient drilling with placement of all necessary innovative equipment on drilling platform.

Keywords: managed pressure drilling; deepwater drilling; offshore drilling; dual gradient drilling; riser; oil and gas exploration in sea.

The article is about problem of drilling deepwater oil and gas wells that consists in complicating and increasing cost of their well design due to narrowing mud window at different depths. The authors analyse drilling technology developed and applied in practice of offshore drilling with a dual gradient drilling, which allows drilling significant intervals without overlapping an intermediate casing string. Based on analysis of these technologies and taking into account their disadvantages the authors proposed and tested a new drilling technology of dual gradient drilling with placement of all necessary innovative equipment on drilling platform.

Keywords: managed pressure drilling; deepwater drilling; offshore drilling; dual gradient drilling; riser; oil and gas exploration in sea.

References

  1. Bogoyavlensky, V. I. (2012). Prospects and problems for development of oil and gas fields in Arctic shelf. Drilling
    and Oil, 11, 4-9.
  2. Volkov, V. V, Shmal, G. I. (2019). Why does Bazhen skid? Drilling and Oil, 7-8, 3-8.
  3. Mirzoev, D. A. (2021). Principal features of the continental shelf oil and gas resources development. SOCAR Proceedings, 1, 78-82.
  4. Petrenko, V. E., Mirzoyev, D. A., Chernikov, B. V., et al. (2019). The concept of creating information support for continental shelf oil and gas fields development projects. SOCAR Proceedings, 4, 73-80.
  5. Chernukhiv, V. I. (2005). Development of technology for drilling wells with managed pressure drilling. PhD dissertation. Stavropol.
  6. Krivolapov, D., Magda, A., Soroka, T. (2020, October). Managed pressure drilling as an advanced solution for deep hthp wells and long intervals with narrow safe pressure limits. SPE-202510-MS, 2020. In: SPE Annual Caspian Technical Conference, Virtual. Society of Petroleum Engineers.
  7. Smith, J. R. (2004). Dual density drilling fluid systems to enhance deepwater drilling. Presentation at Louisiana State University.
  8. Ganiev, R. I., Luc DeBoer, Agliullin, A. K., Ismakov, R. A. (2019). Dual gradient drilling as a way to reduce costs of construction of deepwater wells. Association of Drilling Contractors Journal, 4(55), 2-7.
  9. Ganiev, R. I., Luc de Boer. (2020). Dual gradient drilling in deep water wells. ROGTEC Russian Oil and Gas Technologies, 61, 24-37.
  10. Peterman, C. P. (1998). Riserless and mudlift drilling – the next steps in deepwater drilling. In: Offshore Technology Conference, Houston.
  11. Forrest, N., Bailey, T., Hannegan, D. (2001, February-March). Sub sea equipment for deep water drilling using dual gradient mud system. SPE-67707-MS. In: SPE/IADC Drilling Conference. Society of Petroleum Engineers.
  12. (2013). IADC «DGD System Attributes» presentation in meeting of IADC Dual Gradient Drilling Workshop, Houston.
  13. de Boer, L. (2003). Method and apparatus for varying the density in drilling fluids in deep water oil drilling applications. US Patent 6536540.
  14. de Boer, L. (2003). DGS dual gradient drilling system. Presentation in meeting of the Drilling Engineering Association, Houston.
  15. de Boer, L. (2010). Drill string flow control valve and methods of use. US Patent 8534369.
  16. Ganiev, R. I., Luc DeBoer, Agliullin, A. K., Ismakov, R. A. (2021). Dual gradient drilling: U-tube effect in upper intervals of deep water wells. ROGTEC Russian Oil and Gas Technologies, 65, 58-68.
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DOI: 10.5510/OGP2021SI200585

E-mail: radmirganiev@mail.ru


K.V. Moiseev1,2, A.I. Popenov2, R.N. Bakhtizin2

1Mavlutov Institute of Mechanics, Ufa, Russia; 2Ufa State Petroleum Technological University, Ufa, Russia

Express method for the testing of tribotechnical properties of lubricants


The paper presents the results of experimental study of the tribotechnical properties of lubricants on a unit that simulates the geometric, kinematic and force similarity of well drilling conditions. Bearings with different radial clearances and the same chemical-thermal treatment were investigated. Data registration was carried out on cathode, loop oscilloscopes and electronic recorders. The load on the bearing, the moment of rolling resistance on the journal, and the angular speed of rotation of the outer race were recorded. The temperature was registered using artificial and semiartificial thermocouples. A strobotachometer was used to determine the portable speed of the rolling bodies. The external appearance of all rolling elements was investigated, metallographic analysis of thin surface layers of all rolling elements was carried out, mathematical processing of test results was carried out. It is shown that for the express assessment of the tribotechnical properties of lubricants, the amplitude value of the oscillation of the rolling resistance moment can be used.

Keywords: friction; lubrication; tribotechnical Properties; drilling.

The paper presents the results of experimental study of the tribotechnical properties of lubricants on a unit that simulates the geometric, kinematic and force similarity of well drilling conditions. Bearings with different radial clearances and the same chemical-thermal treatment were investigated. Data registration was carried out on cathode, loop oscilloscopes and electronic recorders. The load on the bearing, the moment of rolling resistance on the journal, and the angular speed of rotation of the outer race were recorded. The temperature was registered using artificial and semiartificial thermocouples. A strobotachometer was used to determine the portable speed of the rolling bodies. The external appearance of all rolling elements was investigated, metallographic analysis of thin surface layers of all rolling elements was carried out, mathematical processing of test results was carried out. It is shown that for the express assessment of the tribotechnical properties of lubricants, the amplitude value of the oscillation of the rolling resistance moment can be used.

Keywords: friction; lubrication; tribotechnical Properties; drilling.

References

  1. Bowden, F. P., Tabor, D. (1950). The friction and lubrication of solids. London: Oxford University Press.
  2. Kragelskii, I. V. (1982). Friction and wear. Elmsford: Pergamon Press.
  3. Kostecki, B. I. (1970). Friction, lubrication and wear in the machinery. Kiev: Engineering.
  4. Garkunov, D. N. (1985). Tribotechnics. Moscow: Mashinostroenie.
  5. Erdemir, A., Martin, J. M. (2007). Superlubricity. Amsterdam: Elsevier.
  6. Mang, T., Dresel, W. (2007). Lubricants and Lubrication. Wiley-VCH Verlag GmbH & Co, Weinheim.
  7. Rudnick, L. R. (2017). Lubricant additives: chemistry and applications. CRC Press.
  8. Ilyasov, A. M., Moiseev, K. V., Urmancheev, S. F. (2005). Numerical simulation of thermoconvection in a liquid for the case when viscosity is a quadratic function of temperature. Journal of Applied and Industrial Mathematics, 8(4), 51–59.
  9. Moiseev, K. V., Volkova, E. V., Urmancheev, S. F. (2013). Effect of convection on polymerase chain reaction in a closed cell. Procedia IUTAM, 8, 172-175.
  10. Kuleshov, V. S., Moiseev, K. V., Khizbullina, S. F., et al. (2018). Convective flows of anomalous thermoviscous fluid. Mathematical Models and Computer Simulations, 10(4), 529–537.
  11. Kuleshov, V. S., Moiseev, K. V., Urmancheev, S. F. (2019). Isolated convection modes for the anomalous thermoviscous liquid in a plane cell. Fluid Dynamics, 54, 983–990.
  12. Moiseev, K. V., Kuleshov, V. S., Bakhtizin, R. N. (2020). Free convective of a linear heterogeneous liquid in a square cavity at side heating. SOCAR Proceedings, 4, 108-116.
  13. Popenov, A. I. (1973). Investigation of factors determining the wear resistance of roller bits. PhD Thesis. UNI.
  14. Mavlutov, M. R., Popenov, A. I. (1980). Oil and gas studies. Moscow: Nedra.
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DOI: 10.5510/OGP2021SI200586

E-mail: constgo@mail.ru


L. P. Kalacheva, I. K. Ivanova, A. S. Portnyagin, I. I. Rozhin, K. K. Argunova, A. I. Nikolaev

Institute of Oil and Gas Problems of the Siberian Branch of the Russian Academy of Sciences, Yakutsk, Russia

Determination of the lower boundaries of the natural gas hydrates stability zone in the subpermafrost horizons of the Yakut arch of the Vilyui syneclise, saturated with bicarbonate-sodium type waters


This paper considers the possibility of the underground gas storage facilities creating in a hydrate state on the north-western slope of the Yakut arch of the Vilyui syneclise. For this, the boundaries of the hydrate stability zone were determined for 6 promising areas of the considered geological structure. Equilibrium conditions of the natural gas hydrates formation in the model porous media containing bicarbonate-sodium type water (mineralization 20 g/l), characteristic for the subpermafrost horizons of the Yakut arch, have been studied by the method of differential thermal analysis. On the basis of the obtained results, the boundaries of the natural gas hydrates stability zone were determined. It was shown that the upper boundaries of the hydrate stability zone are located in the thickness of permafrost rocks. It was found that the lower boundaries of the natural gas hydrates stability zone in moist unsalted porous medium lie in the range from 930 to 1120 m. When the samples are saturated with mineralized water, the boundaries are located 80-360 m higher. The obtained experimental results allow us to conclude that in subpermafrost aquifers of the Yakut arch has favorable conditions for the formation of natural gas hydrates.

Keywords: natural gas hydrates; aquifers; underground gas storage; hydrate stability zone; geothermal gradient; equilibrium conditions of the hydrate formation; bicarbonate-sodium type water.

This paper considers the possibility of the underground gas storage facilities creating in a hydrate state on the north-western slope of the Yakut arch of the Vilyui syneclise. For this, the boundaries of the hydrate stability zone were determined for 6 promising areas of the considered geological structure. Equilibrium conditions of the natural gas hydrates formation in the model porous media containing bicarbonate-sodium type water (mineralization 20 g/l), characteristic for the subpermafrost horizons of the Yakut arch, have been studied by the method of differential thermal analysis. On the basis of the obtained results, the boundaries of the natural gas hydrates stability zone were determined. It was shown that the upper boundaries of the hydrate stability zone are located in the thickness of permafrost rocks. It was found that the lower boundaries of the natural gas hydrates stability zone in moist unsalted porous medium lie in the range from 930 to 1120 m. When the samples are saturated with mineralized water, the boundaries are located 80-360 m higher. The obtained experimental results allow us to conclude that in subpermafrost aquifers of the Yakut arch has favorable conditions for the formation of natural gas hydrates.

Keywords: natural gas hydrates; aquifers; underground gas storage; hydrate stability zone; geothermal gradient; equilibrium conditions of the hydrate formation; bicarbonate-sodium type water.

References

  1. https://www.cedigaz.org/underground-gas-storage-in-the-world-2020-status/
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  5. Bondarev, E. A., Rozhin, I. I., Popov, V. V., Argunova, K. K. Assessment of possibility of natural gas hydrates underground storage in permafrost regions. Kriosfera Zemli, XIX(4), 64-74.
  6. Bondarev, E. A., Rozhin, I. I., Popov, V. V., Argunova, K. K. (2015). Mathematical modeling of natural gas underground storage in hydrate state. SOCAR Proceedings, 2, 54-67.
  7. Duchkov, A. D., Sokolova, L. S., Ayunov, D. E., Permyakov, M. E. (2009). Assesment of potential of West Siberian permafrost for the carbon dioxide storage. Earth's Cryosphere, 13(4), 62-68.
  8. Shagapov, V. Sh., Musakaev, N. G. (2016). Dynamics for generation and decomposition of hydrates in systems of production, transportation and storage of gas. Moscow: Nauka.
  9. Veluswamy, H. P., Kumar, A., Seo, Y., et al. (2018). A review of solidified natural gas (SNG) technology for gas storage via clathrate hydrates. Applied Energy, 216, 262-285.
  10. Dolgaev, S. I., Kvon, V.G., Istomin, V. A., et al. (2018). Comparative economic study of hydrate transportation technology. Vesti Gazovoy Nauki, 1(33), 100-116.
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  12. Shirota, H., Ota, S. (2011). Experiments on self-preservation property & dissociation limit temperature of methane hydrate pellets for sea-borne transport of natural gas hydrate. 2-nd report. In: Proceedings of the 7th International Conference on Gas Hydrates.
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  14. Rehder, G., Eckl, R., Elfgen, M., et al. (2012). Methane hydrate pellet transport using the selfpreservation effect: a techno-economic analysis. Energies, 5, 2499-2523.
  15. Watanabe, S., Takahashi, S., Mizubayashi, H., et al. (2008). A demonstration project of NGH land transportation system. In: Proceedings of the 6th International Conference on Gas Hydrates.
  16. Shibata, T., Yamachi, H., Ohmura, R., Mori, Y. H. (2012). Engineering investigation of hydrogen storage in the form of a clathrate hydrate: Conceptual designs of underground hydrate-storage silos. International Journal of Hydrogen Energy, 37, 7612-7623.
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  21. Rossi, F., Gambelli, A.M. (2021). Thermodynamic phase equilibrium of single-guest hydrate and formation data of hydrate in presence of chemical additives: a review. Fluid Phase Equilibria, 36, 12958.
  22. Semenov V.P. (2018). Geotemperaturnoe pole i kriolitozona Vilyujskoj sineklizy. Dissertaciya na soiskanie uchenoj stepeni kandidata geologo-mineralogicheskih nauk. Yakutsk: SO RAN. Institutmerzlotovedeniya im. V.P. Mel'nikova.
  23. Zheleznyak, M.N., Semenov, V.P. (2020). Geotemperaturnoe pole i kriolitozona Vilyujskoj sineklizy. Novosibirsk: Izd-vo SO RAN.
  24. Duchkov, A. D., Zheleznyak, M. N., Sokolova, L. S., Semenov, V. P. (2019). Methane and carbon dioxide hydrate stability zones in the sedimentary cover of the vilyui syneclise. Kriosfera Zemli, XXIII(6). 19-26.
  25. Carev, V.P. (1976). Osobennosti formirovaniya, metody poiska i razrabotki skoplenij uglevodorodov v usloviyah vechnoj merzloty. Yakutsk: YAkutskoe knizhnoe izdatel'stvo.
  26. Bubnov, A.V., Sidorov, D.P., Carev, V.P., CHerskij, N.V. (1973). Perspektivy gazonosnosti otlozhenij verhnej chasti osadochnogo chekhla Vilyujskoj sineklizy i Predverhoyanskogo progiba /v knige «Issledovaniya i rekomendacii po sovershenstvovaniyu razrabotki poleznyh iskopaemyh severnyj i vostochnyh rajonov SSSR». Yakutsk: Yakutskoe knizhnoe izdatel'stvo.
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  32. Pravkin, S. A., Bolshiyanov, D. Yu., Pomortsev, O, A., et al. (2018). The relief, structure and age of quaternary deposits of the valley of the Lena river in the Yakutian bend. Vestnik of Saint Petersburg University. Earth Sciences, 63(2), 209–229.
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  36. Wright, J. F., Dallimore, S. R., Nixon, F.M. (1999). Influences of grain size and salinity on pressure-temperature thresholds for methane hydrate stability. In: Scientific Results front JAPEX/JNOC/GSC Mallik 2L-38 Gas Hydrate Research Well, Mackenzie Delta, Northwest Territories, Canada. Geological Survey of Canada.
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  39. Tao, Y., Yan, K., Li, X., et al. (2020). Effects of Salinity on Formation Behavior of Methane Hydrate in Montmorillonite. Energies, 13(231), 15.
  40. Lee, J., Chun, M. K., Lee, K. M., et al. (2002). Phase equilibria and kinetic behavior of CO2 hydrate in electrolyte and porous media solutions: application to ocean sequestration of CO2. Korean Journal of Chemical Engineering, 19, 673-678.
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  43. Kalacheva, L. P., Portnyagin, A. S., Solovyeva, S. A. (2020). Research of formation and decomposition processes of natural gas hydrates of different composition in model stratum waters of a bicarbonate-sodium type. In: IOP Conference Series: Earth and Environmental Science, 459(4), 052069.
  44. Kalacheva, L. P., Ivanova, I. K., Portnyagin, A. S. (2021). Equilibrium conditions of the natural gas hydrates formation in the pore space of dispersed rocks. In: IOP Conference Series: Earth and Environmental Science, 666(4), 042062.
  45. Kalacheva, L. P., Rozhin, I. I., Fedorova, A. F. The study of the stratum water mineralization influence on the hydrate formation process of the natural gas from the East Siberian platform fields. SOCAR Proceedings, 2, 56-71.
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DOI: 10.5510/OGP2021SI200549

E-mail: lpko@mail.ru


D. A. Kaushanskiy1,2, N. R. Bakirov1,2, V. B. Demyanovskiy1,2

1Institute of Oil and Gas Problems of the Russian Academy of Sciences, Moscow; 2Research and Technology Company Atombiotech LLC, RF, Moscow

Study of core strength characteristics as an indicator of the volume distribution of the Temposcreen-Plus polymer-gel system


Filtration experiments are widely used in the oil and gas industry. They are used to determine the key physical and chemical characteristics of the porous medium, the parameters of fluid filtration. Also, filtration experiments are the main method for evaluating the residual resistance factor for compositions that are used in water shut-off technologies. However, filtration studies are not sufficient to study the distribution of the filtrate over the volume of the porous medium. This paper describes a method for using strength characteristics studies to evaluate the distribution of the polymer-gel system "Temposcreen-Plus" in the pore volume of the core after filtration. A method for representing core strength data in the form of a visualized image of the hardness distribution on a color scale is also proposed.

Keywords: strength characteristics; hardness; core; "Temposcreen-Plus"; filtration experiments; visualization.

Filtration experiments are widely used in the oil and gas industry. They are used to determine the key physical and chemical characteristics of the porous medium, the parameters of fluid filtration. Also, filtration experiments are the main method for evaluating the residual resistance factor for compositions that are used in water shut-off technologies. However, filtration studies are not sufficient to study the distribution of the filtrate over the volume of the porous medium. This paper describes a method for using strength characteristics studies to evaluate the distribution of the polymer-gel system "Temposcreen-Plus" in the pore volume of the core after filtration. A method for representing core strength data in the form of a visualized image of the hardness distribution on a color scale is also proposed.

Keywords: strength characteristics; hardness; core; "Temposcreen-Plus"; filtration experiments; visualization.

References

  1. Gimatudinov, S. K. (1971). Physics of oil and gas reservoirs. Moscow: Nedra.
  2. Kaushanskiy, D. A., Demyanovskiy, V. B., Bakirov, N. R., et al. (2019). Field trial results of water shut-off in oil producing wells using the Temposcreen-Plus technology in Rn-Purneftegas LLC. Oil Industry, 6, 78-82.
  3. Kaushansky, D. A., Demyanovsky, V. B. (2018). Innovative water suppression technology for production wells «Temposcreen-Plus». Actual Problems of Oil and Gas, 1(20), 22.
  4. (2016). GOST 24621-2015 (ISO 868:2003). Plastics and ebonite. Determination of indentation hardness by means of a durometer (Shore hardness). Moscow: Standartinform.
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DOI: 10.5510/OGP2021SI200550

E-mail: dak@ipng.ru


N. N. Mikhailov1,2, L. S. Sechina2

1Gubkin Russian State University of Oil and Gas (National Research University), Moscow, Russia; 2Oil and Gas Research Institute of the Russian Academy of Sciences, Moscow, Russia

Microstructural wettability of oil and gas condensate zones of the Karachaganak field


The Karachaganak field is represented by gas condensate and oil zones, a convenient object for studying changes in microstructural wettability during the transition from one zone to another. Microstructural wettability was characterized by a hydrophobization coefficient, Ѳн, which determines the proportion of the pore surface area occupied by adsorbed hydrocarbons. It was found that Ѳн of the samples of the gas and gas condensate zones is the same (on average 0.140), the oil zone - on average 0.250. Analysis of the IR spectra of extracted hydrocarbons showed that the microstructural wettability of the oil zone contains more aromatic, aliphatic, oxidized and sulfur-containing structures and fewer branched structures than in the gas condensate zone. The microstructural wettability of carbonate reservoirs depends on the hydrocarbon composition of the adsorbed oil.

Keywords: microstructural wettability; hydrophobic coefficient; hydrocarbons; spectral coefficients.

The Karachaganak field is represented by gas condensate and oil zones, a convenient object for studying changes in microstructural wettability during the transition from one zone to another. Microstructural wettability was characterized by a hydrophobization coefficient, Ѳн, which determines the proportion of the pore surface area occupied by adsorbed hydrocarbons. It was found that Ѳн of the samples of the gas and gas condensate zones is the same (on average 0.140), the oil zone - on average 0.250. Analysis of the IR spectra of extracted hydrocarbons showed that the microstructural wettability of the oil zone contains more aromatic, aliphatic, oxidized and sulfur-containing structures and fewer branched structures than in the gas condensate zone. The microstructural wettability of carbonate reservoirs depends on the hydrocarbon composition of the adsorbed oil.

Keywords: microstructural wettability; hydrophobic coefficient; hydrocarbons; spectral coefficients.

References

  1. Cuiec, L. E. (1990). Evaluation of reservoir wettability and its effect on oil recovery /In: Interfacial phenomena in oil recovery, N.R. Morrow (ed.). New York: Marcell Dekker.
  2. Mikhailov, N. N., Sechina, L. S., Mikhailov, A. N. (2017). Microstructural wettability of carbonate gas-condensate saturated collectors. Geology, Geophysics and Development of Oil and Gas Fields, 8, 45–51.
  3. Mikhailov, N. N., Ermilov, O. M., Sechina, L. S., Menshikova, D. S. (2020). Influence of the component composition of adsorbed oil on the microstructural wettability of hydrocarbon reservoirs. Doklady Earth Sciences, 496(2), 1-6.
  4. Kuzmin, V. A., Mikhaylov, N. N., Skibitskaya, N. A., et al. (2015). Results of the electronmicroscopic research on the impact of microstructural factors of reservoir space on the oil saturation pattern. Geology of Oil and Gas, 3, 34-44.
  5. Mikhailov, N. N., Semenova, N. A., Sechina, L. S. (2011). The influence of microstructure wetting on the petrophysical characteristics of the reservoir rocks. Karotazhnik, 7, 163-172.
  6. Anderson, W. G. (1986). Wettability literature survey - Part 1: Rock/oil/drine interacnions and the effects of core handling on wettability. Journal of Petroleum Technology, 38, 1125-1144.
  7. Tankaeva, L. K., Dmitrievskij, A. N., Sechina, L. S., Privalenko, N. V. (1983). Sposob opredeleniya stepeni gidrofobizacii poverhnosti por. Avtorskoe svidetel'stvo SSSR 1022005.
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DOI: 10.5510/OGP2021SI200551

E-mail: folko200@mail.ru


D.S. Filippova, V.E. Stolyarov, E.A. Safarova

Oil and Gas Research Institute of the Russian Academy of Sciences, Moscow, Russia

Features of monitoring storage of methane-hydrogen mixtures


The storage of methane-hydrogen mixtures (MHM) in existing underground gas storage facilities (UGS) is a prerequisite for the development of a "carbonneutral" strategy of the Russian Federation. The use of technologies for storage and delivery of MHM in industrial volumes should be ensured by experimental research, the creation of a regulatory framework and the introduction of modern methods for maintaining the operational reliability of the existing Unified Gas Transportation System (UGSS). The need for scientific and project work is determined by the peculiarities of the storage of MHM and the assessment of the likelihood of negative technogenic and mechanical consequences during the operation of the equipment. The materials provide the main risk models of the processes that arise in the case of hybrid storage of MHM. The use of cluster technology for storage and transportation of MHM is proposed, and the need to ensure constant monitoring of the component composition of gas as part of the implementation of an integrated automated flow technology is shown.

Keywords: methane-hydrogen mixtures; hydrogen energy; underground gas storage; hardware control; risks.

The storage of methane-hydrogen mixtures (MHM) in existing underground gas storage facilities (UGS) is a prerequisite for the development of a "carbonneutral" strategy of the Russian Federation. The use of technologies for storage and delivery of MHM in industrial volumes should be ensured by experimental research, the creation of a regulatory framework and the introduction of modern methods for maintaining the operational reliability of the existing Unified Gas Transportation System (UGSS). The need for scientific and project work is determined by the peculiarities of the storage of MHM and the assessment of the likelihood of negative technogenic and mechanical consequences during the operation of the equipment. The materials provide the main risk models of the processes that arise in the case of hybrid storage of MHM. The use of cluster technology for storage and transportation of MHM is proposed, and the need to ensure constant monitoring of the component composition of gas as part of the implementation of an integrated automated flow technology is shown.

Keywords: methane-hydrogen mixtures; hydrogen energy; underground gas storage; hardware control; risks.

References

  1. Abukova, L. A., Filippova, D. S., Safarova, E. A., et al. (2021). Hydrogeochemical and microbiological features of ugs in the aspect of hybrid storage of natural gases. In: EAGE Conference Proceedings. https://doi.org/10.3997/2214-4609.202150116
  2. Ajanovic, A., Haas, R. (2018). Economic prospects and policy framework for hydrogen as fuel in the transport sector. Energy Policy, 123, 280–288.
  3. Aksyutin, O. E., Ishkov, A. G., Romanov, K. V. i dr. (2017). Potencial metano-vodorodnogo topliva v usloviyah perekhoda k nizkouglerodnoj ekonomike. Gazovaya promyshlennost', S1(750), 82–85.
  4. Amid, A., Mignard, D., Wilkinson, M. (2016). Seasonal storage of hydrogen in a depleted natural gas reservoir. International Journal of Hydrogen Energy, 41, 5549–5558.
  5. Barsuk, N. E., Khaydina, M. P., Khan, S. A. (2018). “Green” gas in the European gas transportation system. Gas Industry, 10, 104–109.
  6. Bedel, L., Junker, M. (2006, June). Natural gas pipelines for hydrogen transportation. In: Proceedings of the WHEC Conference Session, Lyon, France.
  7. Caglayan, D. G., Weber, N., Heinrichs, H. U., et al. (2020). Technical potential of salt caverns for hydrogen storage in Europe. International Journal of Hydrogen Energy, 45, 6793–6805.
  8. Fekete, J. R., Sowards, J. W., Amaro, R. L. (2015). Economic impact of applying high strength steels in hydrogen gas pipelines. International Journal of Hydrogen Energy, 40, 10547–10558.
  9. Hagemann, B., Rasoulzadeh, M., Panfilov, M., et al. (2015). Mathematical modeling of unstable transport in underground hydrogen storage. Environmental Earth Sciences, 73, 6891-6898.
  10. Henkel, S., Pudlo, D., Werner, L., et al. (2014). Mineral reactions in the geological underground induced by H2 and CO2 injections. Energy Procedia, 6, 8026-8035.
  11. Luboń, K., Tarkowski, R. (2020). Numerical simulation of hydrogen injection and withdrawal to and from a deep aquifer in NW Poland. International Journal of Hydrogen Energy, 45, 2068–2083.
  12. Lurie, М. V. (2021). Transportation of hydrogen through natural gas pipelines using the batch method. Oil and Gas Territory, 3-4, 86-92.
  13. Nemati, B., Mapar, M., Davarazar, P., et al. (2020). A sustainable approach for site selection of underground hydrogen storage facilities using fuzzy-delphi methodology. Journal of Settlements and Spatial Planning, 6, 5–16.
  14. Panfilov, M. (2010). Underground storage of hydrogen: in situ selforganisation and methane generation. Transport in Porous Media, 85(3), 841-865.
  15. Panfilov, M. (2016). Underground and pipeline hydrogen storage /in: Gupta, R.B., Basile, A., Veziroglu, T.N., eds. «Compendium of hydrogen energy». Vol. 2. Hydrogen storage. Distribution and infrastructure. Woodhead Publishing.
  16. Stolyarov, V. E., Monakova, A. S., Safarova, E. A., Filippova, D. S. (2021). Automatization features of industrial hydrogen production and storage. Automation, Telemechanization and Communication in Oil Industry, 3, 18–26.
  17. Tarkowski, R. (2017). Perspectives of using the geological subsurface for hydrogen storage in Poland. International Journal of Hydrogen Energy, 42, 347–355.
  18. Tarkowski, R. (2019). Underground hydrogen storage: Characteristics and prospects. Renewable and Sustainable Energy Reviews, 105, 86–94.
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DOI: 10.5510/OGP2021SI200552

E-mail: safarova@ipng.ru


M. I. Korabelnikov, S. N. Bastrikov, N. A. Aksenova, A. T. Khudaiberdiev

Tyumen Industrial University, branch in Nizhnevartovsk, Russia

The research and development of technical and technological solutions for the operation of oil wells with increased gas content


In the practice of oil production, there are oil deposits with high values of gas content (gas factor), from tens to hundreds of cubic meters of gas per one ton of oil produced. Gas dissolved in oil and coming from the reservoir into the well along with the liquid phase (oil, water), under certain thermodynamic conditions, is capable of forming hydrates, which complicate the operation of downhole pumping equipment, reduce the efficiency of pumps and well flow rate. The formation of gas hydrate plugs in the well requires the total overhaul, which leads to an increase in non-productive time, financial costs and an increase in lost profits on lost oil. Considered in the article technologies and devices that prevent the formation of gas hydrates in marginal wells with a high gas content in oil have shown their unreliability and low efficiency. The authors propose for the consideration a new effective technology for the operation of such wells, which makes it possible to avoid the formation of hydrates.

Keywords: well; gas content; hydrates; production; oil; valve; coupling; pump.

In the practice of oil production, there are oil deposits with high values of gas content (gas factor), from tens to hundreds of cubic meters of gas per one ton of oil produced. Gas dissolved in oil and coming from the reservoir into the well along with the liquid phase (oil, water), under certain thermodynamic conditions, is capable of forming hydrates, which complicate the operation of downhole pumping equipment, reduce the efficiency of pumps and well flow rate. The formation of gas hydrate plugs in the well requires the total overhaul, which leads to an increase in non-productive time, financial costs and an increase in lost profits on lost oil. Considered in the article technologies and devices that prevent the formation of gas hydrates in marginal wells with a high gas content in oil have shown their unreliability and low efficiency. The authors propose for the consideration a new effective technology for the operation of such wells, which makes it possible to avoid the formation of hydrates.

Keywords: well; gas content; hydrates; production; oil; valve; coupling; pump.

References

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  2. Adonin, A. N. (1964). Processes of deep pumping oil production. Moscow: Nedra.
  3. Korabel'nikov, M. I., Junisbekov, M. Sh. (2016). Analysis and ways of increasing the efficiency of artificial oil lift from marginal wells in a down economy. Bulletin of South Ural State University. Series: Power Engineering, 16(1), 75-79.
  4. Carroll, J. J. (2003). Natural gas hydrates: a Guide for engineers. Amsterdam: Gulf Professional Publishing.
  5. Boxall, J., Greaves, D., Mulligan, J. (2008, July). Gas hydrate formation and dissociation from water-in oil emulsions. In: Proceedings of the 6th International Conference on Gas Hydrates (ICGH 2008). Vancouver, British Columbia.
  6. Sloan, E. D., Dend, J. E., Koh, C. (2008). Clathrate hydrates of natural gases. Taylor & Francis, CRC Press.
  7. Fedorov, K. M., Vershinin, V. E., Khabibullin, R. A., Varavva, A. I. (2013). Assessment of hydrate formation depth in the oil wells located in permafrost zones. Tyumen State University Herald, 7, 74-80.
  8. Bakhir, S. J., Latypov, T. M., Kosintsev, V. V. (2010). Method of oil withdrawal from high gas content well and electroloading equipment for it. RU Patent 2380521.
  9. Timashev, A. T., Zaripov A. G., Zijakaev Z. N., Minazov R. R. (1998). Method and device for lifting gas-liquid mixture in wells. RU Patent 2114282.
  10. Duplikhin, V. G. (1997). Method of oil recovery. RU Patent 2078910.
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  12. Zhil'tsov, V. V., Demidov, V. P., Dudarev, A. V., et al. (2005). Method for operating well by electric down-pump with frequency-adjusted drive. RU Patent 2250357.
  13. Krichke, V. O., Krichke, V. V. (1999). Method of automatic control of operating conditions of well equipped with submersible electrical centrifugal pump. RU Patent 2140523.
  14. Illjuk, N. I., Chabaev, L. U., Kovalenko, S. A. (2001). Process of restoration of wells unfit for further use. RU Patent 2176724.
  15. Isaev, G. A. (2012). Fluid pumping-out methods by using electric-centrifugal pump equipment and electric-centrifugal pump gas seperator equipment. RU Patent 2442023.
  16. Ljapkov, P. D., Drozdov, A. N., Igrevskij, V. I., et al. (1995). Method for fluid pumping-out by oil-well pump and gas separator of centrifugal oil-well pump. RU Patent 2027912.
  17. Annenkov, V. I., Bulavin, V. D., Vlasov, S. A., et al. (1999). Method for destruction of hydrateice, asphaltene-resin and paraffin depositions in well provided with sucker rod pump. RU Patent 2137908.
  18. Korabelnikov, M. I., Korabelnikov, A. M. (2018). Oil with high gas content production method from wells and device for its implementation. RU Patent 2667182.
  19. Mishchenko, I. T. (2003). Well oil production. Moscow: «Oil and Gas» Gubkin Russian State University of Oil and Gas.
  20. Bagautdinov, A. K., Barkov, S. L., Belevich, G. K., et al. (1996). Geology and development of the largest and unique oil and gas fields. Vol. 2. Moscow: VNIIOENG.
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DOI: 10.5510/OGP2021SI200557

E-mail: na-acs@yandex.ru


S.V. Kolesnik1, E.S. Shangin2

1Industrial University of Tyumen, Tyumen, Russia; 2Nizhnevartovsk State University, Nizhnevartovsk, Russia

Economic method of oil production based on electrophoresis


Electrophoresis can be considered as a fundamentally new method of lifting oil without the use of producing wells and mechanical devices, with the help of which it is supposed to organize oil extraction from explored fields with a reduction in its cost by 70-80%. The source of electricity for the implementation of the proposed method of oil recovery based on electrophoresis can be a method of autonomous generation of electricity based on atmospheric electricity. This method is based on the operation of a natural generator consisting of the Earth, the atmosphere, the ionosphere and the Earth›s magnetic field.The proposed energy source is simple in design, convenient to use. As a result, the resulting energy is very cheap and environmentally friendly. The use of such an installation can be carried out in any area of the Earth.

Keywords: oil production; electrophoresis; electric field; atmospheric electricity; carbon; the cost of lifting oil.

Electrophoresis can be considered as a fundamentally new method of lifting oil without the use of producing wells and mechanical devices, with the help of which it is supposed to organize oil extraction from explored fields with a reduction in its cost by 70-80%. The source of electricity for the implementation of the proposed method of oil recovery based on electrophoresis can be a method of autonomous generation of electricity based on atmospheric electricity. This method is based on the operation of a natural generator consisting of the Earth, the atmosphere, the ionosphere and the Earth›s magnetic field.The proposed energy source is simple in design, convenient to use. As a result, the resulting energy is very cheap and environmentally friendly. The use of such an installation can be carried out in any area of the Earth.

Keywords: oil production; electrophoresis; electric field; atmospheric electricity; carbon; the cost of lifting oil.

References

  1. Zakirov, S. N., Zakirov, E. S., Indrupsky, I. M. (2016). On regulatory documents in oil and gas subsurface use. Oil Industry, 10, 6-9.
  2. Bilibin, S. I., Dyakonova, T. F., Isakova, T. G., et al. (2015). Algorithms for determining the calculation parameters of deposits of the Bazhenov formation for the Salym group of deposits. Scientific and Technical Bulletin of Rosneft Oil Company, 2, 9-17.
  3. Kroit, G. (1955). Science of colloids. Moscow: Izdatelstvo Inostrannnoy Literatury.
  4. Dukhin, S. S., Deryagin B. V. (1976). Electrophoresis. Moscow: AN SSSR, Institut fizchimii.
  5. Newman, J. (1977). Electrochemical systems. Moscow: Mir.
  6. Vernadsky, V. I. (1967). Biosphere. Moscow: Mysl.
  7. Shangin, E. S. (2002). A method of oil production and a device for its implementation. RU Patent 2184838.
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DOI: 10.5510/OGP2021SI200567

E-mail: kolesniksv@bk.ru


D. M. Kuzina, Ch. Yuan, D. K. Nurgaliev, D. A. Emelianov, M. A. Varfolomeev, A. V. Bolotov, I. F. Minhanov

Kazan Federal University, Kazan, Russia

Effect of in-situ combustion process on the magnetic properties and composition of rock


In-situ combustion (ISC) is a proved, effective method for enhanced oil recovery (EOR). In our previous work, we studied the feasibility of ISC process for heavy oil recovery in Nurlat Oil Field (Tatneft oil company, Russia) regarding to oil recovery, in-situ oil upgrading, stability of combustion front, etc. In this work, we investigated the effect of ISC process on the rock properties and composition. We found that magnetic minerals can be in-situ formed in rock during combustion process of oils. The formation of magnetic minerals in rock depends on temperature, heating time, and oil environment. Based on the magnetic properties, the samples can be divided into the most heated, less heated, and nonheated ones with hydrocarbons. The changes in the magnetic properties of rock can be used for developing technologies for combustion front monitoring, which is very valuable for controlling ISC process and its adjustment.

Keywords: magnetic properties; thermomagnetic analysis; enhanced oil recovery; in-situ combustion; rock.

In-situ combustion (ISC) is a proved, effective method for enhanced oil recovery (EOR). In our previous work, we studied the feasibility of ISC process for heavy oil recovery in Nurlat Oil Field (Tatneft oil company, Russia) regarding to oil recovery, in-situ oil upgrading, stability of combustion front, etc. In this work, we investigated the effect of ISC process on the rock properties and composition. We found that magnetic minerals can be in-situ formed in rock during combustion process of oils. The formation of magnetic minerals in rock depends on temperature, heating time, and oil environment. Based on the magnetic properties, the samples can be divided into the most heated, less heated, and nonheated ones with hydrocarbons. The changes in the magnetic properties of rock can be used for developing technologies for combustion front monitoring, which is very valuable for controlling ISC process and its adjustment.

Keywords: magnetic properties; thermomagnetic analysis; enhanced oil recovery; in-situ combustion; rock.

References

  1. Sarathi, P. S. (1999). In-situ combustion handbook - principles and practices. Bartleville, Oklahoma: BDM petroleum Tchnologies.
  2. Yuan, C., Emelianov, D. A., Varfolomeev, M. A., Abaas, M. (2019). Comparison of oxidation behavior of linear and branched alkanes. Fuel Processing Technology, 188, 203–211.
  3. Yuan, C., Emelianov, D. A., Varfolomeev, M. A., et al. (2021). Mechanistic and kinetic insight into catalytic oxidation process of heavy oil in in-situ combustion process using copper (II) stearate as oil soluble catalyst. Fuel, 284, 118981
  4. Hascakir, B., Ross, C. M., Castanier, L. M., Kovscek, A. R. (2013). Fuel formation and conversion during in-situ combustion of crude oil. SPE Journal, 18(6), 1217–1228.
  5. Yuan, C., Varfolomeev, M. A., Emelianov, D. A., et al. (2018). Copper stearate as a catalyst for improving the oxidation performance of heavy oil in in-situ combustion process. Applied Catalysis A: General, 564, 79–89.
  6. Zhao, S., Pu, W., Varfolomeev, M. A., et al. (2018). Low-temperature oxidation of light and heavy oils via thermal analysis: kinetic analysis and temperature zone division. Journal of Petroleum Science and Engineering, 168, 246–255.
  7. Yuan, C., Emelianov, D. A., Varfolomeev, M. A. (2018). Oxidation behavior and kinetics of light, medium, and heavy crude oils characterized by thermogravimetry coupled with fourier transform infrared spectroscopy. Energy and Fuels, 32(4), 5571–5580.
  8. Yuan, C., Emelianov, D. A., Varfolomeev, M. A., et al. (2018). Oxidation behavior and kinetics of eight C20-C54 n-alkanes by high pressure differential scanning calorimetry (HP-DSC). Energy and Fuels, 32(7), 7933–7942.
  9. Yuan, C., Sadikov, K., Varfolomeev, M., et al. (2020). Low-temperature combustion behavior of crude oils in porous media under air flow condition for in-situ combustion (ISC) process. Fuel, 259, 116293.
  10. Pu, W., Zhao, S., Hu, L., et al. (2020). Thermal effect caused by low temperature oxidation of heavy crude oil and its in-situ combustion behavior. Journal of Petroleum Science and Engineering, 184, 106521.
  11. Yuan, C., Emelianov, D. A., Varfolomeev, M. A., Abaas, M. (2019). Combustion behavior of aromatics and their interaction with n-alkane in in-situ combustion enhanced oil recovery process: thermochemistry. Journal of Industrial and Engineering Chemistry, 76, 467–475.
  12. Varfolomeev, M. A., Rakipov, I. T., Isakov, D. R., et al. (2015). Characterization and kinetics of Siberian and Tatarstan regions crude oils using differential scanning calorimetry. Petroleum Science and Technology, 33(8), 865–871.
  13. Varfolomeev, M. A., Galukhin, A., Nurgaliev, D. K., Kok, M. V. (2016). Thermal decomposition of Tatarstan Ashal’cha heavy crude oil and its SARA fractions. Fuel, 186, 122–127.
  14. Kok, M. V., Gundogar, A. S. (2010). Effect of different clay concentrations on crude oil combustion kinetics by thermogravimetry. Journal of Thermal Analysis and Calorimetry, 99(3), 779–783.
  15. Ariskina, K. A., Yuan, C., Abaas, M., et al. (2020). Catalytic effect of clay rocks as natural catalysts on the combustion of heavy oil. Applied Clay Science, 193, 105662.
  16. Ariskina, K. A., Abaas, M., Yuan, C., et al. (2020). Effect of calcite and dolomite on crude oil combustion characterized by TG-FTIR. Journal of Petroleum Science and Engineering, 184, 106550.
  17. Ismail, N. B., Hascakir, B. (2020). Impact of asphaltenes and clay interaction on in-situ combustion performance. Fuel, 268, 117358.
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  21. Shokrlu, H. Y., Maham, Y., Tan, X., et al. (2013). Enhancement of the efficiency of in situ combustion technique for heavy-oil recovery by application of nickel ions. Fuel, 105, 397–407.
  22. Mehrabi-Kalajahi, S., Varfolomeev, M. A., Yuan, C., et al. (2021). Improving heavy oil oxidation performance by oil-dispersed CoFe2O4 nanoparticles in In-situ combustion process for enhanced oil recovery. Fuel, 285, 119216.
  23. Mehrabi-Kalajahi, S., Varfolomeev, M. A., Yuan, C., et al. (2021). Oil-dispersed ƒ¿-Fe2O3 nanoparticles as a catalyst for improving heavy oil oxidation. Energy and Fuels, 35(13), 10498-10511.
  24. Bazargan, M., Kovscek, A. R. (2015). A reaction model-free approach for in situ combustion calculations: 1-kinetics prediction. Transport in Porous Media, 107(2), 507-525.
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DOI: 10.5510/OGP2021SI200568

E-mail: di.kuzina@gmail.com


I. F. Minkhanov, A. V. Bolotov, R. N. Sagirov, M. A. Varfolomeev, O. V. Anikin, A. R. Tazeev, V. K. Derevyanko

Kazan Federal University, Kazan, Russia

The influence of the content of clay minerals on the efficiency of steam treatment injection for the bitumen oils recovery


Globally, for the development of bitumen oils thermal steam treatment is considered, since this technology is considered the most effective, but it has a number of problems with the presence of clay minerals in the rock. When clay minerals come into contact with steam they swell, leading to a decrease in the permeability of the reservoir, and therefore a decrease in the final oil recovery. This work assesses the influence of clay mineralization content on the degree of oil displacement under thermal steam treatment by conducing filtration experiments. Steam injection experiments containing low oil saturations of less than 2% resulted in no oil displacement. A solvent based on aliphatic and polar fragments was tested to extract oil in such low-oil saturated systems.

Keywords: steam injection; bitumen oil; clay minerals; solvent; oil displacement.

Globally, for the development of bitumen oils thermal steam treatment is considered, since this technology is considered the most effective, but it has a number of problems with the presence of clay minerals in the rock. When clay minerals come into contact with steam they swell, leading to a decrease in the permeability of the reservoir, and therefore a decrease in the final oil recovery. This work assesses the influence of clay mineralization content on the degree of oil displacement under thermal steam treatment by conducing filtration experiments. Steam injection experiments containing low oil saturations of less than 2% resulted in no oil displacement. A solvent based on aliphatic and polar fragments was tested to extract oil in such low-oil saturated systems.

Keywords: steam injection; bitumen oil; clay minerals; solvent; oil displacement.

References

  1. Ahmad, K. M., Kristály, F., Turzo, Z. (2018). Effects of clay mineral and physico-chemical variables on sandstone rock permeability. Journal of Oil, Gas & Petrochemical Sciences, 1(1), 18-26.
  2. Mukhtanov, B. M. (2021). Application of thermal methods in the Republic of Kazakhstan. Current projects and prospects. SOCAR Proceedings, 1, 114-123.
  3. Kudrashou, V. Y., Nasr-El-Din, H. A. (2020). Formation damage associated with mineral alteration and formation of swelling clays caused by steam injection in sandpacks. SPE Reservoir Evaluation and Engineering, 23(1), 326–344.
  4. Bennion, D. B., Thomas, F. B., Sheppard, D. A. (1992, February). Formation damage due to mineral alteration and wettability changes during hot water and steam injection in clay-bearing sandstone reservoirs. SPE-23783-MS. In: Symposium on Formation Damage Control held in Lafayette. Society of Petroleum Engineers.
  5. Gunter, W. D., Zhou, Z., Perkins, R. H. (1994). Modelling formation damage caused by kaolinite from 25 to 300 °C in the oil sand reservoirs of Alberta. SPE Advanced Technology Series, 2(2), 206-213.
  6. Zhuang, Y., Liu, X., Xiong, H., Liang, L. (2018). Microscopic mechanism of clay minerals on reservoir damage during steam injection in unconsolidated sandstone. Energy & Fuels, 32(4), 4671–4681.
  7. Day, J. J., Huitt, J. L. (1967). Laboratory study of rock softening and means of prevention during steam or hot water injection. Journal of Petroleum Technology, 19(05), 703–711.
  8. Jain, A. K., Ahmed, K., Ferdous, H., et al. (2016, March). An experimental investigation of steam induced permeability changes in clay bearing formation of North Kuwait. SPE-179762-MS. In: SPE EOR Conference at Oil and Gas West Asia. Society of Petroleum Engineers.
  9. Minkhanov, I. F., Bolotov, A. V., Al-Muntaser, A. A., et al. (2021). Experimental study on the improving the efficiency of oil displacement by co-using of the steam-solvent catalyst. Oil Industry, 6, 54-57.
  10. Varfolomeev, M. A., Yuan, Ch., Bolotov, A. V., et al. (2021). Effect of copper stearate as catalysts on the performance of in-situ combustion process for heavy oil recovery and upgrading. Journal of Petroleum Science and Engineering, 207, 109125.
  11. Minkhanov, I. F., Marvanov, M. M., Bolotov, A. V., et al. (2020). Improvement of heavy oil displacement efficiency by using aromatic hydrocarbon solvent. International Multidisciplinary Scientific GeoConference: SGEM 20, 1(2), 711-718.
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DOI: 10.5510/OGP2021SI200569

E-mail: minkhanovi@mail.ru


I.I. Mukhamatdinov1, E.E. Giniyatullina1, R.E. Mukhamatdinova1, O.V. Slavkina2, K.A. Shchekoldin2, A.V. Vakhin1

1Kazan Federal University, Kazan, Russia; 2LLC «RITEK», Volgograd, Russia

Evaluation of the aquathermolysis catalyst effect on the composition and properties of high-viscosity oil from the Strelovskoe field


The article examines the aquathermolysis process of high viscosity oil from Strelovskoe field developed by RITEK LLC using steam injection. Laboratory modeling of non-catalytic and catalytic aquathermolysis in a high-pressure reactor was performed. Laboratory tests have demonstrated the high efficiency of the iron-based oil-soluble catalyst developed at Kazan Federal University in the destruction reactions of resinous asphaltenes. Samples of the initial oil as well as products of non-catalytic and catalytic aquathermolysis in the presence of iron tallate and the solvent Asphalt-Resin-Paraffin Deposits were studied at temperatures of 200, 250 and 300°C for 24 hours. In addition, the gas composition of the oil aquathermolysis products and the viscosity-temperature characteristics of the oil samples were determined. The studies have shown that catalytic aquathermolysis has a significant effect on the changes in the composition and properties of oil from the Strelovskoe field. It was found that the presence of a catalyst contributes to decarboxylation reactions, increases the degree of desulfurization and decreases the viscosity of oil samples.

Keywords: high-viscosity oil; aquathermolysis; catalyst precursor; steam thermal treatment; viscosity.

The article examines the aquathermolysis process of high viscosity oil from Strelovskoe field developed by RITEK LLC using steam injection. Laboratory modeling of non-catalytic and catalytic aquathermolysis in a high-pressure reactor was performed. Laboratory tests have demonstrated the high efficiency of the iron-based oil-soluble catalyst developed at Kazan Federal University in the destruction reactions of resinous asphaltenes. Samples of the initial oil as well as products of non-catalytic and catalytic aquathermolysis in the presence of iron tallate and the solvent Asphalt-Resin-Paraffin Deposits were studied at temperatures of 200, 250 and 300°C for 24 hours. In addition, the gas composition of the oil aquathermolysis products and the viscosity-temperature characteristics of the oil samples were determined. The studies have shown that catalytic aquathermolysis has a significant effect on the changes in the composition and properties of oil from the Strelovskoe field. It was found that the presence of a catalyst contributes to decarboxylation reactions, increases the degree of desulfurization and decreases the viscosity of oil samples.

Keywords: high-viscosity oil; aquathermolysis; catalyst precursor; steam thermal treatment; viscosity.

References

  1. Maity, S. K., Ancheyta, J., Marroquín, G. (2010). Catalytic aquathermolysis used for viscosity reduction of heavy crude oils: a review. Energy & Fuels, 24, 2809–2816.
  2. Pevneva, G. S., Voronetskaya, N. G., Sviridenko, N. N. (2020). Cracking of maltenes of naphthenic petroleum in the presence of WC/Ni–Cr. Petroleum Chemistry, 60, 373–379.
  3. Pevneva, G. S., Voronetskaya, N. G., Sviridenko, N. N., Golovko, A. K. (2020). Effect of WC/Ni–Cr additive on changes in the composition of an atmospheric residue in the course of cracking. Petroleum Science, 17, 499–508.
  4. Sviridenko, N. N., Vosmerikov, A. V., Agliullin, M. R., Kutepov, B. I. (2020) General features of catalytic upgrading of karmalskoe heavy oil in the presence of amorphous aluminosilicates. Petroleum Chemistry, 60, 384–391.
  5. Sviridenko, N. N., Golovko, A. K., Kirik, N. P., Anshits, A. G. (2020). Upgrading of heavy crude oil by thermal and catalytic cracking in the presence of NiCr/WC catalyst. Journal of the Taiwan Institute of Chemical Engineers, 112, 97–105.
  6. Muraza, O., Galadima, A. (2015). Aquathermolysis of heavy oil: A review and perspective on catalyst development. Fuel, 157, 219–231.
  7. Hyne, J. B. (1986) Aquathermolysis: a synopsis of work on the chemical reaction between water (steam) and heavy oil sands during simulated steam stimulation. Edmonton, Alberta: AOSTRA Library and Information Service.
  8. Mukhamatdinov, I. I., Khaidarova, A. R., Zaripova, R. D., et al. (2020). The composition and structure of ultra-dispersed mixed oxide (II, III) particles and their influence on in-situ conversion of heavy oil. Catalysts, 10, 114.
  9. Vakhin, A. V., Aliev, F. A., Mukhamatdinov, I. I., et al. (2020). Catalytic aquathermolysis of Boca de Jaruco heavy oil with nickel-based oil-soluble catalyst. Processes, 8, 532.
  10. Khelkhal, M. A., Eskin, A. A., Mukhamatdinov, I. I., et al. (2019). A comparative kinetic study on heavy oil oxidation in the presence of nickel tallate and cobalt tallate. Energy & Fuels, 33(9), 9107-9113.
  11. Valiyev, N. A., Jamalbayov, M. А., Ibrahimov, Kh. M., Hasanov, I. R. (2021). On the prospects for the use of CO2 to enhance oil recovery in the fields of Azerbaijan. SOCAR Proceedings, 1, 83–89.
  12. Shamilov, V. M. (2020). Potential applications of carbon nanomaterials in oil recovery. SOCAR Proceedings, 3, 90–107.
  13. Sitnov, S. A., Mukhamatdinov, I. I., Vakhin, A. V., et al. (2018). Composition of aquathermolysis catalysts forming in situ from oil-soluble catalyst precursor mixtures. Journal of Petroleum Science and Engineering, 169, 44-50.
  14. Shadrina, P. N. (2017). Improvement of technologies for combating asphalt-resin-paraffin deposits on oilfield equipment of high-viscosity oil fields. dissertation. Thesis of PhD. Ufa: Ufa State Petroleum Technical University.
  15. Mukhamatdinov, I. I., Giniyatullina, E. E., Mukhamatdinova, R. E., et al. (2021) Effect of an aquathermolysis catalyst on the in-situ transformation of high-viscosity oil from the Strelovskoe field in the Samara region. Oil and Gas New Features, 3, 38-42.
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DOI: 10.5510/OGP2021SI200570

E-mail: iimuhamatdinov@gmail.com


F. A. Aliev1, A. A. Kiekbaev1, D. V. Andreev3, A. V. Mitroshin3, A. A. Akkuzhin4, A. V. Sharifullin2, A. V. Vakhin1

1Kazan Federal University, Kazan, Russia; 2Kazan National Research Technological University, Kazan, Russia; 3LUKOIL-Engineering limited. PermNIPIneft Branch office in Perm, Perm, Russia; 4LLC LUKOIL-Komi, Usinsk, Russia

The effect of clay minerals on conversion of Yarega heavy oil during catalytic aquathermolysis process


In this study we present the results of physical stimulation of in-situ aquathermolysis process carried out on heavy crude oil sample from Yarega (Russia) oil field in the presence of nickel/iron tallates and clay minerals. The experimental results revealed that clay minerals as the co-catalyst show the best performance at 300 °C in case of nickel tallates, where the viscosity of aquathermolysis products reduces by 4 times in contrast to the initial crude oil. Moreover, the content of saturated fraction isolated from the catalytic aquathermolysis products increased from 36.8 to 50.2 in contrast to the saturated fraction of initial crude oil, while the amount of resins decreased by two times after hydrothermal treatment in the presence of nickel catalyst and clay minerals. Thus, the obtained results justify the involvement of clay minerals to the aquathermolysis process and demonstrate catalytic performance in terms of enhancing group composition and viscosity reduction.

Keywords: heavy oil; upgrading; catalysts; aquathermolysis; clay minerals; transition metals; SARA; rheology.

In this study we present the results of physical stimulation of in-situ aquathermolysis process carried out on heavy crude oil sample from Yarega (Russia) oil field in the presence of nickel/iron tallates and clay minerals. The experimental results revealed that clay minerals as the co-catalyst show the best performance at 300 °C in case of nickel tallates, where the viscosity of aquathermolysis products reduces by 4 times in contrast to the initial crude oil. Moreover, the content of saturated fraction isolated from the catalytic aquathermolysis products increased from 36.8 to 50.2 in contrast to the saturated fraction of initial crude oil, while the amount of resins decreased by two times after hydrothermal treatment in the presence of nickel catalyst and clay minerals. Thus, the obtained results justify the involvement of clay minerals to the aquathermolysis process and demonstrate catalytic performance in terms of enhancing group composition and viscosity reduction.

Keywords: heavy oil; upgrading; catalysts; aquathermolysis; clay minerals; transition metals; SARA; rheology.

References

  1. Sitnov, S., Mukhamatdinov, I., Aliev, F., et al. (2020). Heavy oil aquathermolysis in the presence of rock-forming minerals and iron oxide (II, III) nanoparticles. Petroleum Science and Technology, 38(6), 574-579.
  2. Feyzullayev, K. A., Aliyev, I. M. (2014). The influence of composition of hydrocarbon mixture on condensate recovery in the development of depletion method. SOCAR Proceedings, 3, 71-76.
  3. Aliev, F. A., Mukhamatdinov, I. I., Sitnov, S. A., et al. (2021). In-situ heavy oil aquathermolysis in the presence of nanodispersed catalysts based on transition metals. Processes, 9, 127.
  4. Minkhanov, I. F., Bolotov, A. V., Al-Muntaser, A. A., et al. (2021). Experimental study on the improving the efficiency of oil displacement by co-using of the steam-solvent catalyst. Oil Industry, 6, 54-57.
  5. Mukhamatdinov, I. I., Sitnov, S. A., Slavkina, O. V., et al. (2019). The aquathermolysis of heavy oil from Riphean-Vendian complex with iron-based catalyst: FT-IR spectroscopy data. Petroleum Science and Technology, 37(12), 1410-1416.
  6. Yuan, P., Liu, H., Liu, D., et al. (2013). Role of the interlayer space of montmorillonite in hydrocarbon generation: An experimental study based on high temperature–pressure pyrolysis. Applied Clay Science, 75, 82–91.
  7. Vossoughi, S., Willhite, G., El Shoubary, Y., Bartlett, G. (1983). Study of the clay effect on crude oil combustion by thermogravimetry and differential scanning calorimetry. Journal of Thermal Analysis and Calorimetry. 27, 17–36.
  8. Ranjbar, M. (1993). Influence of reservoir rock composition on crude oil pyrolysis and combustion. Journal of Analytical and Applied Pyrolysis, 27, 87–95.
  9. Zheng, R., Liao, G., You, H., et al. (2020). Montmorillonite-catalyzed thermal conversion of lowasphaltene heavy oil and its main components. Journal of Petroleum Science and Engineering, 187, 106743.
  10. Montgomery, W., Watson, J. S., Lewis, J. M. T., et al. (2018). Role of minerals in hydrogen sulfide generation during steam-assisted recovery of heavy oil. Energy & Fuels, 32, 4651–4654.
  11. Chen, Q. Y., Liu, Y. J., Zhao, J. (2011). Intensified viscosity reduction of heavy oil by using reservoir minerals and chemical agents in aquathermolysis. Advanced Materials Research, 236-238, 839–843.
  12. Muraza, O. (2015). Hydrous pyrolysis of heavy oil using solid acid minerals for viscosity reduction. Journal of Analytical and Applied Pyrolysis, 114, 1–10.
  13. Vakhin, A. V., Aliev, F. A., Mukhamatdinov, I. I., et al. (2021). Extra-heavy oil aquathermolysis using nickel-based catalyst: Some aspects of in-situ transformation of catalyst precursor. Catalysts, 11(2), 189.
  14. Shamilov, V. M. (2020). Potential applications of carbon nanomaterials in oil recovery. SOCAR Proceedings, 3, 90-107.
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DOI: 10.5510/OGP2021SI200572

E-mail: vahin-a_v@mail.ru


E. Utemov, D. Nurgaliev

Kazan Federal University, Kazan, Russia

The technique of recovery of causative sources in case of strong interference of gravity fields using the continuous wavelet transform


The technique of processing gravimetric data is offered in this study. Offered technique based on wavelet transform with so-called «native» wavelet basis functions. Distinctive feature of the technique is a close relationship with both direct and inverse problems of gravimetry. It was shown that the peculiarity allows to quite simply and quickly location of causative sources even under of strong interference of gravity fields.

Keywords: gravimetry; wavelet transform; anomaly; inverse problem.

The technique of processing gravimetric data is offered in this study. Offered technique based on wavelet transform with so-called «native» wavelet basis functions. Distinctive feature of the technique is a close relationship with both direct and inverse problems of gravimetry. It was shown that the peculiarity allows to quite simply and quickly location of causative sources even under of strong interference of gravity fields.

Keywords: gravimetry; wavelet transform; anomaly; inverse problem.

References

  1. Hood, P. (1965). Gradient measurements in aeromagnetic surveying. Geophysics, 30, 891–802.
  2. Thompson, D. T. (1982). EULDPH – A new technique for making computer-assisted depth estimates from magnetic data. Geophysics, 47, 31–37.
  3. Reid, A. B., Allsop, J. M., Granser, H., et al. (1990). Magnetic interpretation in three dimensions using Euler deconvolution. Geophysics, 55, 80–91.
  4. Zhang, C., Mushayandebvu, M. F., Reid, A. B., et al. (2000). Euler deconvolution of gravity tensor gradient data. Geophysics, 65(2), 512-520.
  5. Moreau, F., Gibert, D., Holschneider, M., Saracco, G. (1997). Wavelet analysis of potential fields. Inverse Problems, 13, 165-178.
  6. Moreau, F., Gibert, D., Holschneider, M., Saracco, G. (1999), Identification of sources of potential fields with the continuous wavelet transform: Basic theory. Journal of Geophysical Research, 104(B3), 5003-5013.
  7. Sailhac, P., Galdeano, A., Gibert, D., et al. (2000). Identification of sources of potential fields with the continuous wavelet transform: complex wavelets and application to aeromagnetic profiles in French Guiana. Journal of Geophysical Research, 104 (B8), 19455-19475.
  8. Gibert, D., Pessel, M. (2001). Identification of sources of potential fields with the continuous wavelet transform: Application to self-potential profiles. Geophysical Research Letters, 28(9), 1863-1866.
  9. Sailhac, P., Gibert, D., Boukerbout, H. (2009). The theory of the continuous wavelet transform in the interpretation of potential fields: a review. Geophysical Prospecting, 57, 517–525.
  10. Thierry, P. (1984), Functions analytic on the half-plane as quantum mechanical states. Journal of Mathematical Physics, 25(11), 3252.
  11. Utemov, E. V., Nurgaliev, D. K. (2005). Natural wavelet transformations of gravity data: theory and applications. Izvestia Physics of the Solid Earth, 41(4), 88-96.
  12. Alexandrescu, M., Gilbert, D., Hulot, G., et al. (1995). Detection of geomagnetic jerks using wavelet analysis. Journal of Geophysical Research, 100, 12557-12572.
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DOI: 10.5510/OGP2021SI200576

E-mail: eutemov69@gmail.com


I.G. Fattakhov1,2, L.S. Kuleshova1, R.N.Bakhtizin1, V.V. Mukhametshin1, A.V. Kochetkov2

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

Complexing the hydraulic fracturing simulation results when hybrid acid-propant treatment performing and with the simultaneous hydraulic fracture initiation in separated intervals


The purpose of the work is to substantiate and formulate the principles of data generation with multiple results of hydraulic fracturing (HF) modeling. Qualitative data for assessment, intercomparison and subsequent statistical analysis are characterized by a single numerical value for each considered hydraulic fracturing parameter. For a number of hydraulic fracturing technologies, uncertainty may arise due to obtaining several values for the parameter under consideration. The scientific novelty of the work lies in the substantiation of a new approach for evaluating the obtained data series during hydraulic fracturing modeling. A number of data can be obtained both during the formation and modeling of several hydraulic fractures, and for one fracture when calculating in different modules of the simulator. As a result, an integration technique was developed that allows forming a uniform data array regardless of the number of elements in the hydraulic fracturing modeling results.

Keywords: hydraulic fracturing; acid-proppant hydraulic fracturing; hydraulic fracturing of layered rocks; hydraulic fracturing modeling; pseudo-three-dimensional fracture model; data preparation; statistical analysis.

The purpose of the work is to substantiate and formulate the principles of data generation with multiple results of hydraulic fracturing (HF) modeling. Qualitative data for assessment, intercomparison and subsequent statistical analysis are characterized by a single numerical value for each considered hydraulic fracturing parameter. For a number of hydraulic fracturing technologies, uncertainty may arise due to obtaining several values for the parameter under consideration. The scientific novelty of the work lies in the substantiation of a new approach for evaluating the obtained data series during hydraulic fracturing modeling. A number of data can be obtained both during the formation and modeling of several hydraulic fractures, and for one fracture when calculating in different modules of the simulator. As a result, an integration technique was developed that allows forming a uniform data array regardless of the number of elements in the hydraulic fracturing modeling results.

Keywords: hydraulic fracturing; acid-proppant hydraulic fracturing; hydraulic fracturing of layered rocks; hydraulic fracturing modeling; pseudo-three-dimensional fracture model; data preparation; statistical analysis.

References

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  4. 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.
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  6. Rabaev, R. U., Chibisov, A. V., Kotenev, A. Yu., et al. (2021). Mathematical modelling of carbonate reservoir dissolution and prediction of the controlled hydrochloric acid treatment efficiency. SOCAR Proceedings, 2, 40-46.
  7. Mukhametshin, V. V. (2020). Oil Production Facilities Management Improving Using the Analogy Method. SOCAR Proceedings, 4, 42-50.
  8. Khuzin, R. R., Bakhtizin, R. N., Andreev, V. E., et al. (2021). Oil Recovery Enhancement by Reservoir Hydraulic Compression Technique Employment. SOCAR Proceedings, SI1, 98-108.
  9. Novikov, M. G., Islamov, A. I., Takhautdinov, R. Sh. (2021). Evolution of production intensification methods in the course of development of deposits in the tournaisian stage of Sheshmaoil company's oilfields: from acid stimulation to hybrid fracturing. Oil. Gas. Innovations, 3(244), 58-61.
  10. Mukhametshin, V. Sh., Zeigman, Yu. V., Andreev, A. V. (2017). Rapid assessment of deposit production capacity for determination of nanotechnologies application efficiency and necessity to stimulate their development. Nanotechnologies in Construction, 9(3), 20–34.
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  12. Yakupov, R. F., Khakimzyanov, I. N., Mukhametshin, V. V., Kuleshova, L. S. (2021). Hydrodynamic model application to create a reverse oil cone in water-oil Zones. SOCAR Proceedings, 2, 54-61.
  13. 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.
  14. Khakimzyanov, I. N., Mukhametshin, V. Sh., Bakhtizin, R. N., Sheshdirov, R. I. (2021). Determination of well spacing volumetric factor for assessment of final oil recovery in reservoirs developed by horizontal wells. SOCAR Proceedings, 2, 47-53.
  15. 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.
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  17. Veliyev, E. F. (2020). Review of modern in-situ fluid diversion technologies. SOCAR Proceedings, 2, 50-66.
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DOI: 10.5510/OGP2021SI200577

E-mail: vv@of.ugntu.ru


V. G. Pogrebnyak, I. I. Chudyk, A. V. Pogrebnyak, I. V. Perkun

Ivano-Frankivsk National Technical University of Oil and Gas, Ivano-Frankivsk, Ukraine

High-efficiency casing perforation oil and gas wells


The energetic capabilities of a high-speed jet of an aqueous solution of polyethylene oxide (PEO) with varying concentration and different outflow pressures from a jetforming nozzle were investigated using the length of the forming channel in the model of the casing of an oil and gas well, cement sheath and rock layer, as well as impact of the jet force on a metal plate fixed on a physical pendulum. The experimental data made it possible to obtain a calculated dependence in a dimensionless form to determine the quality (initial sections) of jets of aqueous solutions with different concentrations and molecular weights of PEO, considering the real parameters of the jet-forming nozzles of the hydroperforator. A comprehensive study of the perforation process made it possible to substantiate the mechanism of the high destructive capacity of a high-speed jet of polymer solution. It has been established that the mechanism of the high destructive capacity of the polymer water jet is not due to the Toms effect, but caused by the destructive action of the dynamic pressure of the polymer water jet «reinforced» by strongly unfolded macromolecular chains under the action of a tensile flow in the inlet area of the jet forming nozzle of the hydroperforator.

Keywords: perforator; jet nozzle; jet quality; casing; cement sheath; rock; Toms effect.

The energetic capabilities of a high-speed jet of an aqueous solution of polyethylene oxide (PEO) with varying concentration and different outflow pressures from a jetforming nozzle were investigated using the length of the forming channel in the model of the casing of an oil and gas well, cement sheath and rock layer, as well as impact of the jet force on a metal plate fixed on a physical pendulum. The experimental data made it possible to obtain a calculated dependence in a dimensionless form to determine the quality (initial sections) of jets of aqueous solutions with different concentrations and molecular weights of PEO, considering the real parameters of the jet-forming nozzles of the hydroperforator. A comprehensive study of the perforation process made it possible to substantiate the mechanism of the high destructive capacity of a high-speed jet of polymer solution. It has been established that the mechanism of the high destructive capacity of the polymer water jet is not due to the Toms effect, but caused by the destructive action of the dynamic pressure of the polymer water jet «reinforced» by strongly unfolded macromolecular chains under the action of a tensile flow in the inlet area of the jet forming nozzle of the hydroperforator.

Keywords: perforator; jet nozzle; jet quality; casing; cement sheath; rock; Toms effect.

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DOI: 10.5510/OGP2021SI200578

E-mail: vgpogrebnyak@gmail.com


G.G. Gilaev1, M.Ya. Khabibullin2, R.N. Bakhtizin3

1Kuban State Technological University, Institute of Oil, Gas and Energy, Krasnodar, Russia; 2Oktyabrskiy Affiliate of Ufa State Petroleum Technological University, Russia; 3Ufa State Petroleum Technological University, Ufa, Russia

Improvement of oil and gas production infrastructure as an effective tool for maintaining basic oil and gas production


The modern world is a complex mechanism in which each process, direction, sphere of activity, despite visual differences, ultimately creates a single complex element aimed at ensuring human life. One of the key processes occurring on the planet is the extraction of hydrocarbons. The article proposes to consider a solution that will contribute to ensuring the efficiency of oil and gas production processes, will extend the life cycle of mature oil and gas production assets of the Russian Federation (hereinafter referred to as the RF) and extend their economic profitability. Economic and technological efficiency from infrastructure reengineering measures is individual for each region, and directly depends on the volume of oil, water production and the state of the ground infrastructure. The described areas of infrastructure reengineering, in aggregate, represent an effective tool for optimizing operating and capital costs, increasing the reliability of technological equipment, removing infrastructure restrictions, which will contribute to the achievement of the set task - maintaining oil production at mature assets.

Keywords: facilities for oil treatment; gas compression; reservoir pressure maintenance; power supply; engineering networks; operating costs; reengineering.

The modern world is a complex mechanism in which each process, direction, sphere of activity, despite visual differences, ultimately creates a single complex element aimed at ensuring human life. One of the key processes occurring on the planet is the extraction of hydrocarbons. The article proposes to consider a solution that will contribute to ensuring the efficiency of oil and gas production processes, will extend the life cycle of mature oil and gas production assets of the Russian Federation (hereinafter referred to as the RF) and extend their economic profitability. Economic and technological efficiency from infrastructure reengineering measures is individual for each region, and directly depends on the volume of oil, water production and the state of the ground infrastructure. The described areas of infrastructure reengineering, in aggregate, represent an effective tool for optimizing operating and capital costs, increasing the reliability of technological equipment, removing infrastructure restrictions, which will contribute to the achievement of the set task - maintaining oil production at mature assets.

Keywords: facilities for oil treatment; gas compression; reservoir pressure maintenance; power supply; engineering networks; operating costs; reengineering.

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DOI: 10.5510/OGP2021SI200581

E-mail: m-hab@mail.ru


V.A. Grishchenko, S.S. Pozhitkova, V.Sh. Mukhametshin, R.F. Yakupov

Ufa State Petroleum Technological University, Ufa, Russia

Water cut forecast after downhole pumping equipment optimization based on displacement characteristics


The article deals with the issue of water cut predicting when downhole pumping equipment optimizing. In practice, an expert assessment of this parameter is used as a rule, which does not take into account the degree of planned optimization relative to the current mode. The paper proposes a methodology allowing taking into account the dynamics of planned fluid withdrawals in predicting water cut based on displacement characteristics. To solve the described problem, four characteristics were selected with a certain type of statistical dependence, where, in one part of the equation, fluid withdrawals do not depend on oil withdrawals. This allows, by setting different values of fluid production, to predict oil production and water cut at any time period. On the example of deposits of one of the regions of the Ural-Volga region, the most suitable for certain geological conditions displacement characteristics were determined. Look back analysis shows a high degree of convergence between the calculated and actual water cut indicators – the average absolute deviation is 1.9%, which allows forecasting with sufficient accuracy.

Keywords: oil fields development; production stimulation; displacement characteristics; water cut.

The article deals with the issue of water cut predicting when downhole pumping equipment optimizing. In practice, an expert assessment of this parameter is used as a rule, which does not take into account the degree of planned optimization relative to the current mode. The paper proposes a methodology allowing taking into account the dynamics of planned fluid withdrawals in predicting water cut based on displacement characteristics. To solve the described problem, four characteristics were selected with a certain type of statistical dependence, where, in one part of the equation, fluid withdrawals do not depend on oil withdrawals. This allows, by setting different values of fluid production, to predict oil production and water cut at any time period. On the example of deposits of one of the regions of the Ural-Volga region, the most suitable for certain geological conditions displacement characteristics were determined. Look back analysis shows a high degree of convergence between the calculated and actual water cut indicators – the average absolute deviation is 1.9%, which allows forecasting with sufficient accuracy.

Keywords: oil fields development; production stimulation; displacement characteristics; water cut.

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DOI: 10.5510/OGP2021SI200582

E-mail: vsh@of.ugntu.ru


V.A. Grishchenko, I.M. Tsiklis, V.Sh. Mukhametshin, R.F. Yakupov

Ufa State Petroleum Technological University, Ufa, Russia

Methodological approaches to increasing the flooding system efficiency at the later stage of reservoir development


Based on the analysis of the efficiency of CVI.1 and CVI.2 oil reservoirs development, which partially coincide in structural terms, and the terrigenous strata of the Lower Carboniferous of one of Volga-Ural oil and gas province oil fields, an algorithm for assessing the efficiency of waterflooding was proposed, which takes into account the geological structure of the facility, the results of core and geophysical well surveys, as well as the historical performance of wells. The presented algorithm makes it possible to identify ineffective injection directions for making decisions on waterflooding system optimizing. The effect is the identified potential to cut costs by reducing inefficient injection, as well as identifying areas for the introduction of enhanced oil recovery techniques.

Keywords: field development; reservoir pressure maintenance system; waterflooding efficiency; cost reduction.

Based on the analysis of the efficiency of CVI.1 and CVI.2 oil reservoirs development, which partially coincide in structural terms, and the terrigenous strata of the Lower Carboniferous of one of Volga-Ural oil and gas province oil fields, an algorithm for assessing the efficiency of waterflooding was proposed, which takes into account the geological structure of the facility, the results of core and geophysical well surveys, as well as the historical performance of wells. The presented algorithm makes it possible to identify ineffective injection directions for making decisions on waterflooding system optimizing. The effect is the identified potential to cut costs by reducing inefficient injection, as well as identifying areas for the introduction of enhanced oil recovery techniques.

Keywords: field development; reservoir pressure maintenance system; waterflooding efficiency; cost reduction.

References

  1. Muslimov, R. Kh. (2009). Features of exploration and development of oil fields in a market economy. Kazan: FEN.
  2. 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.
  3. Mukhametshin, V. Sh., Khakimzyanov, I. N., Bakhtizin, R. N., Kuleshova, L. S. (2021). Differentiation and grouping of complex-structured oil reservoirs in carbonate reservoirs in development management problems solving. SOCAR Proceedings, SI1, 88-97.
  4. Yartiev, A. F., Khabibrakhmanov, A. G., Podavalov, V. B., Bakirov, A. I. (2017). Cyclic water flooding of bobric formation at Sabanchinskoye field. Oil Industry, 3, 85-87.
  5. 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.
  6. Indrupskiy, I. M., Shupik, N. V., Zakirov, S. N. (2013). Improving pressure maintenance by advance waterflooding. Oil and Gas Technologies, 3 (86), 49-55.
  7. 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.
  8. 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.
  9. Mukhametshin, V. V. (2020). Oil production facilities management improving using the analogy method. SOCAR Proceedings, 4, 42-50.
  10. Musin, K. M., Khusainov, V. M., Gallyamov, R. R., et al. (2015). Justification of the maximum permissible and optimal bottom-hole pressures for carbonate formations (on the example of the Tournaisky tier of the Krasnogorsky deposit). Collection of scientific works of TatNIPIneft. Moscow: Oil Industry, 83, 106-113.
  11. Khakimzyanov, I. N., Mukhametshin, V. Sh., Bakhtizin R. N., et al. (2021). Justification of necessity to consider well interference in the process of well pattern widening in the Bavlinskoye oil field pashiyan formation. SOCAR Proceedings, SI1, 77-87.
  12. Zakirov, S. N., Indrupsky, I. M., Zakirov, E. S., et al. (2009). New principles and technologies for the development of oil and gas fields. Part 2. Moscow; Izhevsk: Institute of Computer Research.
  13. 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.
  14. Yanin, A. N. (2017). Retrospective analysis of feasibility of a small oil deposit water-flooding with the deteriorated reservoirs. Oilfield Engineering, 2, 24-31.
  15. 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.
  16. Veliyev, E. F. (2021). Polymer dispersed system for in-situ fluid diversion. Prospecting and Development of Oil and Gas Fields, 1(78), 61–72.
  17. Khuzin, R. R., Bakhtizin, R. N., Andreev, V. E., et al. (2021). Oil recovery enhancement by reservoir hydraulic compression technique employment. SOCAR Proceedings, SI1, 98-108.
  18. Veliyev, E. F. (2020). Review of modern in-situ fluid diversion technologies. SOCAR Proceedings, 2, 50-66.
  19. Khayredinov, N. Sh., Popov, A. M., Mukhametshin, V. Sh. (1992). Increasing the flooding efficiency of poor-producing oil deposits in carbonate collectors. Oil industry, 9, 18–20.
  20. Veliyev, E. F. (2020). Mechanisms of polymer retention in porous media. SOCAR Procеedings, 3, 126-134.
  21. Kuleshova, L. S., Fattakhov, I. G., Sultanov, Sh. Kh., et al. (2021). Experience in Conducting Multi-Zone Hydraulic Fracturing on the Oilfield of PJSC «Tatneft». SOCAR Proceedings, SI1, 68-76.
  22. Economides, J. M., Nolte, K. I. (2000). Reservoir stimulation. West Sussex, England: John Wiley and Sons.
  23. Yakupov, R. F., Khakimzyanov, I. N., Mukhametshin, V. V., Kuleshova, L. S. (2021). Hydrodynamic model application to create a reverse oil cone in water-oil zones. SOCAR Proceedings, 2, 54-61.
  24. 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.
  25. Akhmetov, R. T., Malyarenko, A. M., Kuleshova, L. S., et al. (2021). Quantitative assessment of hydraulic tortuosity of oil and gas reservoirs in western siberia based on capillarimetric studies. SOCAR Proceedings, 2, 77-84.
  26. 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. Society of Petroleum Engineers.
  27. Khakimzyanov, I. N., Mukhametshin, V. Sh., Bakhtizin, R. N., Sheshdirov, R.I. (2021). Determination of well spacing volumetric factor for assessment of final oil recovery in reservoirs developed by horizontal wells. SOCAR Proceedings, 2, 47-53.
  28. 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.
  29. Mardashov, D. V., Rogachev, M. K., Zeigman, Yu. V., Mukhametshin, V. V. (2021). Well Killing Technology before Workover Operation in Complicated Conditions. Energies, 14(3), 654, 1-15.
  30. Sun, S. Q., Wan, J. C. (2002). Geological analogs usage rates high in global survey. Oil & Gas Journal, 100(46), 49-50.
  31. Abidov, D. G., Kamartdinov, M. R. (2013). The material balance method as the primary tool for evaluating the development indicators of a field site during flooding. Bulletin of the Tomsk Polytechnic University. Geo Assets Engineering, 322, 1, 91-96.
  32. Ankudinov, A. A., Vaganov, L. A. (2013). The method of distribution of injected water over the entire area of an oil deposit with the determination of influencing factors. Materials of the International Scientific and Practical Conference, 165-168.
  33. Martemyanov, Yu. F., Lazareva, T. Ya. (2010). Expert methods of decision-making. Tambov: Tambov State Technical University.
  34. Rabaev, R. U., Chibisov, A. V., Kotenev, A. Yu., et al. (2021). Mathematical modelling of carbonate reservoir dissolution and prediction of the controlled hydrochloric acid treatment efficiency. SOCAR Proceedings, 2, 40-46.
  35. Viktorov, P. F., Gainullin, K. Kh., Efremov, F. M., et al. (1996). Justification of the criteria for shutting off injection wells. Geology of Oil and Gas, 7, 36-38.
  36. 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. Nanotechnologies in Construction, 12(2), 100–107.
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DOI: 10.5510/OGP2021SI200583

E-mail: vsh@of.ugntu.ru


I.Sh. Mingulov1, M.D. Valeev2, V.V. Mukhametshin1, L.S. Kuleshova1

1Ufa State Petroleum Technological University, Ufa, Russia; 2JSC RDE “VM Sistema”, Kumlekul, Russia

Wells production viscosity measurement results application for pumping equipment operation diagnostics


The article is devoted to the diagnostics of the well pumping equipment operation using wells production viscosity measurement results obtained by the developed field device VNP 1-4, 0-90. The method for making measurements with a field oil viscometer was developed in accordance with the provisions of GOST R 8.563, GOST R ISO 5725-2. It has gained certification and entered the State Register of the Russian Federation. On the basis of preliminary laboratory studies of oils viscosity from the group of fields of LLC UK «Sheshmaoil», a formula was obtained for the dependence of oil emulsions viscosity on temperature and the content of formation water in them. Viscosity measurements obtained with the developed device in field conditions have shown the applicability of the method for calculating the watered oil viscosity.The application of the results of measuring the watered oil viscosity at the wellhead allows diagnosing the downhole sucker rod pump unit operation based on the construction of a dynamic model of its operation.

Keywords: equipment diagnostics; water cut; temperature; fluid viscosity; dynamic model; sucker rod pump.

The article is devoted to the diagnostics of the well pumping equipment operation using wells production viscosity measurement results obtained by the developed field device VNP 1-4, 0-90. The method for making measurements with a field oil viscometer was developed in accordance with the provisions of GOST R 8.563, GOST R ISO 5725-2. It has gained certification and entered the State Register of the Russian Federation. On the basis of preliminary laboratory studies of oils viscosity from the group of fields of LLC UK «Sheshmaoil», a formula was obtained for the dependence of oil emulsions viscosity on temperature and the content of formation water in them. Viscosity measurements obtained with the developed device in field conditions have shown the applicability of the method for calculating the watered oil viscosity.The application of the results of measuring the watered oil viscosity at the wellhead allows diagnosing the downhole sucker rod pump unit operation based on the construction of a dynamic model of its operation.

Keywords: equipment diagnostics; water cut; temperature; fluid viscosity; dynamic model; sucker rod pump.

References

  1. Muslimov, R. Kh. (2014). Oil recovery: past, present, future (production optimization, maximization of oil recovery). Kazan: FEN.
  2. Gazizov, A. A., Gazizov, A. Sh., & Bogdanova, S. A. (2014). High-tech technologies of oil production. Kazan: Center of Innovative Technologies.
  3. 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.
  4. 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.
  5. 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.
  6. 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.
  7. Mardashov, D. V., Rogachev, M. K., Zeigman, Yu. V., Mukhametshin, V.V. (2021). Well killing technology before workover operation in complicated conditions. Energies, 14(3), 654, 1-15.
  8. 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.
  9. 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.
  10. Muslimov, R. Kh. (2009). Features of exploration and development of oil fields in a market economy. Kazan: FEN.
  11. Kuleshova, L. S., Fattakhov, I. G., Sultanov, Sh. Kh., et al. (2021). Experience in conducting multi-zone hydraulic fracturing on the oilfield of PJSC «Tatneft». SOCAR Proceedings, SI1, 68-76.
  12. Mukhametshin, V. Sh., Khakimzyanov, I. N., Bakhtizin, R. N., Kuleshova, L. S. (2021). Differentiation and grouping of complex-structured oil reservoirs in carbonate reservoirs in development management problems solving. SOCAR Proceedings, SI1, 88-97.
  13. Minnikhanov, R. N., Maganov, N. U., Khisamov, R. S. (2016). On creation of research and testing facilities to promote study of nonconventional oil reserves in Tatarstan. Oil Industry, 8, 60-63.
  14. Novikov, M. G., Islamov, A. I., Takhautdinov, R. Sh. (2021). Evolution of production intensification methods in the course of development of deposits in the tournaisian stage of Sheshmaoil company's oilfields: from acid stimulation to hybrid fracturing. Oil. Gas. Innovations, 3(244), 58-61.
  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. Khakimzyanov, I. N., Mukhametshin, V. Sh., Bakhtizin, R. N., Sheshdirov, R. I. (2021). Determination of well spacing volumetric factor for assessment of final oil recovery in reservoirs developed by horizontal wells. SOCAR Proceedings, 2, 47-53.
  17. 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. Society of Petroleum Engineers.
  18. Mukhametshin, V. V. (2018). Rationale for trends in increasing oil reserves depletion in Western Siberia cretaceous deposits based on targets identification. Bulletin of the Tomsk Polytechnic University. Geo Assets Engineering, 329(5), 117–124.
  19. Khakimzyanov, I. N., Mukhametshin, V. Sh., Bakhtizin, R. N., et al. (2021). Justification of necessity to consider well interference in the process of well pattern widening in the Bavlinskoye oil field pashiyan formation. SOCAR Proceedings, SI1, 77-87.
  20. Khabibrakhmanov, А. G., Zaripov, А. Т., Khakimzyanov, I. N., et al. (2017). Evaluation of the efficiency of well grid compaction in low-permeable carbonate reservoirs (on the example of the fields of the Republic of Tatarstan). Kazan: Slovo Publ.
  21. Khisamov, R. S., Khabibrakhmanov, A. G., Podavalov, V. B., et al. (2016). Geological features and prospects for development of low-permeability carbonate reservoirs of Rodveryuskoye oil field. Oil Industry, 11, 84-87.
  22. 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.
  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 Tomsk Polytechnic University. Geo Assets Engineering, 331, 5, 140–146.
  24. Veliyev, E. F. (2021). Polymer dispersed system for in-situ fluid diversion. Prospecting and Development of Oil and Gas Fields, 1(78), 61–72.
  25. Veliyev, E. F. (2020). Mechanisms of polymer retention in porous media. SOCAR Procеedings, 3, 126-134.
  26. Mukhametshin, V. V. (2020). Oil production facilities management improving using the analogy method. SOCAR Proceedings, 4, 42-50.
  27. Khayredinov, N. Sh., Popov, A. M., Mukhametshin, V. Sh. (1992). Increasing the flooding efficiency of poor-producing oil deposits in carbonate collectors. Oil industry, 9, 18–20.
  28. Veliyev, E. F. (2020). Review of modern in-situ fluid diversion technologies. SOCAR Proceedings, 2, 50-66.
  29. Kutyrev, E. F., Sergienko, V. N., Kutyrev, A. E. (2005). About the concept of water-flooded oil pools development at late stages (part 2). Oil Industry, 10, 44-48.
  30. Akhmetov, R. T., Malyarenko, A. M., Kuleshova, L. S., et al. (2021). Quantitative assessment of hydraulic tortuosity of oil and gas reservoirs in Western Siberia based on capillarimetric studies. SOCAR Proceedings, 2, 77-84.
  31. Mukhametshin, V. Sh., Zeigman, Yu. V., Andreev, A. V. (2017). Rapid assessment of deposit production capacity for determination of nanotechnologies application efficiency and necessity to stimulate their development. Nanotechnologies in Construction, 9(3), 20–34.
  32. Khuzin, R. R., Bakhtizin, R. N., Andreev, V. E., et al. (2021). Oil recovery enhancement by reservoir hydraulic compression technique employment. SOCAR Proceedings, SI1, 98-108.
  33. 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.
  34. Yakupov, R. F., Khakimzyanov, I. N., Mukhametshin, V. V., Kuleshova, L. S. (2021). Hydrodynamic model application to create a reverse oil cone in water-oil zones. SOCAR Proceedings, 2, 54-61.
  35. Rabaev, R. U., Chibisov, A. V., Kotenev, A. Yu., et al. (2021). Mathematical modelling of carbonate reservoir dissolution and prediction of the controlled hydrochloric acid treatment efficiency. SOCAR Proceedings, 2, 40-46.
  36. 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.
  37. 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.
  38. Valeev, M. D., Leontiev, S. A., Mayer, A. V., Mokhov, M. A. (2018). Theory and practice of pumping production of high-viscosity oil from flooded wells. Moscow: Gubkin Russian State University of Oil and Gas (NIU).
  39. Sergeev, V .V., Belenkova, N. G., Zeigman, Yu. V., Mukhametshin, V. Sh. (2017). Physical properties of emulsion systems with SiO2 nanoparticles. Nanotechnologies in Construction, 9(6), 37–64.
  40. Rakhmatullin, V. N., Kutyrev, E. F., Ramazanov, R. U., Karimov, A. A. (2006). Investigation of the effective viscosity of oil during deep-pump production. Collection of reports of the second scientific and practical conference (additional volume) «Problems of the oil and gas complex of Western Siberia and ways to improve its efficiency». Ufa: Monographiya, 321-324.
  41. (2019). Field oil viscometer GNP 1-4, 0-90. State registration number in the Register of the Russian Federation FR.1.31.2019.32427.
  42. Isaev, A. A., Malykhin, V. I., Sharifullin, A. A. (2019). Development and implementation of a field viscometer. Oilfield Engineering, 12, 62-66.
  43. Isaev, A. A., Takhautdinov, R. Sh., Malykhin, V. I., Sharifullin, A. A. (2019). Field methods of land seismic prospecting and marine vibrator. Exposition Oil & Gas, 5(72), 37–40.
  44. Isaev, A. A., Takhautdinov, R. Sh., Malykhin, V. I., Sharifullin, A. A. (2019, October). Development of novel methods and devices for measuring the total gas-oil ratio, oil and water production rates and fluid viscosity. SPE-198421-MS. In: SPE Annual Caspian Technical Conference held. Society of Petroleum Engineers.
  45. Isaev, A. A., Malykhin, V. I., Sharifullin, A.A. (2019). Fluid viscosity measutring according to höppler principle. Oil. Gas. Innovations, 11, 92-94.
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DOI: 10.5510/OGP2021SI200584

E-mail: vv@of.ugntu.ru


V.A. Grishchenko, R.U. Rabaev, I.N. Asylgareev, V.Sh. Mukhametshin, R.F. Yakupov

Ufa State Petroleum Technological University, Ufa, Russia

Methodological approach to optimal geological and technological characteristics determining when planning hydraulic fracturing at multilayer facilities


The paper considers the issue of increasing the hydraulic fracturing efficiency in a multilayer facility at the final stage of development with an uneven degree of reserves development along the section. Based on the results of the analysis, it was found that the upper layers, which have the worst filtration-reservoir properties, are less developed in comparison with the highly productive lower ones. When hydraulic fracturing was carried out in the upper formations, some of the operations had low success due to the breakthrough of hydraulic fractures into the lower depleted formations. On the basis of the revealed dependencies, the work determined the optimal specific loading of proppant per meter of effective power, depending on the geological conditions, and maps of the prospects for hydraulic fracturing are built.

Keywords: oil fields development; hydraulic fracturing; hydraulic fracturing optimization; multilayer facilities.

The paper considers the issue of increasing the hydraulic fracturing efficiency in a multilayer facility at the final stage of development with an uneven degree of reserves development along the section. Based on the results of the analysis, it was found that the upper layers, which have the worst filtration-reservoir properties, are less developed in comparison with the highly productive lower ones. When hydraulic fracturing was carried out in the upper formations, some of the operations had low success due to the breakthrough of hydraulic fractures into the lower depleted formations. On the basis of the revealed dependencies, the work determined the optimal specific loading of proppant per meter of effective power, depending on the geological conditions, and maps of the prospects for hydraulic fracturing are built.

Keywords: oil fields development; hydraulic fracturing; hydraulic fracturing optimization; multilayer facilities.

References

  1. Dmitrievsky, A. N. (2017). Resource-innovative strategy for the development of the Russian economy. Oil Industry, 5, 6-7.
  2. Muslimov, R. Kh. (2009). Features of exploration and development of oil fields in a market economy. Kazan: FEN.
  3. Sergeev, V. V., Belenkova, N. G., Zeigman, Yu. V., Mukhametshin, V. Sh. (2017). Physical properties of emulsion systems with SiO2 nanoparticles. Nanotechnologies in Construction, 9(6), 37–64.
  4. Mardashov, D. V., Rogachev, M. K., Zeigman, Yu. V., Mukhametshin, V. V. (2021). Well Killing Technology before Workover Operation in Complicated Conditions. Energies, 14(3), 654, 1-15.
  5. Muslimov, R. Kh. (2005). Modern methods of oil recovery increasing: design, optimization and performance evaluation. Kazan: FEN Publ.
  6. Minnikhanov, R. N., Maganov, N. U., Khisamov, R.S. (2016). On creation of research and testing facilities to promote study of nonconventional oil reserves in Tatarstan. Oil Industry, 8, 60-63.
  7. Khakimzyanov, I. N., Mukhametshin, V. Sh., Bakhtizin, R. N., et al. (2021). Justification of necessity to consider well interference in the process of well pattern widening in the Bavlinskoye oil field pashiyan formation. SOCAR Proceedings, SI1, 77-87.
  8. Yakupov, R. F., Khakimzyanov, I. N., Mukhametshin, V. V., Kuleshova, L. S. (2021). Hydrodynamic model application to create a reverse oil cone in water-oil zones. SOCAR Proceedings, 2, 54-61.
  9. 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. Veliyev, E. F. (2020). Review of modern in-situ fluid diversion technologies. SOCAR Proceedings, 2, 50-66.
  11. Rabaev, R. U., Chibisov, A. V., Kotenev, A. Yu., et al. (2021). Mathematical modelling of carbonate reservoir dissolution and prediction of the controlled hydrochloric acid treatment efficiency. SOCAR Proceedings, 2, 40-46.
  12. Khuzin, R. R., Bakhtizin, R. N., Andreev, V. E., et al. (2021). Oil recovery enhancement by reservoir hydraulic compression technique employment. SOCAR Proceedings, SI1, 98-108.
  13. 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.
  14. Rzayeva, S. J. (2019). New microbiological method of oil recovery increase containing highly mineralized water. SOCAR Procеedings, 2, 38-44.
  15. Khakimzyanov, I. N., Mukhametshin, V. Sh., Bakhtizin, R. N., Sheshdirov, R. I. (2021). Determination of well spacing volumetric factor for assessment of final oil recovery in reservoirs developed by horizontal wells. SOCAR Proceedings, 2, 47-53.
  16. Akhmetov, R. T., Malyarenko, A. M., Kuleshova, L. S., et al. (2021). Quantitative assessment of hydraulic tortuosity of oil and gas reservoirs in Western Siberia based on capillarimetric studies. SOCAR Proceedings, 2, 77-84.
  17. 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.
  18. Economides, J. M., Nolte, K. I. (2000). Reservoir stimulation. West Sussex, England: John Wiley and Sons.
  19. 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.
  20. 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.
  21. Kanevskaya, R. D. (1999). Mathematical modeling of oil and gas field development using hydraulic fracturing. Moscow: Nedra-Business Center.
  22. Ismayilov, F. S., Ibrahimov, H. M., Abdullayeva, F. Y. (2015). Estimated results of biotechnology application based on formation stimulation at field «Bibiheybat». SOCAR Proceedings, 2, 43-46.
  23. 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.
  24. 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.
  25. Suleimanov, B. A., Veliyev, E. F. (2016). The effect of particle size distribution and the nanosized additives on the quality of annulus isolation in well cementing. SOCAR Proceedings, 4, 4-10.
  26. Veliyev, E. F. (2020). Mechanisms of polymer retention in porous media. SOCAR Procеedings, 3, 126-134.
  27. Mukhametshin, V. Sh., Zeigman, Yu. V., Andreev, A. V. (2017). Rapid assessment of deposit production capacity for determination of nanotechnologies application efficiency and necessity to stimulate their development. Nanotechnologies in Construction, 9(3), 20–34.
  28. 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.
  29. 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.
  30. 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. Society of Petroleum Engineers.
  31. Mukhametshin, V. Sh., Khakimzyanov, I. N., Bakhtizin, R. N., Kuleshova, L. S. (2021). Differentiation and grouping of complex-structured oil reservoirs in carbonate reservoirs in development management problems solving. SOCAR Proceedings, SI1, 88-97.
  32. Mukhametshin, V. V. (2020). Oil production facilities management improving using the analogy method. SOCAR Proceedings, 4, 42-50.
  33. Koltyrin, A. N. (2016). Efficiency enhancement of the technology of a formation hydraulic fracturing in a carbonate-type collector. Oilfield Engineering, 10, 28-31.
  34. 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.
  35. 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.
  36. 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.
  37. Sun, S. Q., Wan, J. C. (2002). Geological analogs usage rates high in global survey. Oil & Gas Journal, 100(46), 49-50.
  38. Zdolnik, S. E., Nekipelov, Yu. V., Gaponov, M. A., Folomeev, A. E. (2016). Introduction of innovative hydrofracturing technologies on carbonate reservoirs of Bashneft PJSOC. Oil Industry, 7, 92-95.
  39. 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. Nanotechnologies in Construction, 12(2), 100–107.
  40. Kuleshova, L. S., Fattakhov, I. G., Sultanov, Sh. Kh., et al. (2021). Experience in conducting multi-zone hydraulic fracturing on the oilfield of PJSC «Tatneft». SOCAR Proceedings, SI1, 68-76.
  41. Latypov, I. D., Efimov, D. V., Murinov, K. Yu., et al. (2016). Development of a methodological justification of the applicability of hydraulic fracturing technology on carbonate reservoirs of deposits operated by Bashneft-Polyus LLC. Proceedings of the conference «Current scientific and technical solutions for the development of the oil production potential of PJSC ANC Bashneft». Ufa: BashNIPIneft, 124, 359-365.
  42. Chekushin, V. F., Kolesnikov, A. A., Mukhametshin, M. R., Litvinenko, S. A. (2012). Wide implementation of fracturing on oil-fields of the Republic of Bashkortostan. Oil Industry, 4, 40-42.
  43. Grishchenko, V. A., Bashirov, I. R., Mukhametshin, M. R., Bildanov, V. F. (2018). Features of application of proppant-acid fracturing technology o in the fields of the Republic of Bashkortostan. Oil Industry, 12, 120-122.
  44. Jennings, A. R. Jr. PE. (2003). OGCI/PetroSkills hydraulic fracturing applications. Enhanced Well Stimulation, Inc.
  45. Grishchenko, V. A., Yakupov, R. F., Mukhametshin, V. Sh., et al. (2021). Localization and recovery strategy of residual reserves the pashian horizon of the Tuymazinskoye oil field at the final stage of development. Oil Industry, 5, 103-107.
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DOI: 10.5510/OGP2021SI200587

E-mail: vsh@of.ugntu.ru


V.V. Mukhametshin1, R.N. Bakhtizin1, L.S. Kuleshova1, A.P. Stabinskas2, A.R. Safiullina1

1Ufa State Petroleum Technological University, Ufa, Russia; 2«Gazprom» PJSC, Saint-Petersburg, Russia

Screening and assessing the conditions for effective oil recovery enhancing techniques application for hard to recover high-water cut reserves


For the conditions of deposits in Jurassic and Paleozoic terrigenous reservoirs of the Sherkalinsky trough and Shaimsky swell of Western Siberia, a criterion analysis and screening of enhanced oil recovery techniques used in the fields of the West Siberian oil and gas province were carried out. For various groups of oil fields, a set of the most effective technologies for the development of residual hard-to-recover reserves of flooded fields has been proposed. The areas for effective application of the selected techniques for deposits introduced into development within the considered tectonic-stratigraphic elements are determined. The areas determination was carried out on the basis of 19 parameters characterizing the geological-physical and physical-chemical properties of formations and fluids, as well as the maximum and minimum values of the canonical discriminant functions determined by the situational map. Based on the numerical modeling of oil recovery processes, a forecast of an increase in the final oil recovery factor was made for five facilities-field test sites of the selected groups of facilities.

Keywords: hard-to-recover reserves; terrigenous reservoirs; factor analysis; enhanced oil recovery techniques; numerical modeling; criterion analysis.

For the conditions of deposits in Jurassic and Paleozoic terrigenous reservoirs of the Sherkalinsky trough and Shaimsky swell of Western Siberia, a criterion analysis and screening of enhanced oil recovery techniques used in the fields of the West Siberian oil and gas province were carried out. For various groups of oil fields, a set of the most effective technologies for the development of residual hard-to-recover reserves of flooded fields has been proposed. The areas for effective application of the selected techniques for deposits introduced into development within the considered tectonic-stratigraphic elements are determined. The areas determination was carried out on the basis of 19 parameters characterizing the geological-physical and physical-chemical properties of formations and fluids, as well as the maximum and minimum values of the canonical discriminant functions determined by the situational map. Based on the numerical modeling of oil recovery processes, a forecast of an increase in the final oil recovery factor was made for five facilities-field test sites of the selected groups of facilities.

Keywords: hard-to-recover reserves; terrigenous reservoirs; factor analysis; enhanced oil recovery techniques; numerical modeling; criterion analysis.

References

  1. 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.
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  5. Rzayeva, S. J. (2019). New microbiological method of oil recovery increase containing highly mineralized water. SOCAR Procеedings, 2, 38-44.
  6. Sun, S. Q., Wan, J. C. (2002). Geological analogs usage rates high in global survey. Oil & Gas Journal, 100(46), 49-50.
  7. Khakimzyanov, I. N., Mukhametshin, V. Sh., Bakhtizin, R. N., Sheshdirov, R. I. (2021). Determination of well spacing volumetric factor for assessment of final oil recovery in reservoirs developed by horizontal wells. SOCAR Proceedings, 2, 47-53.
  8. Ismayilov, F. S., Ibrahimov, H. M., Abdullayeva, F. Y. (2015). Estimated results of biotechnology application based on formation stimulation at field «Bibiheybat». SOCAR Proceedings, 2, 43-46.
  9. 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. In: SPE Europec/EAGE Annual Conference and Exhibition. Society of Petroleum Engineers.
  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.
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  12. Rabaev, R. U., Chibisov, A. V., Kotenev, A. Yu., et al. (2021). Mathematical modelling of carbonate reservoir dissolution and prediction of the controlled hydrochloric acid treatment efficiency. SOCAR Proceedings, 2, 40-46.
  13. 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.
  14. Akhmetov, R. T., Malyarenko, A. M., Kuleshova, L. S., et al. (2021). Quantitative assessment of hydraulic tortuosity of oil and gas reservoirs in Western Siberia based on capillarimetric studies. SOCAR Proceedings, 2, 77-84.
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  17. 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.
  18. 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.
  19. Yakupov, R. F., Khakimzyanov, I. N., Mukhametshin, V. V., Kuleshova, L. S. (2021). Hydrodynamic model application to create a reverse oil cone in water-oil zones. SOCAR Proceedings, 2, 54-61.
  20. 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.
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  22. Sergeev, V. V., Belenkova, N. G., Zeigman, Yu. V., Mukhametshin, V. Sh. (2017). Physical properties of emulsion systems with SiO2 nanoparticles. Nanotechnologies in Construction, 9(6), 37–64.
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  27. 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.
  28. Suleimanov, B. A., Veliyev, E. F. (2016). The effect of particle size distribution and the nanosized additives on the quality of annulus isolation in well cementing. SOCAR Proceedings, 4, 4-10.
  29. Minnikhanov, R. N., Maganov, N. U., Khisamov, R. S. (2016). On creation of research and testing facilities to promote study of nonconventional oil reserves in Tatarstan. Oil Industry, 8, 60-63.
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  31. Veliyev, E. F. (2020). Mechanisms of polymer retention in porous media. SOCAR Procеedings, 3, 126-134.
  32. Muslimov, R. Kh. (2014). Oil recovery: past, present, future (production optimization, maximization of oil recovery). Kazan: FEN.
  33. 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.
  34. Mukhametshin, V. V. (2020). Oil production facilities management improving using the analogy method. SOCAR Proceedings, 4, 42-50.
  35. 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.
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DOI: 10.5510/OGP2021SI200588

E-mail: markl212@mail.ru


R. A. Ismakov1, E. V. Denisova2, S. P. Sidorov2, M. A. Chernikova1

1Ufa State Petroleum Technical University, Ufa, Russia; 2Institute of Mechanics. R.R. Mavlyutova UFIC RAS, Ufa, Russia

Research of inflow control devices for estimation of application in intellectual well


Ensuring the completeness of oil and gas production from the subsoil by using modern techniques and technologies for controlling the inflow into the well is an urgent task, especially for wells with long horizontal ends. Inflow control devices (ICD), used in conjunction with packers and downhole measurement devices, are part of such systems, covered by the concept of «smart well». In general, such systems make it possible to control the inflow (flow rate) in individual intervals of horizontal wells or in vertical wells of multilayer fields while operating simultaneously in order to optimize production without additional downhole operations in real time.

Keywords: inflow control device; horizontal well; intelligent well.

Ensuring the completeness of oil and gas production from the subsoil by using modern techniques and technologies for controlling the inflow into the well is an urgent task, especially for wells with long horizontal ends. Inflow control devices (ICD), used in conjunction with packers and downhole measurement devices, are part of such systems, covered by the concept of «smart well». In general, such systems make it possible to control the inflow (flow rate) in individual intervals of horizontal wells or in vertical wells of multilayer fields while operating simultaneously in order to optimize production without additional downhole operations in real time.

Keywords: inflow control device; horizontal well; intelligent well.

References

  1. Gualdron, M. G., Anaya, A. F., Araujo, Y. E., et al. (2014, September) Passive inflow control device (ICDs) application in horizontal wells completions in Rubiales area, heavy oil reservoir. SPE-171040-MS. In: SPE Heavy and Extra Heavy Oil Conference. Society of Petroleum Engineers.
  2. Henriksen, K., H., Gule, E. I., Augustine, J. R. (2006, June). Augustine case study: the application of inflow control devices in the Troll field. SPE-100308-MS. In: SPE Europec EAGE Annual Conference and Exhibition. Society of Petroleum Engineers.
  3. Halvorsen, M., Madsen, M., Vikoren Mo., M., et al. (2016, April). Enhanced oil recovery on Troll field by implementing autonomous inflow control device. SPE-180037-MS. In: SPE Bergen One Day Seminar. Society of Petroleum Engineers.
  4. Vela, I., Viloria-Gomez, L., Caicedo, R., et al. (2011, May). Well production enhancement results with inflow control device (ICD) completions in horizontal wells in Ecuador. SPE-143431-MS. In: SPE EUROPEC/EAGE Annual Conference and Exhibition. Society of Petroleum Engineers.
  5. Nukhaev, M., Zhuravlev, O., Shchelushkin, R. et al. (2014). Features of equipment for the horizontal wells construction. Neftegaz, 4, 20-24.
  6. Haaland, A., Rundgren, G., Johannessen, Ø., et al. (2005, May). Completion technology on trollinnovation and simplicity. OTC-17113. In: Offshore Technology Conference. Society of Petroleum Engineers.
  7. Henriksen, K. H., Gule, E. I., Augustine, J. (2006, June). Case study: the application of inflow control devices in the Troll oil field. SPE-100308-SM. In: Annual Conference and Exhibition. Society of Petroleum Engineers.
  8. Akram, N., Hicking, S., Blythe, P., et al. (2001, September). Intelligent well technology in mature assets. SPE-71822-SM. In: Offshore Europe Conference. Society of Petroleum Engineers.
  9. Bogaert, P. M., Yang, W., Meijers, H. C., et al. (2004, May). Improving oil production using smart fields technology in the SF30 satellite oil development offshore Malaysia. OTC-16162-MS. In: Offshore Technology Conference. Society of Petroleum Engineers.
  10. Raffn, A. G., Hundsnes, S., Kvernstuen, S., et al. (2007, April). ICD screen technology used to optimize waterflooding in injector well. SPE-106018-MS. In: Production and Operations Symposium. Society of Petroleum Engineers.
  11. Garcia, L., Coronado, M. P., Russell, R. D., et al. (2009, December). The first passive inflow control device that maximizes productivity during every phase of a well's life. IPTC-13863-MS. In: International Petroleum Technology Conference. Society of Petroleum Engineers.
  12. Gusev, A. A. (2014). Hydraulics. Theory and practice. Moscow: Yurayt.
  13. AI-Khelaiwi, F. T., Davies, D. R. (2007, April). Inflow control devices: application and value quantification of a developing technology. SPE-108700-MS. In: Production and Operations Symposium. Society of Petroleum Engineers.
  14. Halliburton EquiFlow® autonomous inflow control device. https://www.halliburton.com/en/resources/equiflow-aicd-boosts-oil-production-reduces-water-production
  15. Crow, S. L., Coronado, M. P., Mody, R. K. (2006, September). Means for passive inflow control upon gas breakthrough. SPE-102208-MS. In: Conference and Exhibition, San Antonio, Texas, USA. Society of Petroleum Engineers.
  16. Eltaher, E., Muradov, Kh., Davies, D., et al. (2014, October). Autonomous inflow control valves - their modelling and «added value». SPE-170780-MS. In: SPE Annual Technical Conference and Exhibition. Society of Petroleum Engineers.
  17. Taghavi, S., Aakre, H., Swaffield, S., et al. (2019, October). Verification of autonomous inflow control valve flow performance within heavy oil-SAGD Thermal flow loop. SPE-196216-MS. In: SPE Annual Technical Conference and Exhibition. Society of Petroleum Engineers.
  18. Shaw, J. (2011, November). Comparison of downhole control system technologies for intelligent completions. SPE-147547-MS. In: Canadian Unconventional Resources Conference. Society of Petroleum Engineers.
  19. Al-Khelaiwi, F. T., Birchenko, V. M., Konopczynski, M. R., et al. (2010). Advanced wells: a comprehensive approach to the selection between passive and active inflow-control completion. SPE-132976-PA. SPE Production and Operation, 305-326.
  20. Rahman, J., Allen, C., Bhat, G. (2012, February). Second-generation interval control valve (ICV) improves operational efficiency and inflow performance in intelligent completions. SPE-150850-MS. In: North Africa Technical Conference and Exhibition. Society of Petroleum Engineers.
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  22. Ismakov, R. A., Denisova. E. V., Chernikova. M. A., Sidorov. S. P. ( 2019). System of device for controlling fluid injection in a well. Bulletin of the Tomsk Polytechnic University. Geo Assets Engineering, 330, 11, 192-198.
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DOI: 10.5510/OGP2021SI200589

E-mail: denisova.anrb@mail.ru


M.Ya. Khabibullin1, G.G. Gilaev2, R.U. Rabaev3

1Oktyabrskiy Affiliate of Ufa State Petroleum Technological University, Oktyabrskiy, Russia; 2Kuban State Technological University,Institute of Oil, Gas and Energy, Krasnodar, Russia; 3Ufa State Petroleum Technological University, Ufa, Russia

Improvement of acid treatment with the sintanol preparation after hydro-sand blasting of wells in the conditions of ANK «Bashneft»


A sandblasting hammer is lowered into the well, setting against the selected processing interval, and hydraulic clamps are necessary for the rig to be held firmly. The displacement of the latter eliminates the possibility of selective processing. After the usual sandblasting and flushing the well from sand, without changing the position of the perforator, an acid solution is pumped into the pipes, which, entering the channel formed, is filtered through its walls into the treated section of the formation. The part of the acid that, after the end of the treatment, has accumulated in the wellbore, is forced into the reservoir by the squeezing fluid through the annular space. Increase the acid depletion time, i.e. slow down the reaction rate by adding special reagents to the solution. So, a syntanol DS-10 TU 2483-016-71150986-2012 (a non-ionic surfactant and is intended for use as an effective surfactant) is a very effective reaction rate reducer. Adding it in an amount of 0.5% (by weight of the volume of the solution) can reduce the reaction rate by 2.7 times.

Keywords: speed; reaction; syntanol; processing; pressure.

A sandblasting hammer is lowered into the well, setting against the selected processing interval, and hydraulic clamps are necessary for the rig to be held firmly. The displacement of the latter eliminates the possibility of selective processing. After the usual sandblasting and flushing the well from sand, without changing the position of the perforator, an acid solution is pumped into the pipes, which, entering the channel formed, is filtered through its walls into the treated section of the formation. The part of the acid that, after the end of the treatment, has accumulated in the wellbore, is forced into the reservoir by the squeezing fluid through the annular space. Increase the acid depletion time, i.e. slow down the reaction rate by adding special reagents to the solution. So, a syntanol DS-10 TU 2483-016-71150986-2012 (a non-ionic surfactant and is intended for use as an effective surfactant) is a very effective reaction rate reducer. Adding it in an amount of 0.5% (by weight of the volume of the solution) can reduce the reaction rate by 2.7 times.

Keywords: speed; reaction; syntanol; processing; pressure.

References

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  24. Khabibullin, M. Ya. (2019, December). Development of the design of the sucker-rod pump for sandy wells. In: IOP Conference Series: Materials Science and Engineering, 560 012065.
  25. Gilaev, Gen. G., Khabibullin, M. Ya., Gilaev, G. G. (2020). Prospects for the use of acid gel for pumping proppant in the process of hydraulic fracturing of carbonate formations in the Samara region. Oil Industry, 8, 54-57.
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  27. Khabibullin, M. Ya. (2019). A systematized approach to methods of water injection into injection wells. Oil and Gas Business, 17(3), 80-86.
  28. Rady, A., Nasr-El-Din, H. A. (2015, October). Iron precipitation in calcite, dolomite and sandstone cores. SPE-176574-MS. In: SPE Russian Petroleum Technology Conference. Society of Petroleum Engineers.
  29. Rabie, A. I., Nasr-El-Din, H. A. (2015, March). Sodium gluconate as a new environmentally friendly iron controlling agent for HP/ HT acidizing treatments. SPE-172640-MS. In: SPE Middle East Oil & Gas Show and Conference. Society of Petroleum Engineers.
  30.  30. Litvin, V. T., Strizhnev, K. V., Roshchin, P. V. (2015). Features of the structure and intensification of oil inflows in complex reservoirs of the Bazhenov formation of the Palyanovskoye field. Theory and practice, 10(3).
  31. Shaken, M. Sh. (2019). Studying the applicability of acid treatment in conglomerate reservoir. SOCAR Proceedings, 4, 23-31.
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  33. Sultanmagomedov, T. S., Bakhtizin, R. N., Sultanmagomedov, S. M. (2020). Study of pipeline movements in permafrost soils. SOCAR Proceedings, 4, 75-83.
  34. Moiseev, K. V., Kuleshov, V. S., Bakhtizin, R. N. (2020). Free convection of a linearly inhomogeneous liquid in a square cavity under lateral heating. SOCAR Proceedings, 4, 108-116.
  35. Gilaev, Gen. G., Khabibullin, M. Ya., Gilaev, G. G. (2020). The main aspects of using acid gel for proppant injection during hydraulic fracturing operations on carbonate reservoirs in the Volga-Ural region. SOCAR Proceedings, 4, 33-41.
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DOI: 10.5510/OGP2021SI200590

E-mail: m-hab@mail.ru


I.G. Fattakhov1,2, L.S. Kuleshova1, Sh.Kh. Sultanov1, V.V. Mukhametshin1, A.S. Zhirkeev2, A.K. Sakhapova2

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

Improving the waterproofing efficiency by using a plugging compound


Increasing the efficiency of water shut-off works is one of the important tasks for the sustainable well operation. The article discusses the use of various plugging compositions for water inflow into a well isolating, their advantages and disadvantages, conditions of use, and presents the results of a study of the proposed composition. The composition of an aqueous solution of polyaluminium chloride and a suspension of gypsum anhydrite is considered. The composition contains 45-55 mass percent of 15-25 percent aqueous solution of polyaluminium chloride and 45-55 mass percent suspension of gypsum anhydrite at a water-solid ratio of 0.9. The technical result is an increase in the efficiency of water inflow into the well isolating by obtaining a homogeneous, dense plugging mass formed by mixing the components of the composition and gaining maximum strength over time.

Keywords: well; water cut; isolation; water inflow; plugging mass; bottomhole formation zone; oil production; polyaluminium chloride; anhydrite.

Increasing the efficiency of water shut-off works is one of the important tasks for the sustainable well operation. The article discusses the use of various plugging compositions for water inflow into a well isolating, their advantages and disadvantages, conditions of use, and presents the results of a study of the proposed composition. The composition of an aqueous solution of polyaluminium chloride and a suspension of gypsum anhydrite is considered. The composition contains 45-55 mass percent of 15-25 percent aqueous solution of polyaluminium chloride and 45-55 mass percent suspension of gypsum anhydrite at a water-solid ratio of 0.9. The technical result is an increase in the efficiency of water inflow into the well isolating by obtaining a homogeneous, dense plugging mass formed by mixing the components of the composition and gaining maximum strength over time.

Keywords: well; water cut; isolation; water inflow; plugging mass; bottomhole formation zone; oil production; polyaluminium chloride; anhydrite.

References

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  8. 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.
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  12. 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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  16. Rabaev, R. U., Chibisov, A. V., Kotenev, A. Yu., et al. (2021). Mathematical modelling of carbonate reservoir dissolution and prediction of the controlled hydrochloric acid treatment efficiency. SOCAR Proceedings, 2, 40-46.
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  22. Yakupov, R. F., Khakimzyanov, I. N., Mukhametshin, V. V., Kuleshova, L. S. (2021). Hydrodynamic model application to create a reverse oil cone in water-oil zones. SOCAR Proceedings, 2, 54-61.
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  24. Mukhametshin, V. Sh., Khakimzyanov, I. N., Bakhtizin, R. N., Kuleshova, L. S. (2021). Differentiation and grouping of complex-structured oil reservoirs in carbonate reservoirs in development management problems solving. SOCAR Proceedings, SI1, 88-97.
  25. Veliyev, E. F. (2021). Polymer dispersed system for in-situ fluid diversion. Prospecting and Development of Oil and Gas Fields, 1(78), 61–72.
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  29. Muslimov, R. Kh. (2009). Features of exploration and development of oil fields in a market economy. Kazan: FEN.
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DOI: 10.5510/OGP2021SI200591

E-mail: vv@of.ugntu.ru


A.I. Shayakhmetov, V.L. Malyshev, E.F. Moiseeva, A.I. Ponomarev

Ufa State Petroleum Technical University, Ufa, Russia

Estimation of efficiency of oil extraction with supercritical CO2 in a low-permeability reservoir


The results of experimental study of oil extraction by supercritical carbon dioxide in a low-permeability reservoir are presented. As an object of study, we selected core samples from a low-permeability oil-saturated reservoir of one of the fields in Western Siberia, which is currently being developed in the regime of depletion of reservoir energy. The contact time of supercritical carbon dioxide with composite core models in three experiments was 8, 24, and 72 hours, respectively. Based on the results of laboratory experiments, the dynamics of the penetration of carbon dioxide along the depth of the composite core model was established. The value of the oil recovery factor and it’s distribution along the length of the core model in time is given.

Keywords: carbon dioxide; low-permeability reservoir; mnimum miscibility pressure; slim-tube; extraction; oil recovery.

The results of experimental study of oil extraction by supercritical carbon dioxide in a low-permeability reservoir are presented. As an object of study, we selected core samples from a low-permeability oil-saturated reservoir of one of the fields in Western Siberia, which is currently being developed in the regime of depletion of reservoir energy. The contact time of supercritical carbon dioxide with composite core models in three experiments was 8, 24, and 72 hours, respectively. Based on the results of laboratory experiments, the dynamics of the penetration of carbon dioxide along the depth of the composite core model was established. The value of the oil recovery factor and it’s distribution along the length of the core model in time is given.

Keywords: carbon dioxide; low-permeability reservoir; mnimum miscibility pressure; slim-tube; extraction; oil recovery.

References

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  30. Malyshev, V. L., Moiseeva, E. F., Kalinovsky, Yu. V. (2018). Comparative study of the determination of thermodynamic properties of methane based on the Peng-Robinson equation of state and the molecular dynamics simulations. SOCAR Proceedings, 2, 33-40.
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DOI: 10.5510/OGP2021SI200592

E-mail: airat_shayahmeto@mail.ru


T.R. Khisamiev1, I.R. Bashirov3, V.Sh. Mukhametshin2, L.S. Kuleshova2, R.F. Yakupov3, A.M. Vagizov1

1«RN-BashNIPIneft» LLC, Ufa, Russia; 2Ufa State Petroleum Technological University, Ufa, Russia; 3«Bashneft-Dobycha» LLC, Ufa, Russia

Results of the development system optimization and increasing the efficiency of carbonate reserves extraction of the turney stage of the Chetyrmansky deposit


The article is devoted to the issue of optimizing the development system and increasing the efficiency of carbonate deposits of the Tournaisian stage of the Chetyrmanskoye field developing, and the formation of a strategy for their additional development. As a result of the horizontal drilling, the rate of withdrawal from current recoverable reserves in the main area in terms of reserves increased from 0.3 to 5%, which confirms the high efficiency of horizontal wells drilling with multi-stage hydraulic fracturing in reservoirs with high stratification and heterogeneity degree of the productive section in order to increase the rate of reserves production and achieve the approved oil recovery factor, as well as the high efficiency of the proposed methodological approach in the design of the facility development by a system of horizontal wells, the correct choice of the facility development strategy in the design solutions formation.

Keywords: oil fields development; carbonate deposits; development of reserves; multi-stage hydraulic fracturing; horizontal well.

The article is devoted to the issue of optimizing the development system and increasing the efficiency of carbonate deposits of the Tournaisian stage of the Chetyrmanskoye field developing, and the formation of a strategy for their additional development. As a result of the horizontal drilling, the rate of withdrawal from current recoverable reserves in the main area in terms of reserves increased from 0.3 to 5%, which confirms the high efficiency of horizontal wells drilling with multi-stage hydraulic fracturing in reservoirs with high stratification and heterogeneity degree of the productive section in order to increase the rate of reserves production and achieve the approved oil recovery factor, as well as the high efficiency of the proposed methodological approach in the design of the facility development by a system of horizontal wells, the correct choice of the facility development strategy in the design solutions formation.

Keywords: oil fields development; carbonate deposits; development of reserves; multi-stage hydraulic fracturing; horizontal well.

References

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  5. Gareev, A. I., Nurov, S. R., Vagizov, A. M., Sibaev, T. V. (2018). Complex approaches to improving development system of unique Arlanskoye oilfield. Oil Industry, 12, 112-116.
  6. 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.
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  8. 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.
  9. Novikov, M .G., Islamov, A. I., Takhautdinov, R. Sh. (2021). Evolution of production intensification methods in the course of development of deposits in the tournaisian stage of Sheshmaoil company's oilfields: from acid stimulation to hybrid fracturing. Oil. Gas. Innovations, 3(244), 58-61.
  10. Rabaev, R. U., Chibisov, A. V., Kotenev, A. Yu., et al. (2021). Mathematical modelling of carbonate reservoir dissolution and prediction of the controlled hydrochloric acid treatment efficiency. SOCAR Proceedings, 2, 40-46.
  11. 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.
  12. Andreev, A. V., Mukhametshin, V. Sh., Kotenev, Yu. A. (2016). Deposit Productivity Forecast in Carbonate Reservoirs with Hard to Recover Reserves. SOCAR Procеedings, 3, 40-45.
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  17. Economides, J. M., Nolte, K. I. Reservoir stimulation. (2000). West Sussex, England: John Wiley and Sons.
  18. 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.
  19. 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.
  20. Mukhametshin, V. Sh., Zeigman, Yu. V., Andreev, A. V. (2017). Rapid assessment of deposit production capacity for determination of nanotechnologies application efficiency and necessity to stimulate their development. Nanotechnologies in Construction, 9(3), 20–34.
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  23. Veliyev, E. F. (2021). Polymer dispersed system for in-situ fluid diversion. Prospecting and Development of Oil and Gas Fields, 1(78), 61–72.
  24. Mukhametshin, V. V. (2017). Eliminating uncertainties in solving bottom hole zone stimulation tasks. Bulletin of the Tomsk Polytechnic University. Geo Assets Engineering, 328(7), 40–50.
  25. Veliyev, E. F. (2020). Review of modern in-situ fluid diversion technologies. SOCAR Proceedings, 2, 50-66.
  26. Suleimanov, B. A., Veliyev, E. F. (2016). The effect of particle size distribution and the nanosized additives on the quality of annulus isolation in well cementing. SOCAR Proceedings, 4, 4-10.
  27. 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.
  28. Ismayilov, F. S., Ibrahimov, H. M., Abdullayeva, F. Y. (2015). Estimated results of biotechnology application based on formation stimulation at field «Bibiheybat». SOCAR Proceedings, 2, 43-46.
  29. Mardashov, D. V., Rogachev, M. K., Zeigman, Yu. V., Mukhametshin, V. V. (2021). Well Killing Technology before Workover Operation in Complicated Conditions. Energies, 14(3), 654, 1-15.
  30. Rzayeva, S. J. (2019). New microbiological method of oil recovery increase containing highly mineralized water. SOCAR Procеedings, 2, 38-44.
  31. Sergeev, V. V., Belenkova, N. G., Zeigman, Yu. V., Mukhametshin, V. Sh. (2017). Physical properties of emulsion systems with SiO2 nanoparticles. Nanotechnologies in Construction, 9(6), 37–64.
  32. 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.
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  34. 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. Society of Petroleum Engineers.
  35. Sergeev, V.V., Sharapov, R.R., Kudymov, A.Y., Zeigman, Y.V., & Mukhametshin, V.Sh. (2020). Experimental research of the colloidal systems with nanoparticles influence on filtration characteristics of hydraulic fractures. Nanotehnologies in Construction, 12(2), 100–107.
  36. 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.
  37. Kondratyev, S. A., Zhukovsky, A. A., Kochneva, T. S., Malysheva, V. L. (2016). Some experience of the formation proppant fracturine in carbonate reservoirs of Perm region deposits. Oilfield Engineering, 6, 23-26.
  38. 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.
  39. Veliyev, E. F. (2020). Mechanisms of Polymer Retention in Porous Media. SOCAR Procеedings, 3, 126-134.
  40. Mukhametshin, V. V. (2020). Oil Production Facilities Management Improving Using the Analogy Method. SOCAR Proceedings, 4, 42-50.
  41. 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.
  42. Akhmetov, R. T., Malyarenko, A. M., Kuleshova, L. S., et al. (2021). Quantitative assessment of hydraulic tortuosity of oil and gas reservoirs in western siberia based on capillarimetric studies. SOCAR Proceedings, 2, 77-84.
  43. Sun, S. Q. Wan, J.C. (2002). Geological analogs usage rates high in global survey. Oil & Gas Journal, 100(46), 49-50.
  44. 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.
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DOI: 10.5510/OGP2021SI200598

E-mail: vsh@of.ugntu.ru


A.P. Stabinskas1, Sh.Kh. Sultanov1, V.Sh. Mukhametshin1, L.S. Kuleshova1, A.V. Churakov2, A.R. Safiullina1, E.M. Veliev1

1Ufa State Petroleum Technological University, Ufa, Russia; 2Gazpromneft Science & Technology Center, Saint-Petersburg, Russia

Evolution of hydraulic fracturing fluid: from guar systems to synthetic gelling polymers


The paper presents the possibilities of optimizing technological approaches for performing hydraulic fracturing operations, taking into account the transition from traditionally used chemical components of the process fluid to synthetic gelling polymers. The proposed option makes it possible to reduce the unit costs of operational activities to increase oil production both for new assets of oil and gas producing companies and for assets at the stage of industrial development. The special emphasis of the proposed technological solutions is correlated with the environmental Agenda for Sustainable Development until 2030, aimed at transforming the production processes of the energy complex to reduce the ecological footprint of enterprises. A complete set of laboratory studies confirms the prospect of industrial application of synthetic polymer systems and the feasibility of replicating this approach. The subsequent stage of scale-up of pilot tests will allow to have a basis for development and implementation of standards in the oil and gas industry.

Keywords: oil; well; hydraulic fracturing; chemicals; synthetic gelling polymers.

The paper presents the possibilities of optimizing technological approaches for performing hydraulic fracturing operations, taking into account the transition from traditionally used chemical components of the process fluid to synthetic gelling polymers. The proposed option makes it possible to reduce the unit costs of operational activities to increase oil production both for new assets of oil and gas producing companies and for assets at the stage of industrial development. The special emphasis of the proposed technological solutions is correlated with the environmental Agenda for Sustainable Development until 2030, aimed at transforming the production processes of the energy complex to reduce the ecological footprint of enterprises. A complete set of laboratory studies confirms the prospect of industrial application of synthetic polymer systems and the feasibility of replicating this approach. The subsequent stage of scale-up of pilot tests will allow to have a basis for development and implementation of standards in the oil and gas industry.

Keywords: oil; well; hydraulic fracturing; chemicals; synthetic gelling polymers.

References

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  6. Mukhametshin, V. Sh., Zeigman, Yu. V., Andreev, A. V. (2017). Rapid assessment of deposit production capacity for determination of nanotechnologies application efficiency and necessity to stimulate their development. Nanotechnologies in Construction, 9(3), 20–34.
  7. Rabaev, R. U., Chibisov, A. V., Kotenev, A. Yu., et al. (2021). Mathematical modelling of carbonate reservoir dissolution and prediction of the controlled hydrochloric acid treatment efficiency. SOCAR Proceedings, 2, 40-46.
  8. Ibragimov, N. G., Musabirov, M. Kh., Yartiev, A. F. (2015). Tatneft’s experience in commercialization of importsubstituting well stimulation technologies. Oil Industry, 8, 86-89.
  9. Khakimzyanov, I. N., Mukhametshin, V. Sh., Bakhtizin, R. N., Sheshdirov, R. I. (2021). Determination of well spacing volumetric factor for assessment of final oil recovery in reservoirs developed by horizontal wells. SOCAR Proceedings, 2, 47-53.
  10. Yusifov, T. Yu., Fattakhov, I. G., Ziyatdinov, A. M., et al. (2015). Effect of the stress state of reservoir on the formation of hydraulic fracture. Scientific Review, 19, 97-102.
  11. Khakimzyanov, I. N., Mukhametshin, V. Sh., Bakhtizin, R. N., et al. (2021). Justification of necessity to consider well interference in the process of well pattern widening in the Bavlinskoye oil field pashiyan formation. SOCAR Proceedings, SI1, 77-87.
  12. Stabinskas, A. P. (2014). Efficiency estimation of oil well after hydraulic fracturing treatment. Problems of Gathering, Treatment and Transportation of Oil and Oil Products, 1(95), 10-20.
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  14. Shaken, M. Sh. (2020). Problems and methods of hydraulic fracturing in multilayered oil reservoirs with the continuous perforation. SOCAR Proceedings, 3, 66-73.
  15. 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.
  16. Veliyev, E. F., Aliyev, A. A., Mammadbayli, T. E. (2021). Machine learning application to predict the efficiency of water coning prevention techniques implementation. SOCAR Procceedings, 1, 104-113.
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  18. Akhmetov, R. T., Malyarenko, A. M., Kuleshova, L. S., et al. (2021). Quantitative assessment of hydraulic tortuosity of oil and gas reservoirs in western siberia based on capillarimetric studies. SOCAR Proceedings, 2, 77-84.
  19. Mukhametshin, V. Sh., Khakimzyanov, I. N., Bakhtizin, R. N., Kuleshova, L. S. (2021). Differentiation and grouping of complex-structured oil reservoirs in carbonate reservoirs in development management problems solving. SOCAR Proceedings, SI1, 88-97.
  20. Veliyev, E. F. (2020). Review of modern in-situ fluid diversion technologies. SOCAR Proceedings, 2, 50-66.
  21. 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.
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  23. Kuleshova, L. S., Fattakhov, I. G., Sultanov, Sh. Kh., et al. (2021). Experience in conducting multi-zone hydraulic fracturing on the oilfield of PJSC «Tatneft». SOCAR Proceedings, SI1, 68-76.
  24. 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.
  25. Mukhametshin, V. V. (2018). Efficiency estimation of nanotechnologies applied in constructed wells to accelerate field development. Nanotechnologies in Construction, 10(1), 113–131.
  26. Veliyev, E. F. (2021). Polymer dispersed system for in-situ fluid diversion. Prospecting and Development of Oil and Gas Fields, 1(78), 61–72.
  27. Sergeev, V. V., Belenkova, N. G., Zeigman, Yu. V., Mukhametshin, V. Sh. (2017). Physical properties of emulsion systems with SiO2 nanoparticles. Nanotechnologies in Construction, 9(6), 37–64.
  28. 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.
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  30. Khuzin, R. R., Bakhtizin, R. N., Andreev, V. E., et al. (2021). Oil recovery enhancement by reservoir hydraulic compression technique employment. SOCAR Proceedings, SI1, 98-108.
  31. Stabinskas, A. P., Sultanov, Sh. Kh, Khafizov, A. R., Borisov, G. A. (2011). Influence analysis treatered of injection on effectiveness hydraulic fracturing. Petroleum Engineering, 9(3), 45-49.
  32. Sultanov, Sh. Kh., Kotenev, Yu. A., Andreev, V. E., et al. (2012). Geoinformation strategy of fields development with oil reserves difficult to recover. Georesources, 2 (44), 40-43.
  33. Sergeev, V. V., Sharapov, R. R., Kudymov, A. Yu., et al. (2020). Experimental research of the colloidal systems with nanoparticles influence on filtration characteristics of hydraulic fractures. Nanotechnologies in Construction, 12(2), 100–107.
  34. Veliyev, E. F. (2020). Mechanisms of polymer retention in porous media. SOCAR Procеedings, 3, 126-134.
  35. 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.
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  37. Zeigman, Yu. V., Mukhametshin, V. Sh., Sergeev, V. V., Kinzyabaev, F. S. (2017). Experimental study of viscosity properties of emulsion system with SiO2 nanoparticles. Nanotechnologies in Construction, 9(2), 16–38.
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DOI: 10.5510/OGP2021SI200599

E-mail: vsh@of.ugntu.ru


R.T. Akhmetov, L.S. Kuleshova, R.U. Rabaev, V.V. Mukhametshin, A.M. Malyarenko, D.I. Kobishcha, D.I. Akhmetshina

Ufa State Petroleum Technological University, Ufa, Russia

Filtering pore chanels distribution density in Western Siberia


It is well known that information on filter channels distribution density can be obtained based on the data of core samples capillary studies in laboratory conditions. The curve of the fractional participation of pore channels in filtration, as a rule, is obtained by numerical processing of the capillary studies results. In this study, using a generalized mathematical model of capillary curves, an analytical solution is obtained for filtration channels distribution density by size in the conditions of Western Siberia reservoirs. The work shows that the main share in the filtration is taken by pore channels, the sizes of which are close to the maximum value. The density function of the filtering channels is mainly determined by the maximum radius and heterogeneity of the pore channel size distribution.

Keywords: capillary pressure curve; generalized model; distribution density; filtering channels.

It is well known that information on filter channels distribution density can be obtained based on the data of core samples capillary studies in laboratory conditions. The curve of the fractional participation of pore channels in filtration, as a rule, is obtained by numerical processing of the capillary studies results. In this study, using a generalized mathematical model of capillary curves, an analytical solution is obtained for filtration channels distribution density by size in the conditions of Western Siberia reservoirs. The work shows that the main share in the filtration is taken by pore channels, the sizes of which are close to the maximum value. The density function of the filtering channels is mainly determined by the maximum radius and heterogeneity of the pore channel size distribution.

Keywords: capillary pressure curve; generalized model; distribution density; filtering channels.

References

  1. Shmal, G. I. (2017). Oil and gas complex in response to geopolitical and economic challenges: problems and solutions. Oil Industry, 5, 8-11.
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  6. Zeigman, Yu. V., Mukhametshin, V. Sh., Sergeev, V. V., Kinzyabaev, F. S. (2017). Experimental study of viscosity properties of emulsion system with SiO2 nanoparticles. Nanotehnologies in Construction, 9(2), 16–38.
  7. Mardashov, D. V., Rogachev, M. K., Zeigman, Yu. V., Mukhametshin, V. V. (2021). Well killing technology before workover operation in complicated conditions. Energies, 14(3), 654, 1-15.
  8. Sergeev, V. V., Sharapov, R. R., Kudymov, A. Yu., et al. (2020). Experimental research of the colloidal systems with nanoparticles influence on filtration characteristics of hydraulic fractures. Nanotechnologies in Construction, 12(2), 100–107.
  9. Veliyev, E. F., Aliyev, A. A., Mammadbayli, T. E. (2021). Machine learning application to predict the efficiency of water coning prevention techniques implementation. SOCAR Procceedings, 1, 104-113.
  10. 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.
  11. Economides, J. M., Nolte, K. I. (2000). Reservoir stimulation. West Sussex, England: John Wiley and Sons.
  12. Yakupov, R. F., Khakimzyanov, I. N., Mukhametshin, V. V., Kuleshova, L. S. (2021). Hydrodynamic Model Application to Create a Reverse Oil Cone in Water-Oil Zones. SOCAR Proceedings, 2, 54-61.
  13. Khuzin, R. R., Bakhtizin, R. N., Andreev, V. E., et al. (2021). Oil recovery enhancement by reservoir hydraulic compression technique employment. SOCAR Proceedings, SI1, 98-108.
  14. 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.
  15. Abbasov, A. A., Abbasov, E. M., Ismayilov, Sh. Z., Suleymanov, A. A. (2021). Waterflooding efficiency estimation using capacitance-resistance model with non-linear productivity index. SOCAR Procеedings, 3, 45-53.
  16. Khakimzyanov, I. N., Mukhametshin, V. Sh., Bakhtizin, R. N., et al. (2021). Justification of necessity to consider well interference in the process of well pattern widening in the Bavlinskoye oil field pashiyan formation. SOCAR Proceedings, SI1, 77-87.
  17. Veliyev, E. F. (2020). Mechanisms of polymer retention in porous media. SOCAR Procеedings, 3, 126-134.
  18. Veliyev, E. F. (2021). Application of amphiphilic block-polymer system for emulsion flooding. SOCAR Proceedings, 3, 78-86.
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  21. Ter-Sarkisov, R. M., Maksimov, V. M., Basniev, K. S., et al. (2012). Geological and hydrothermodynamic modeling of oil and gas fields. Izhevsk: Izhevsk Institute of Computer Research.
  22. Kuleshova, L. S., Fattakhov, I. G., Sultanov, Sh. Kh., et al. (2021). Experience in conducting multi-zone hydraulic fracturing on the oilfield of PJSC «Tatneft». SOCAR Proceedings, SI1, 68-76.
  23. 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.
  24. Muslimov, R. Kh. (2014). Oil recovery: past, present, future (production optimization, maximization of oil recovery). Kazan: FEN.
  25. Rabaev, R. U., Chibisov, A. V., Kotenev, A. Yu., et al. (2021). Mathematical modelling of carbonate reservoir dissolution and prediction of the controlled hydrochloric acid treatment efficiency. SOCAR Proceedings, 2, 40-46.
  26. 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.
  27. 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.
  28. Mukhametshin, V. Sh., Khakimzyanov, I. N., Bakhtizin, R. N., Kuleshova, L. S. (2021). Differentiation and grouping of complex-structured oil reservoirs in carbonate reservoirs in development management problems solving. Socar Proceedings, SI1, 88-97.
  29. Mukhametshin, V. V. (2020). Oil production facilities management improving using the analogy method. SOCAR Proceedings, 4, 42-50.
  30. 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.
  31. Sun, S. Q., Wan, J. C. (2002). Geological analogs usage rates high in global survey. Oil & Gas Journal, 100(46), 49-50.
  32. 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.
  33. Akhmetov, R. T., Malyarenko, A. M., Kuleshova, L. S., et al. (2021). Quantitative assessment of hydraulic tortuosity of oil and gas reservoirs in Western Siberia based on capillarimetric studies. SOCAR Proceedings, 2, 77-84.
  34. 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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  37. Mukhametshin, V. V. (2018). Rationale for trends in increasing oil reserves depletion in Western Siberia cretaceous deposits based on targets identification. Bulletin of the Tomsk Polytechnic University. Geo Assets Engineering, 329(5), 117–124.
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DOI: 10.5510/OGP2021SI200600

E-mail: vv@of.ugntu.ru


V. A. Grishchenko¹,², T. V. Pozdnyakova¹, B. M. Mukhamadiyev¹, V. V. Mukhametshin², R. N. Bakhtizin², L. S. Kuleshova², R. F. Yakupov²

¹«RN-BashNIPIneft» LLC, Ufa, Russia; ²Ufa State Petroleum Technological University, Ufa, Russia; ³«Bashneft-Dobycha» LLC, Ufa, Russia

Improving the carbonate reservoirs development efficiency on the example of the Tournaisian stage deposits


The article deals with the issue of carbonate strata of complex geological structure development efficiency improving. Such facilities, as a rule, have deteriorated reservoir properties, parameter anisotropy and are complicated by secondary cavernosity. All of these factors affect the recovery efficiency and are often reflected in development indicators. On the example of Tournaisian stage deposits an example of a methodological approach to the development analysis which takes into consideration various geological factors is presented. As a result, various dependencies were obtained, which when taken into account determin the most promising areas in terms of development efficiency. The issues of the waterflooding system efficiency and the ways of its efficiency increasing are considered separately.

Keywords: oil fields development; carbonate reservoirs; development efficiency; waterflooding system.

The article deals with the issue of carbonate strata of complex geological structure development efficiency improving. Such facilities, as a rule, have deteriorated reservoir properties, parameter anisotropy and are complicated by secondary cavernosity. All of these factors affect the recovery efficiency and are often reflected in development indicators. On the example of Tournaisian stage deposits an example of a methodological approach to the development analysis which takes into consideration various geological factors is presented. As a result, various dependencies were obtained, which when taken into account determin the most promising areas in terms of development efficiency. The issues of the waterflooding system efficiency and the ways of its efficiency increasing are considered separately.

Keywords: oil fields development; carbonate reservoirs; development efficiency; waterflooding system.

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  17. Yakupov, R. F., Khakimzyanov, I. N., Mukhametshin, V. V., Kuleshova, L. S. (2021). Hydrodynamic model application to create a reverse oil cone in water-oil zones. SOCAR Proceedings, 2, 54-61.
  18. Abbasov, A. A., Abbasov, E. M., Ismayilov, Sh. Z., Suleymanov, A. A. (2021). Waterflooding efficiency estimation using capacitance-resistance model with non-linear productivity index. SOCAR Procеedings, 3, 45-53.
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  25. Mukhametshin, V. V. (2018). Rationale for trends in increasing oil reserves depletion in Western Siberia cretaceous deposits based on targets identification. Bulletin of the Tomsk Polytechnic University. Geo Assets Engineering, 329(5), 117–124.
  26. Khakimzyanov, I. N., Mukhametshin, V. Sh., Bakhtizin, R. N., et al. (2021). Justification of necessity to consider well interference in the process of well pattern widening in the Bavlinskoye oil field pashiyan formation. SOCAR Proceedings, SI1, 77-87.
  27. Veliyev, E. F., Aliyev, A. A., Mammadbayli, T. E. (2021). Machine learning application to predict the efficiency of water coning prevention techniques implementation. SOCAR Procceedings, 1, 104-113.
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  29. Mukhametshin, V. V. (2020). Oil production facilities management improving using the analogy method. SOCAR Proceedings, 4, 42-50.
  30. 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.
  31. 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.
  32. Muslimov, R. Kh. (2008). Methods of increasing an oil fields development efficiency at a late stage. Oil Industry, 3, 30-35.
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  40. Veliyev, E. F. (2020). Review of modern in-situ fluid diversion technologies. SOCAR Proceedings, 2, 50-66.
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  42. 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.
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DOI: 10.5510/OGP2021SI200603

E-mail: vv@of.ugntu.ru


V.A. Grishchenko, I.N. Asylgareev, R.N. Bakhtizin, V.V. Mukhametshin, R.F. Yakupov

Ufa State Petroleum Technological University, Ufa, Russia

Methodological approach to the resource base efficiency monitoring in oil fields development


The article discusses the issue of resource base management in a complex structure of residual reserves. To increase the efficiency of the reserves development, constant monitoring of their distribution is necessary - how much they are involved, is there any potential for additional involvement, how efficient are the areas already involved in development. The paper proposes a methodological approach to the residual reserves control process organization, which allows planning and adjusting the program of reserves development. This is of particular relevance for companies that develop assets in the late stages of development, which do not have the ability to indiscriminate drilling. On the example of one of the enterprises developing assets in the Volga-Ural oil and gas province, the structuring of residual reserves was carried out, on the basis of which a strategy for increasing the reserves involvement in development was formed. To analyze the efficiency of reserves recovery in the involved areas, a reserve utilization factor based on the displacement forecast is proposed. Its implementation made it possible to identify problem areas, on the example of one of which a highly effective program for drilling horizontal wells was subsequently implemented.

Keywords: oil fields development; oil reserves; resource management; reserves development; horizontal wells.

The article discusses the issue of resource base management in a complex structure of residual reserves. To increase the efficiency of the reserves development, constant monitoring of their distribution is necessary - how much they are involved, is there any potential for additional involvement, how efficient are the areas already involved in development. The paper proposes a methodological approach to the residual reserves control process organization, which allows planning and adjusting the program of reserves development. This is of particular relevance for companies that develop assets in the late stages of development, which do not have the ability to indiscriminate drilling. On the example of one of the enterprises developing assets in the Volga-Ural oil and gas province, the structuring of residual reserves was carried out, on the basis of which a strategy for increasing the reserves involvement in development was formed. To analyze the efficiency of reserves recovery in the involved areas, a reserve utilization factor based on the displacement forecast is proposed. Its implementation made it possible to identify problem areas, on the example of one of which a highly effective program for drilling horizontal wells was subsequently implemented.

Keywords: oil fields development; oil reserves; resource management; reserves development; horizontal wells.

References

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  2. 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.
  3. Khakimzyanov, I. N., Mukhametshin, V. Sh., Bakhtizin, R. N., et al. (2021). Justification of necessity to consider well interference in the process of well pattern widening in the Bavlinskoye oil field pashiyan formation. SOCAR Proceedings, SI1, 77-87.
  4. Veliyev, E. F. (2020). Review of modern in-situ fluid diversion technologies. SOCAR Proceedings, 2, 50-66.
  5. Khatmullin, I. F., Khatmullina, E. I., Khamitov, A. T., et al. (2015). Identification of zones with poor displacement in fields with hard-to-recover reserves. Oil Industry, 1, 74-79.
  6. Mukhametshin, V. V. (2020). Oil production facilities management improving using the analogy method. SOCAR Proceedings, 4, 42-50.
  7. 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.
  8. Abbasov, A. A., Abbasov, E. M., Ismayilov, Sh. Z., Suleymanov, A. A. (2021). Waterflooding efficiency estimation using capacitance-resistance model with non-linear productivity index. SOCAR Procеedings, 3, 45-53.
  9. Yakupov, R. F., Khakimzyanov, I. N., Mukhametshin, V. V., Kuleshova, L.S. (2021). Hydrodynamic model application to create a reverse oil cone in water-oil zones. SOCAR Proceedings, 2, 54-61.
  10. 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.
  11. Veliyev, E. F., Aliyev, A. A., Mammadbayli, T. E. (2021). Machine learning application to predict the efficiency of water coning prevention techniques implementation. SOCAR Procceedings, 1, 104-113.
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  18. Mukhametshin, V. Sh., Khakimzyanov, I. N., Bakhtizin, R. N., Kuleshova, L. S. (2021). Differentiation and grouping of complex-structured oil reservoirs in carbonate reservoirs in development management problems solving. SOCAR Proceedings, SI1, 88-97.
  19. Muslimov, R. Kh. (2008). Methods of increasing an oil fields development efficiency at a late stage. Oil Industry, 3, 30-35.
  20. 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.
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  24. Khuzin, R. R., Bakhtizin, R. N., Andreev, V. E., et al. (2021). Oil recovery enhancement by reservoir hydraulic compression technique employment. SOCAR Proceedings, SI11, 98-108.
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  26. Rabaev, R. U., Chibisov, A. V., Kotenev, A. Yu., et al. (2021). Mathematical modelling of carbonate reservoir dissolution and prediction of the controlled hydrochloric acid treatment efficiency. SOCAR Proceedings, 2, 40-46.
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  36. Minnikhanov, R. N., Maganov, N. U., Khisamov, R. S. (2016). On creation of research and testing facilities to promote study of nonconventional oil reserves in Tatarstan. Oil Industry, 8, 60-63.
  37. Kuleshova, L. S., Fattakhov, I. G., Sultanov, Sh. Kh., et al. (2021). Experience in conducting multi-zone hydraulic fracturing on the oilfield of PJSC «Tatneft». SOCAR Proceedings, SI1, 68-76.
  38. Khakimzyanov, I. N., Mukhametshin, V. Sh., Bakhtizin, R. N., Sheshdirov, R. I. (2021). Determination of well spacing volumetric factor for assessment of final oil recovery in reservoirs developed by horizontal wells. SOCAR Proceedings, 2, 47-53.
  39. Veliyev, E. F. (2020). Mechanisms of polymer retention in porous media. SOCAR Procеedings, 3, 126-134.
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DOI: 10.5510/OGP2021SI200604

E-mail: denisova.anrb@mail.ru


S.V. Galkin1, Ia.V.Savitckii1, I.Ju. Kolychev1, A.S. Votinov2

1Perm National Research Polytechnic University, Perm, Russia; 2Perm PermNIPIneft branch of «LUKOIL-Engineering» LLC in Perm, Perm, Russia

Prospects for the application of proppant hydraulic fracturing at Kashiro-Verey operational facilities Volga-Ural oil and gas province


The geological structure of Kashiro-Verey carbonate deposits is considered on the example of one of the deposits of the Perm Region. By combining geophysical studies of wells, standard and tomographic studies of core, the following lithotypes of carbonate rocks were identified: highly porous cavernous, layered heterogeneous porous, heterogeneous fractured porous, dense. It was found that for heterogeneous lithotypes, the porosity estimate in the volume of the permeable part of the rocks significantly exceeds 7%. Experiments on the destruction of rocks were carried out for the selected lithotypes. As a result, it was found that cracks do not form for samples of the cavernous lithotype at a compression pressure of 20 MPa. For a compacted lithotype, already at a compression pressure of more than 10 MPa, an intensive development of fracturing occurs. As a result of multiaxial loading of cores, which can be considered as analogous fracturing of the formation, wide fractures are formed, along which filtration of fluids can occur.

Keywords: proppant hydraulic fracturing; X-ray tomography of the core; porosity; permeability; fractured reservoir; oil deposit; carbonate deposits.

The geological structure of Kashiro-Verey carbonate deposits is considered on the example of one of the deposits of the Perm Region. By combining geophysical studies of wells, standard and tomographic studies of core, the following lithotypes of carbonate rocks were identified: highly porous cavernous, layered heterogeneous porous, heterogeneous fractured porous, dense. It was found that for heterogeneous lithotypes, the porosity estimate in the volume of the permeable part of the rocks significantly exceeds 7%. Experiments on the destruction of rocks were carried out for the selected lithotypes. As a result, it was found that cracks do not form for samples of the cavernous lithotype at a compression pressure of 20 MPa. For a compacted lithotype, already at a compression pressure of more than 10 MPa, an intensive development of fracturing occurs. As a result of multiaxial loading of cores, which can be considered as analogous fracturing of the formation, wide fractures are formed, along which filtration of fluids can occur.

Keywords: proppant hydraulic fracturing; X-ray tomography of the core; porosity; permeability; fractured reservoir; oil deposit; carbonate deposits.

References

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  23. Efimov, A. A., Galkin, S. V., Savitckii, Ia. V., et al. (2016). Study of wettability of reservoirs of oil fields by the method of x-ray tomography core. SOCAR Proceedings, 4, 55-63.
  24. Berg, S., Armstrong, R., Ott, H., et al. (2014) Multiphase flow in porous rock imaged under dynamic flow conditions with fast x-ray computed microtomography. Petrophysics, 55(4), 304-312.
  25. Krivoshchekov, S. N., Kochnev, A. À. (2013). The experience of using x-ray tomography to study the properties of rocks. Perm Journal of Petroleum and Mining Engineering, 12(6), 32-42.
  26. Cherepanov, S. S., Ponomareva, I. N., Erofeev, A. A., Galkin, S. V. (2014). Determination of fractured rock parameters based on a comprehensive analysis of the data core studies, hydrodynamic and geophysical well tests. Oil Industry, 2, 94-96.
  27. Mordvinov, V. A., Martyushev, D. A., Ladeishchikova, T. S., Gorlanov, N. P. (2015). Assessment of the effect of natural fracturing of the reservoir on the productivity dynamics of producing wells of the Ozernoye field. Perm Journal of Petroleum and Mining Engineering, 14 (14), 32-38.
  28. Martyushev, D. A., Yurikov, A. (2021). Evaluation of opening of fractures in the Logovskoye carbonate reservoir, Perm Krai, Russia. Petroleum Research, 6(2), 137-143.
  29. Seredin, V. V., Parshina, T. Y., Rastegaev, A. V., et al. (2018) Changes of energy potential on clay particle surfaces at high pressures. Applied Clay Science, 155, 8-14.
  30. Seredin, V. V., Andrianov, A. V., Gaynanov, S. Kh., et al. (2021) Formation of the kaolin structure treated by pressure. Perm Journal of Petroleum and Mining Engineering, 21(1), 9-16.
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DOI: 10.5510/OGP2021SI200605

E-mail: doc_galkin@mail.ru


M.М. Irani, V.P. Telkov

Gubkin Russian State University of Oil and Gas (National Research University), Moscow, Russia

Study of modern options for using combinations of gasflooding and traditional waterflooding (water-gas influence and its alternative)


Water-gas influence (WGI) is an oil recovery method improving displacement ratio, sweep efficiency and adjusting the alignment of displacement. This study is a review of the traditional WAG methods (Immiscible WAG, Hybrid WAG, Simultaneous WAG and Selective Simultaneous WAG), including with stabilizing surfactants, WAG. We also consider such sparsely used methods as: SSWAG, FAWAG, CWAG, TWAG, VR-WAG, Up- and Down-dip WAG, HC-WAG, PAG, SAG, WASP, LSW WAG, LSASF, SMSW-AGF and others. The advantages and disadvantages of these tools are considered.

Keywords: water-gas influence (WGI); WAG; SWAG; enhanced oil recovery; APG utilization.

Water-gas influence (WGI) is an oil recovery method improving displacement ratio, sweep efficiency and adjusting the alignment of displacement. This study is a review of the traditional WAG methods (Immiscible WAG, Hybrid WAG, Simultaneous WAG and Selective Simultaneous WAG), including with stabilizing surfactants, WAG. We also consider such sparsely used methods as: SSWAG, FAWAG, CWAG, TWAG, VR-WAG, Up- and Down-dip WAG, HC-WAG, PAG, SAG, WASP, LSW WAG, LSASF, SMSW-AGF and others. The advantages and disadvantages of these tools are considered.

Keywords: water-gas influence (WGI); WAG; SWAG; enhanced oil recovery; APG utilization.

References

  1. Telkov, V. P. (2009). Razrabotka tekhnologii vodogazovogo vozdejstviya na plast putyom nasosno-ezhektornoj i nasosno-kompressornoj zakachki vodogazovyh smesej s penoobrazuyushchimi PAV. Dissertaciya na soiskanie uchenoj stepeni kandidata tekhnicheskih nauk. Moskva: RGU Nefti i Gaza im. I.M. Gubkina.
  2. Christensen, J. R., Stenby, E. H., Skauge, A. (1998, March). Review of WAG field experience. SPE-39883-MS. In: SPE International Petroleum Conference and Exhibition of Mexico. Society of Petroleum Engineers.
  3. Darvishnezhad, M. J., Jannatrostami, A., Montazeri, G. H. (2010, June). SPE-132847-MS. Study of various water alternating gas injection methods in 4-and 5-spot injection patterns in an iranian fractured reservoir. In: Trinidad and Tobago Energy Resources Conference. Society of Petroleum Engineers.
  4. Afzali, S., Rezaei, N., Zendehboudi, S. (2018). A comprehensive review on enhanced oil recovery by water alternating gas (WAG) injection. Fuel, 227, 218-246.
  5. Graham, A. J., Christie, M. A., Al-Haboobi, Z. I. M. (2020). Calibrating the todd and longstaff mixing parameter value for miscible finite-sized slug WAG injection for application on a field scale. SPE Reservoir Evaluation and Engineering, 23, 479–497.
  6. Choudhary, M. K., Parekh, B., Dezabala, E., et al. (2011, November). Design, implementation and performance of a down-dip WAG pilot. IPTC-14571-MS. In: International Petroleum Technology Conference. Society of Petroleum Engineers.
  7. Zhao, X.-W., Ning, L.C.-L., Ding, X.-L., et al. (2013, October). Study on enhanced oil recovery technology in low permeability heterogeneous reservoir by water-alternate-gas of CO2 flooding. SPE-165907-MS. In: SPE Asia Pacific Oil and Gas Conference and Exhibition. Society of Petroleum Engineers.
  8. Mousavi, S. M. (2011, July). Investigation of different I-WAG schemes toward optimization of displacement efficiency. SPE-144891-MS. In: SPE Enhanced Oil Recovery Conference. Society of Petroleum Engineers.
  9. Netaifi, A. S. Al, Cinar, Y. (2015, March). Experimental investigation of three-phase immiscible floods during gas gravity drainage in naturally fractured reservoirs. SPE-172816-MS. In: SPE Middle East Oil & Gas Show and Conference. Society of Petroleum Engineers.
  10. Holtz, M. H. (2016, April). Immiscible water alternating gas (IWAG) EOR: current state of the art. SPE-179604-MS. In: SPE Improved Oil Recovery Conference. Society of Petroleum Engineers.
  11. Han, L., Gu, Y. (2014). Optimization of miscible CO2 water-alternating-gas injection in the Bakken formation. Energy and Fuels, 28(11), 6811–6819.
  12. Ning, S. X., Jhaveri, B. S., Fueg, E. M., et al. (2016, May). Optimizing the utilization of miscible injectant at the Greater Prudhoe Bay fields. SPE-180420-MS. In: SPE Western Regional Meeting. Society of Petroleum Engineers.
  13. Sohrabi, M., Tehrani, D. H., Al-Abri, M. (2007, September). Performance of near-miscible gas and SWAG injection in a mixed-wet core. In: International Symposium of the Society of Core Analysts held in Calgary, Canada.
  14. Hong, K. C., Co, C.O.F.R., Stevens, C. (1992). Water alternating steam process improves project economics at West Coalinga field. SPE Reservoir Engineering,7(04), 407-413.
  15. Tunio, S. Q., Chandio, T. A. (2012). Recovery enhancement with application of FAWAG for a Malaysian field. Research Journal of Applied Sciences, Engineering and Technology, 4(1), 8–10.
  16. Bagrezaie, M. A., Pourafshary, P., Gerami, S. (2014, March). Study of different water alternating carbon dioxide injection methods in various injection patterns in an Iranian non fractured carbonate reservoir. OTC-24793-MS. In: Offshore Technology Conference-Asia. Society of Petroleum Engineers.
  17. Sagir, M., Tan, I.M., Mushtaq, M., Nadeem, M. (2014). Novel CO2 philic surfactants for CO2 mobility control for enhanced oil recovery applications. In: SPE EOR Conference at Oil and Gas West Asia 2014: Driving Integrated and Innovative EOR. Society of Petroleum Engineers.
  18. Gong, J., Vincent-Bonnieu, S., Bahrim, R. Z. K., et al. (2019). Modeling of liquid injectivity in surfactant-alternating-gas foam enhanced oil recovery. SPE Journal, 24, 1123–1138.
  19. Gong, J., Vincent-Bonnieu, S., Bahrim, R. Z. K., et al. (2020). Laboratory investigation of liquid injectivity in surfactant-alternating-gas foam enhanced oil recovery. Transport in Porous Media, 131(1), 85–99.
  20. McGuire, P. L. (2005, March-April). Viscosity reduction WAG: an effective EOR process for North Slope viscous oils. SPE-93914-MS. In: SPE Western Regional Meeting. Society of Petroleum Engineers.
  21. Al-Shalabi, E. W., Sepehrnoori, K., Pope, G. (2014, December). Modeling the combined effect of injecting low salinity water and carbon dioxide on oil recovery from carbonate cores. IPTC-17862-MS. In: International Petroleum Technology Conference. Society of Petroleum Engineers.
  22. Bagrezaie, M. A., Pourafshary, P. (2014, November). Screening different water alternating carbon dioxide injection scenarios to achieve to the highest macroscopic sweep efficiency in a non fractured carbonate reservoir. SPE-172267-MS. In: SPE Annual Caspian Technical Conference and Exhibition. Society of Petroleum Engineers.
  23. Abbas, A. H., Abdullah, D. S., Jaafar, M. Z., et al. (2020). Comparative numerical study for polymer alternating gas (PAG) flooding in high permeability condition. SN Applied Sciences, 2(5).
  24. Dandan, H., Yuanbing, W. (2017, March). Optimization and design for WAG-CO2 combined with soft micro gel SMG in complicated carbonate reservoirs containing with high permeability streaks. SPE-183723-MS. In: SPE Middle East Oil & Gas Show and Conference. Society of Petroleum Engineers.
  25. Afsharpoor, A., Lee, G.S., & Kam, S.I. (2010). Mechanistic simulation of continuous gas injection period during surfactant-alternating-gas (SAG) processes using foam catastrophe theory. Chemical Engineering Science, 65(11), 3615–3631.
  26. Farajzadeh, R., Eftekhari, A. A., Hajibeygi, H., et al. (2016). Simulation of instabilities and fingering in surfactant alternating gas (SAG) foam enhanced oil recovery. Journal of Natural Gas Science and Engineering, 34, 1191–1204.
  27. Al-Saedi, H. N., Long, Y., Flori, R. E., Bai, B. (2019). Coupling smart seawater flooding and CO2 flooding for sandstone reservoirs: smart seawater alternating CO2 flooding (SMSW-AGF). Energy and Fuels, 33(10), 9644–9653.
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DOI: 10.5510/OGP2021SI200606

E-mail: telkov_viktor@mail.ru


T.S. Sultanmagomedov, R.N. Bakhtizin, S.M. Sultanmagomedov, T.M. Halikov

Ufa State Petroleum Technological University, Ufa, Russia

Research of throwing areols of underground pipeline in permafrost


Study is due to the possibility of loss of stability of the pipeline in the process of pumping a product with a positive operating temperature and the formation of thawing halos. The article presents the ways of solving the thermomechanical problem of pipeline displacement due to thawing. The rate of formation of a thawing halo is investigated depending on the initial temperatures of the soil and the pumped product. The developed monitoring system makes it possible to study the rate of occurrence of thawing halos in the process of pumping the product. An experimental study on the formation of thawing halos around the pipeline was carried out on an experimental model. A thermophysical comparative calculation of temperatures around the pipeline on a model by the finite element method has been carried out.

Keywords: underground pipeline; permafrost; thawing halo; monitoring; operating conditions; stress–strain state.

Study is due to the possibility of loss of stability of the pipeline in the process of pumping a product with a positive operating temperature and the formation of thawing halos. The article presents the ways of solving the thermomechanical problem of pipeline displacement due to thawing. The rate of formation of a thawing halo is investigated depending on the initial temperatures of the soil and the pumped product. The developed monitoring system makes it possible to study the rate of occurrence of thawing halos in the process of pumping the product. An experimental study on the formation of thawing halos around the pipeline was carried out on an experimental model. A thermophysical comparative calculation of temperatures around the pipeline on a model by the finite element method has been carried out.

Keywords: underground pipeline; permafrost; thawing halo; monitoring; operating conditions; stress–strain state.

References

  1. Chadburn, S. E., Burke, E. J., Cox, P. M., et al. (2017). An observation–based constraint on permafrost loss as a function of global warming. Nature Climate Change, 7(5), 340–344.
  2. The Intergovernmental Panel on Climate Change. (2021). https://www.ipcc.ch/sr15/chapter/chapter–1
  3. Riseborough, D., Shiklomanov, N., Etzelmuller, B., et al. (2008) Recent advances in permafrost modelling. Permafrost and Periglac. Process, 19, 137–156.
  4. Novikov, P. A. (2016). Identification of dangerous sections of main oil pipelines based on long–term forecasting of the thawing halo of permafrost soils. PhD Thesis. Ufa: USPTU.
  5. P609–86. (1987). Recommendations for predicting the dynamics of thermal and mechanical interaction of pipelines with thawing soils. Moscow: VNIIST.
  6. Nishimura, S., Gens, A., Olivella, S., Jardine, R. J. (2009). THM–coupled finite element analysis of frozen soil: formulation and application. Ge´otechnique, 59(3), 159–171.
  7. Li, H., Lai, Y., Wang, L., et al. (2018). Review of the state of the art: interactions between a buried pipeline and frozen soil. Cold Regions Science and Technology, 157, 171–186.
  8. Garris, N. A., Rusakov, A.I., Lebedeva, A.A. (2018). Balanced heat exchange of oil pipeline in permafrost calculation and thawing halo radius determination. Petroleum Engineering, 16(5), 73–80.
  9. Garris, N. A., Kutlyeva, Z. R., Baeva, G. N. (2018). Algorithm for the process of thawing–freezing soil regulating around the ground pipeline in permafrost. Petroleum Engineering, 16(6), 46–55.
  10. Garris, N. A., Akchurina, E. A., Rusakov, A. I. (2018). Сonjugate problem of controlled heat exchange of oil pipeline in permafrost. Petroleum Engineering, 16(1), 54–61.
  11. Zhao, Y., Bo, Y., Yu, G., Li, W. (2014). Study on the water–heat coupled phenomena in thawing frozen soil around a buried oil pipeline. Applied Thermal Engineering, 73, 1477–1488.
  12. Xu, J., Abdalla, B., Eltaher, A., Jukes, P. (2009). Permafrost thawing–pipeline interaction advanced finite element model. Paper OMAE2009–79554. In: International Conference on Ocean, Offshore and Arctic Engineering.
  13. Bakhtizin, R. N., Sultanomagomedov, S. M., Sultanmagomedov, T. S., et al. (2020). Experimental studies of the resistance of frozen soil to longitudinal displacements of the pipeline with changes in temperature and humidity. Science and Technology of Pipeline Transport and Oil Products, 3, 243–251.
  14. Wen, Z., Sheng, Y., Jin, H., et al. (2010). Thermal elasto–plastic computation model for a buried oil pipeline in frozen ground. Cold Regions Science and Technology, 64(3), 248–255.
  15. Sultanmagomedov, T. S., Bakhtizin, R. N., Sultanmagomedov, S. M., Urmanova, A. R. (2021). Simulation of pipeline axial displacement in frozen soils. Bulletin of the Tomsk Polytechnic University. Geo Assets Engineering, 4, 87–96.
  16. Sultanmagomedov, T. S., Bakhtizin, R. N., Sultanmagomedov, S. M. (2020). Experimental Study of pipeline movements in permafrost soils. SOCAR Proceedings, 4, 75–84.
  17. Liu, B., Moffitt, K., Nixon, J. F., et al. (2004, October). Numerical studies of pipeline uplift resistance in frozen ground. Paper IPC2004–0137. In: International Pipeline Conference.
  18. Primakov, S. S., Zholobov, I. A. (2014). Measurement of the thermal conductivity of frozen soils in the range of practically significant temperature. Oil Economy, 9, 55–57.
  19. Primakov, S. S., Vershinin, V. E., Zholobov, I. A. (2013). Thermal power interaction hot buried pipeline with permafrost soils. Oil Economy, 11, 128–131.
  20. Fang, L., Yu, B., Li, J., et al. (2017). Numerical analysis of frozen soil around the mohe–daqing crude oil pipeline with thermosyphons. Heat Transfer Engineering, 39(7–8), 630–641.
  21. Gulin, D. A., Fayzullina, E. V., Sharipova, E. I., et al. (2021). Analysis of the stress–strain state of the pipeline in the areas of frost heaving of the soil using the SCAD software package. In: IOP Conference Series: Earth and Environmental Science.
  22. Shamilov, Kh. Sh., Sultanmagomedov, T. S., Sultanmagomedov, S. M. (2021). Design of the support for underground pipeline fastening in conditions of insular and discontinuous permafrost zones. Bulletin of the Tomsk Polytechnic University. Geo Assets Engineering, 1, 31–40.
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DOI: 10.5510/OGP2021SI200594

E-mail: tsultanmaga@gmail.com


G.G. Gilaev1, M.Ya. Khabibullin2, R.N. Bakhtizin3

1Kuban State Technological University,Institute of Oil, Gas and Energy, Krasnodar, Russia; 2Oktyabrskiy Affiliate of Ufa State Petroleum Technological University, Oktyabrskiy, Russia; 3Ufa State Petroleum Technological University, Ufa, Russia

Research of the resistance process of casing column filters at their contact with rock


The analysis of theoretical solutions and experimental data given in numerous literatures to justify the choice of the ratio of the size of gravel in relation to the size of formation sand showed that with the development of experimental methods and the accumulation of laboratory and field data, this ratio tends to decrease. When installing filters in an open hole, pressure losses at the interface between gravel and the formation play a significant role, and it should be noted that the greatest productivity and efficiency of the filter in an open hole is achieved when there is a packing around it, which can be created by crushing the sandy massif of the formation by cyclical changes debit. When choosing a filter design, along with the ability to provide them with a reliable hydraulic connection in the reservoir-filter system, the main task is also solved - to prevent sand flow into the well. The study of the conditions for the removal of sand particles through the flow sections in perforated, mesh and slotted filters during their operation both in homogeneous and in sands of different size, made it possible to recommend empirical dependences for determining the size of the holes.

Keywords: porous medium; coarse fraction; sand; particle; well.

The analysis of theoretical solutions and experimental data given in numerous literatures to justify the choice of the ratio of the size of gravel in relation to the size of formation sand showed that with the development of experimental methods and the accumulation of laboratory and field data, this ratio tends to decrease. When installing filters in an open hole, pressure losses at the interface between gravel and the formation play a significant role, and it should be noted that the greatest productivity and efficiency of the filter in an open hole is achieved when there is a packing around it, which can be created by crushing the sandy massif of the formation by cyclical changes debit. When choosing a filter design, along with the ability to provide them with a reliable hydraulic connection in the reservoir-filter system, the main task is also solved - to prevent sand flow into the well. The study of the conditions for the removal of sand particles through the flow sections in perforated, mesh and slotted filters during their operation both in homogeneous and in sands of different size, made it possible to recommend empirical dependences for determining the size of the holes.

Keywords: porous medium; coarse fraction; sand; particle; well.

References

  1. Bliznyukov, V. Yu., Gilaev, A. G., Gilaev, G. G. (2010). Analysis of production casing disturbances during the development of sand-producing productive formations with abnormally high reservoir pressures. Construction of oil and gas wells onshore and offshore, 6, 50-54.
  2. Gilaev, G. G. (2004). Development of theory and practice of production of hard-to-recover hydrocarbon reserves in complex fields. Dissertation for the degree of Doctor of Technical Sciences. Tyumen.
  3. Gilaev, Gen. G., Khabibullin, M. Ya., Gilaev, G. G. (2020). Prospects for the use of acid gel for proppant injection in the process of hydraulic fracturing of carbonate formations in the Samara region. Oil industry, 8, 54-57.
  4. Rabaev, R. U., Bakhtizin, R. N., Sultanov, Sh. Kh. et al. (2020). Substantiation of application of acid fracturing technology in carbonate reservoirs of offshore gas condensate fields. SOCAR Proceedings, 4, 60-67.
  5. Sultanmagomedov, T. S., Bakhtizin, R. N., Sultanmagomedov, S. M. (2020). Study of pipeline movements in permafrost soils. SOCAR Proceedings, 4, 75-83.
  6. Moiseev, K. V., Kuleshov, V. S., Bakhtizin, R. N. (2020). Free convection of a linearly inhomogeneous liquid in a square cavity under lateral heating. SOCAR Proceedings, 4, 108-116.
  7. Gilaev, Gen. G., Khabibullin, M. Ya., Gilaev, G. G. (2020). The main aspects of using acid gel for proppant injection during hydraulic fracturing operations on carbonate reservoirs in the Volga-Ural region. SOCAR Proceedings, 4, 33-41.
  8. Bakhtizin, R. N., Karimov, R. M., Mastobaev, B. N. (2016). Generalized flow curve and universal rheological model of oil. SOCAR Proceedings, 2, 43-49.
  9. Klimov, V. V. (2014). Interpretation of casing profile data. Accuracy and instrumental consistency for wells of arbitrary profile. Oil & Gas Journal Russia, 5 (83), 36 - 39.
  10. Bliznyukov, V. Yu., Gilaev, A. G., Islamov, R. F. et al. (2010). Methods for preventing and eliminating sand production in production wells. Onshore and offshore oil and gas well construction, 9, 15-21.
  11. Bliznyukov, Yu. V., Gilaev, A. G., Gilaev, G. G. et al. (2010). Sand production in production wells and casing failure. assessment of the regularities of the distribution of reservoir, pore pressures along the section of the wells of the Sladkovsko-Morozov group of fields. Construction of oil and gas wells onshore and offshore, 1, 17-22.
  12. Privalikhin, R. S. (2011). Stress state in the contact zone of two cylindrical bodies of finite length. General problems of mechanical engineering. Siberian Federal University, Krasnoyarsk, 10, 599 – 603.
  13. Bliznyukov, Yu. V., Gilaev, A. G., Mollaev, Z. Kh. et al. (2010). Influence of physical and mechanical properties of the reservoir and the drop in reservoir pressure on sand production. Petroleum Engineer, 3, 5-9.
  14. Khabibullin, M. Ya. (2020). Improving the process of hydrochloric acid treatment of wells using the latest technologies and equipment. Bulletin of the Tomsk Polytechnic University. Engineering of Georesources, 331 (10), 128-134.
  15. Firme, P. A., Pereira, F. L., Roehl, D., Romanel, C. (2016). A probabilistic assessment of the casing integrity in a Pre-salt wellbore. 50th US Rock Mechanics Geomechanics Symposium, 3, 2555-2564.
  16. Lee, H., Ong, S., Azeemuddin, M. (2012). A wellbore stability model for formations with anisotropic rock strengths. Journal of Petroleum Science and Engineering, 96-97, 109-119.
  17. Aregbe, A. G. (2017). Wellbore Stability Problems in Deepwater Gas Wells. World Journal of Engineering and Technology, 5 (4), 626-647.
  18. Gilaev, G. G., Manasyan, A. E., Fedorchenko, G. D. et al. (2013). Oil deposits in carbonate deposits of the Famennian stage of the Samara region: history of discovery and prospect of prospecting. Oil industry, 10, 38-40.
  19. Bliznyukov, V. Yu., Gilaev, A. G., Gilaev, G. G. et al. (2010). Substantiation of the conditions for calculating and choosing the strength characteristics of the production strings of the Sladkovsko-Morozov group of fields. Construction of oil and gas wells onshore and offshore, 2, 31-38.
  20. Behnia, M. L, Seifabad, M. C. (2018). Stability analysis and optimization of the support system of an underground powerhouse cavern considering rock mass variability. Environmental Earth Sciences, 77 (18), 567-578.
  21. Cai, M. (2011). Rock mass characterization and rock property variability considerations for tunnel and cavern design. Rock Mechanics and Rock Engineering, 44 (4), 379-399.
  22. Gaede, O., Karrech, A., Regenauer-Lieb, K. (2013). Anisotropic damage mechanics as a novel approach to improve pre- and post-failure borehole stability analysis. Geophysical Journal International, 193 (3), 1095-1109.
  23. Gao, D., Sun, L., Lian, J. (2010). Prediction of casing wear in extendedreach drilling. Petroleum Scince, 10, 494-501.
  24. Garkasi, A., Yanghua, X., Gefri, L. (2010). Casing wear in extended reach and multilateral wells. World Oil, 6, 135-140.
  25. Jiabin, L., Yongga, M., Tianmin, S. (2008). Reserch on Mechanism of Casing Wear in Sliding-Impact Wear Condition. Advanced Tribology: Proceedings of CIST, 87 (7), 980-984.
  26. Lu, H., Kim, E., Gutierrez, M. (2019). Monte Carlo simulation (MCS) -based uncertainty analysis of rock mass quality Q in underground construction. Tunnelling and Underground Space Technology, 94 (8), 327-332.
  27. Khabibullin, M. Ya. (2019). Managing the processes accompanying fluid motion inside oil field converging-diverging pipes. Journal of Physics: Conference Series. International Conference «Information Technologies in Business and Industry», 042012.
  28. Gilaev, G. G., Khismetov, T. V., Bernshtein, A. M. et al. (2009). Application of heat-resistant well killing fluids based on oil emulsions. Oil industry, 8, 64-67.
  29. Khabibullin, M. Ya. (2020). Thermal Acid Pulsing Method for Enhanced Oil Recovery. Oil and Gas Business, 18 (4), 58-64.
  30. Khabibullin, M. Ya. (2019). Managing the reliability of the tubing string in impulse non-stationary flooding. Journal of Physics: Conference Series. International Conference «Information Technologies in Business and Industry» 4. Mechatronics, Robotics and Electrical Drives, 052012.
  31. Gilaev, Gen. G., Khabibullin, M. Ya., Gilaev, G. G. (2020). Prospects for the use of acid gel for proppant injection in the process of hydraulic fracturing of carbonate formations in the Samara region. Oil industry, 8, 54-57.
  32. Khabibullin, M. Ya. (2019). Theoretical grounding and controlling optimal parameters for water flooding tests in field pipelines. Journal of Physics: Conference Series. International Conference «Information Technologies in Business and Industry», 042013.
  33. Manshad, A., Jalalifar, H., Aslannejad, M. (2014). Analysis of vertical, horizontal and deviated wellbores stability by analytical and numerical methods. Journal of Petroleum Exploration and Production Technology, 4, 359-369.
  34. Kamenev, P. A., Bogomolov, L. M. (2017). On the depth distribution of the coefficient of internal friction and cohesion in sedimentary rock massifs about. Sakhalin. Geophysical Research, 18 (1), 5-19.
  35. Zhang, J., Lu, Y. (2019). Study on temperature distribution of ultra-deep wellbore and its effect on mechanical properties of surrounding rock. Yanshilixue Yu Gongcheng Xuebao. Chinese Journal of Rock Mechanics and Engineering, 38, 2831-2839.
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DOI: 10.5510/OGP2021SI200579

E-mail: m-hab@mail.ru


K.A. Bashmur1, E.A. Petrovsky1, V.S. Tynchenko1,2, V.V. Bukhtoyarov1,2, R.B. Sergienko3, O.A. Kolenchukov1

1Siberian Federal University, Krasnoyarsk, Russia; 2Institute of Computer Science and Telecommunications, Reshetnev Siberian State University of Science and Technology, Krasnoyarsk, Russia; 3Gini Gmbh, Munich, Germany

Effects of a rough surface vortex breaker hydrocyclone on the separating capacity of heterogeneous fluid systems


This paper considers the issue of heterogeneous system separation efficiency under the action of centrifugal forces working in hydrocyclones. The main problem with these apparatuses is related to vortex forming. The paper describes the negative effects of vortexes on the heterogeneous medium separation process. A hydrocyclone design was developed and described, which improves the hydrocyclone separation capacity. This design introduces a vortex breaker. Furthermore, vortex formation can be eliminated or minimized by providing the vortex breaker with a rough surface. To determine the separation efficiency and the adequacy of the proposed solution, hydrodynamic computer simulation and experimental studies were conducted. Solidworks Flow Simulation software was used for hydrodynamic computer simulation. To check the medium separation degree, an experimental study was conducted showing improvement of the hydrocyclone separation capacity efficiency by 3% in the developed apparatus compared to conventional hydrocyclone designs.

Keywords: hydrocyclone; separation; separating capacity; vortex breaker; heterogeneous system; oil preparation; hydrodynamics.

This paper considers the issue of heterogeneous system separation efficiency under the action of centrifugal forces working in hydrocyclones. The main problem with these apparatuses is related to vortex forming. The paper describes the negative effects of vortexes on the heterogeneous medium separation process. A hydrocyclone design was developed and described, which improves the hydrocyclone separation capacity. This design introduces a vortex breaker. Furthermore, vortex formation can be eliminated or minimized by providing the vortex breaker with a rough surface. To determine the separation efficiency and the adequacy of the proposed solution, hydrodynamic computer simulation and experimental studies were conducted. Solidworks Flow Simulation software was used for hydrodynamic computer simulation. To check the medium separation degree, an experimental study was conducted showing improvement of the hydrocyclone separation capacity efficiency by 3% in the developed apparatus compared to conventional hydrocyclone designs.

Keywords: hydrocyclone; separation; separating capacity; vortex breaker; heterogeneous system; oil preparation; hydrodynamics.

References

  1. Svarovsky, L., Thew, M. T. (1992). Hydrocyclones: analysis and applications. Dordrecht: Springer.
  2. Adelshin, A. B., Busarev, A. V., Selyugin, A. S., et al. (1988). Oil dehydration in pressure hydrocyclones. Oil Industry, 4, 54-56.
  3. Dadashov, I. H., Abbasov, I. Ch., Melikova, S. A. (2012). Methods for improving drilling in abnormally low formation pressure. SOCAR Proceedings, 2, 14-19.
  4. Mullakayev, M. S., Veksler, G. B., Mullakayev, R. M. (2019). Mobile sonochemical complex of oil sludge processing. SOCAR Proceedings, 3, 88-96.
  5. Nasiri, M., Jafari, I. (2017). Produced water from oil-gas plants: a short review on challenges and opportunities. Periodica Polytechnica: Chemical Engineering, 61(2), 73-81.
  6. Durdevic, P., Pedersen, S., Bram, M., et al. (2015). Control oriented modeling of a de-oiling hydrocyclone. IFAC-PapersOnLine, 48(28), 291-296.
  7. Padhi, M., Kumar, M., Mangadoddy, N. (2020). Understanding the bicomponent particle separation mechanism in a hydrocyclone using a computational fluid dynamics model. Industrial & Engineering Chemistry Research, 59(25), 11621-11644.
  8. Akhsanov, R.R., Murov, V.M., Nikolayev, N.V., et al. (1981). Investigation of the hydrodynamics of a swirling flow in a three-product hydrocyclone. Oil Industry, 5, 49-52.
  9. Lagutkin, M. G., Baranova, E. Yu. Bulychev, S. Yu. (2008). Effects of the cover zone in a hydrocyclone on the expected suspension separation parameters. Chemical and Petroleum Engineering, 44(1-2), 3-8.
  10. Ivanov, A. A., Balakhnin I. A., Pronin, A. I., et al. (2007). Transitional modes and crisis phenomena in hydrocyclones. Theoretical Foundations of Chemical Engineering, 41(6), 681-691.
  11. Shagarova, O. N. (2010). Energy characteristics of the hydrocyclone. Mining Informational and Analytical Bulletin (Scientific and Technical Journal), 10, 127-132.
  12. Petrovsky, E. A., Bashmur, K. A., Shadchina, Yu. N., et al. (2019). Study of microrelief forming technology on sliding bearings for oil and gas centrifugal units. Journal of Physics: Conference Series, 1399, 055032.
  13. Petrovsky, E. A., Bashmur, K. A., Tynchenko, V. S., et al. (2020). Control of geometric characteristics of surface micro-relief in metal turning using nanodiamond powders. Journal of Physics: Conference Series, 1515, 042104.
  14. Petrovsky, E. A., Anushenkov, A. N., Petrov, D. V. (2018). Vortex breaker hydrocyclone. RU Patent utility model 182045.
  15. Kumar, P., Dwari, S., Utkarsh, S., et al. (2020). Investigation and development of 3D printed biodegradable PLA as compact antenna for broadband applications. IETE Journal of Research, 66(1), 53-64.
  16. Kashtavtsev, V. E., Mishtenko, I. T. (2004). Salt formation in oil production. Moscow: Orbita-M.
  17. Hasanov, F. G., Kazimov, Sh. P., Abdullayeva, E. S. (2017). A new approach to the mechanical impurities utilization in the flowstream preparation system. SOCAR Proceedings, 4, 57-65.
  18. Tang, Z., Yu, L., Wang, F., et al. (2018). Effect of particle size and shape on separation in a hydrocyclone. Water, 11(1), 16.
  19. Petrovskiy, E. A., Bashmur, K. A., Klykova, V. D. (2021). Design for a hydrocyclone with a disk deflector offering improved efficiency for separating mechanical impurities. Chemical and Petroleum Engineering, 57(5-6), 472-476.
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DOI: 10.5510/OGP2021SI200580

E-mail: bashmur@bk.ru


S.G. Zubairov1, R.R. Yakhin2, A.N. Zotov1, T.I. Salikhov1

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

Investigation of a full-size damper for an electrically driven centrifugal pump for oil production


The article describes a way to combat fatigue effects in the details of connecting modules of an electric driven centrifugal pump unit for oil production. A constructive solution for implementing the method in relation to complex downhole conditions in the form of a multifunctional damper using a differential piston to transfer it from the transport position when lowering into the well into the working one is shown. For a full-size damper, experimental studies of its vibration- isolating characteristics have been carried out when used in the form of substrates for supporting arms of elastomers of various densities and compositions. The preferred characteristics of elastomers and their ranking for various frequencies of forced vibrations are determined.

Keywords: module, connection parts; electrically driven centrifugal pump unit; electrocentrifugal pumping unit; differential piston; damper; sbstrate; vibration velocity.

The article describes a way to combat fatigue effects in the details of connecting modules of an electric driven centrifugal pump unit for oil production. A constructive solution for implementing the method in relation to complex downhole conditions in the form of a multifunctional damper using a differential piston to transfer it from the transport position when lowering into the well into the working one is shown. For a full-size damper, experimental studies of its vibration- isolating characteristics have been carried out when used in the form of substrates for supporting arms of elastomers of various densities and compositions. The preferred characteristics of elastomers and their ranking for various frequencies of forced vibrations are determined.

Keywords: module, connection parts; electrically driven centrifugal pump unit; electrocentrifugal pumping unit; differential piston; damper; sbstrate; vibration velocity.

References

  1. Zubairov, S. G., Yakhin, R. R., Salikhov, I. A., et al. (2010). Electric centrifugal pumping unit. RU Patent 2386055.
  2. Zubairov, S. G., Yakhin, R. R., Halimov, F. G., Salikhov, I. A. (2011). Stand for vibration tests of the vibration compensator of electric centrifugal pumping units. Petroleum Engineering, 3, 318-322.
  3. Adler, Yu. P., Markova, E. V., Granovsky, Yu. V. (1976). Planning an experiment in the search for optimal conditions. Moscow: Science.
  4. Yakhin, R. R., Zubairov, S. G., Ermolenko, A. N. (2011). Investigation of the damping properties of the ECPU vibration compensator on specialized stands. Vestnik USATU, 15, 4 (44), 116-119.
  5. Moiseev, K. V., Kuleshov, V. S., Bakhtizin, R. N. (2020). Free convective of a linear heterogeneous liquid in a square cavity at side heating. SOCAR Proceedings, 4, 108-116.
  6. Gmurman, V. E. (2004). Probability theory and mathematical statistics: Textbook for universities. Moscow: Higher School.
  7. Zubairov, S. G., Yakhin, R. R. (2011). Processing the results of vibration tests by the method of a full factorial experiment. Proceedings of the VII International Educational-Scientific-Practical Conference «Pipeline transport – 2011». Ufa.
  8. GOST 23326-78. (1980). Rubber. Dynamic test methods. General requirements. Moscow: Standartinform.
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DOI: 10.5510/OGP2021SI200593

E-mail: mkm-ufa@mail.ru


O.A. Kolenchukov1, E.A. Petrovsky1, K.A. Bashmur1, V.S. Tynchenko1,2, R.B. Sergienko3

1School of Petroleum and Natural Gas Engineering, Siberian Federal University, Krasnoyarsk, Russia; 2Institute of Computer Science and Telecommunications, Reshetnev Siberian State University of Science and Technology, Krasnoyarsk, Russia; 3Gini Gmbh, Munich, Germany

Simulating the hydrocarbon waste pyrolysis in reactors of various designs


The study presents a simulation of pyrolysis reactors of various designs performed in the COMSOL Multiphysics software package. The non-isothermal flow (k–ε turbulent flow) module is used. The advantages this technique has over other commonly used ones are shown. The results indicate that under the same conditions, heating in sectional reactors is more intense. To achieve optimal results, the coolant flow rate in new reactors maybe by an order of magnitude less compared to the conventional design. The use of sectional reactors for multi-flow processing of hydrocarbon waste is advisable.

Keywords: sectional reactor; pyrolysis; hydrocarbon waste; heat transfer; turbulent flow. 

The study presents a simulation of pyrolysis reactors of various designs performed in the COMSOL Multiphysics software package. The non-isothermal flow (k–ε turbulent flow) module is used. The advantages this technique has over other commonly used ones are shown. The results indicate that under the same conditions, heating in sectional reactors is more intense. To achieve optimal results, the coolant flow rate in new reactors maybe by an order of magnitude less compared to the conventional design. The use of sectional reactors for multi-flow processing of hydrocarbon waste is advisable.

Keywords: sectional reactor; pyrolysis; hydrocarbon waste; heat transfer; turbulent flow. 

References

  1. Hedeşiu, D. M., Popescu, S. G., Dragomir, M. (2012). Critical analysis on quality costs models. Quality - Access to Success, 13(131), 71-76.
  2. Chung, C. A. (2003). Simulation modeling handbook: a practical approach. USA: CRC Press.
  3. Wang, Z., Guo, Q., Liu, X., Cao, C. (2007). Low temperature pyrolysis characteristics of oil sludge under
    various heating conditions. Energy & Fuels, 21(2), 957-962.
  4. Zubairov, S. G., Ahmetov, A. F., Bairamgulov, et al. (2018). Evaluation of strain-stress states of initial and improved designs of the modules for oil sludge pyrolysis. SOCAR Proceedings, 2, 71-76.
  5. Petrovsky, E. A., Kolenchukov, O. A., Solovyov, E. A. (2019). Study of pyrolysis of oil sludge. IOP Conference Series: Materials Science and Engineering, 537, 032082.
  6. Kolenchukov, O. A., Solovyov, E. A. (2019). Sectional pyrolysis reactor. RU Patent 2677184.
  7. Ionescu, A., Costescu, M. (2006). Special features in turbulent mixing. comparison between periodic and non periodic case. Surveys in Mathematics and its Applications, 1, 33-40.
  8. Zaheer, Q., Masud, J. (2018). Comparison of flow field simulation of liquid ejector pump using standard k-ε and embedded LES turbulence modelling techniques. Journal of Applied Fluid Mechanics, 11(2), 385-395.
  9. Aver`yanov, V., Vasiliev, V., Ulyasheva, V. (2018). Selection of turbulence models in case of numerical simulation of heat-, air- and mass exchange processes. In: 10th Conference on Interdisciplinary Problems in Environmental Protection and Engineering EKO-DOK.
  10. Kowal, G., Lazarian, A., Vishniac, E. T., Otmianowska-Mazur, K. (2012). Reconnection studies under different types of turbulence driving. Nonlinear Processes in Geophysics, 19(2), 297-314.
  11. Bai, Z., Zhang, J. (2017). Comparison of different turbulence models for numerical simulation of pressure distribution in v-shaped stepped spillway. Mathematical Problems in Engineering, 2017, 3537026.
  12. Novković, Đ. M., Burazer, J. M., Ćoćić, A. S., Lećić, M. R. (2018). On the influence of turbulent kinetic energy level on accuracy of k–ε and LRR turbulence models. Theoretical and Applied Mechanics, 25(2), 139-149.
  13. Zidouni Kendil, F., Bousbia Salah, A., Mataoui, A. (2010). Assessment of three turbulence model performances in predicting water jet flow plunging into a liquid pool. Nuclear Technology & Radiation Protection, 25(1), 13-22.
  14. Spalart, P. R. (2000). Strategies for turbulence modelling and simulation. International Journal of Heat and Fluid Flow, 21(3), 252-263.
  15. Atifi, A., Mounir, H., & El Marjani, A. (2015). A 2D finite element model for the analysis of a PEM fuel cell heat and stress distribution. International Review on Modeling and Simulation (IREMOS), 8(6), 632-639.
  16. Cheng, S., Wang, Y., Gao, N., et al. (2016). Pyrolysis of oil sudge with oil sludge ash additive employing a stirred tank reactor. Journal of Analytical and Applied Pyrolysis, 120, 511-520.
  17. Kolenchukov, O. A., Petrovsky, E. A. (2019). Analysis of the causes of failures of pyrolysis units. Journal of Physics: Conference Series, 1399, 055077.
  18. Song, C., Pan, W., Srimat, S. T. et al. (2004). Tri-reforming of methane over Ni catalysts for CO2 conversion to Syngas with desired H2CO ratios using flue gas of power plants without CO2 separation. Studies in Surface Science and Catalysis, 153, 315-322.
  19. Chang, C.-Y., Shie, J.-L., Lin, J.-P., et al. (2000). Major products obtained from the pyrolysis of oil sludge. Energy & Fuels, 14(6), 1176-1183.
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DOI: 10.5510/OGP2021SI200554

E-mail: bashmur@bk.ru


A.I. Lakhova1, S.M. Petrov2, N.E. Ignashev1, G.G. Islamova2, K.A. Shchekoldin3

1Kazan Federal University, Kazan, Russia; 2Kazan National Research Technological University, Kazan, Russia; 3LLC «RITEK», Volgograd, Russia

Upgrading of heavy crude oil in supercritical aqueous fluid in the presence of activated charcoal


The article presents the results of deep processing of heavy crude oil in supercritical aqueous fluid, which makes it possible to significantly reduce the content of sulfur and resinous asphaltene compounds in products, and to increase the yield of light fuel fractions. The possibility of reducing the temperature of upgrading of heavy crude oil due to the presence of active charcoal in the reaction medium is shown. The proposed technology provides environmentally safe and residue-free processing of heavy oil and further production of high-quality hydrocarbon raw materials enriched in low-boiling fractions.

Keywords: upgrading; heavy crude oil; supercritical aqueous fluid; activated charcoal.

The article presents the results of deep processing of heavy crude oil in supercritical aqueous fluid, which makes it possible to significantly reduce the content of sulfur and resinous asphaltene compounds in products, and to increase the yield of light fuel fractions. The possibility of reducing the temperature of upgrading of heavy crude oil due to the presence of active charcoal in the reaction medium is shown. The proposed technology provides environmentally safe and residue-free processing of heavy oil and further production of high-quality hydrocarbon raw materials enriched in low-boiling fractions.

Keywords: upgrading; heavy crude oil; supercritical aqueous fluid; activated charcoal.

References

  1. Huang, S., Cao, M., Cheng, L. (2018). Experimental study on aquathermolysis of different viscosity heavy oil with superheated steam. Energy & Fuels, 32(4), 4850-4858.
  2. Petrov, S., Nosova, A., Bashkirtseva, N., Fakhrutdinov, R. (2019, June). Features of heavy oil spraying with single evaporation. IOP Conference Series: Earth and Environmental Science, 282(1), 012004.
  3. Pivkin, P. (2017). Selecting optimal cutting tools for lathes. Russian Engineering Research, 37(4), 351-353.
  4. Petrov, S. M., Kayukova, G. P., Vakhin, A. V., et al. (2015). Catalytic effects research of carbonaceous rock under conditions of in-situ oxidation of super-sticky naphtha. Research Journal of Pharmaceutical, Biological and Chemical Sciences, 6(6), 1624-1629.
  5. Nasyrova, Z., Aliev, A., Petrov, S., et al. (2018). The catalytic effects of carbonate minerals on characteristics of heavy oil in hydrothermal reactions. Petroleum Science and Technology, 36(18), 1439-1445.
  6. Nosova, A., Petrov, S., Safiulina, A., et al. (2018). The transformation of high-viscosity oil of carbonate rock in the presence of CO [AcAc] 3 catalyst in a vapor-air medium. Petroleum Science and Technology, 36(13), 1001-1006.
  7. Thimm, H. F. (2014, June). Aquathermolysis and sources of produced gases in SAGD. In: SPE Heavy Oil Conference. Society of Petroleum Engineers.
  8. Hyne, J. B., Clark, P. D., Clarke, R. A., et al. (1982). Aquathermolysis of heavy oils. Revista Tecnica Intevep, 2(2).
  9. Betiha, M. A., ElMetwally, A. E., Al-Sabagh, A. M., Mahmoud, T. (2020). Catalytic aquathermolysis for altering the rheology of asphaltic crude oil using ionic liquid modified magnetic MWCNT. Energy & Fuels, 34(9), 11353-11364.
  10. Safiulina, A., Petrov, S., Nosova, A., et al. (2019). Transformation of heavy oil in hydrothermal impact. Petroleum Science and Technology, 37(5), 611-616.
  11. Lin, D., Zhu, H., Wu, Y., et al. (2019). Morphological insights into the catalytic aquathermolysis of crude oil with an easily prepared high-efficiency Fe3O4-containing catalyst. Fuel, 245, 420-428.
  12. Kayukova, G. P., Morozov, V. P., Islamova, R. R., et al. (2015). Composition of oils of carbonate reservoirs in current and ancient water—oil contact zones. Chemistry and Technology of Fuels and Oils, 51(1), 117-126.
  13. Petrov, S. M., Safiulina, A. G., Bashkirtseva, N. Y., et al. (2021). Influence of metal oxides and their precursors on the composition of final products of aquathermolysis of raw Ashalchin oil. Processes, 9(2), 256.
  14. Li, C., Huang, W., Zhou, C., Chen, Y. (2019). Advances on the transition-metal based catalysts for aquathermolysis upgrading of heavy crude oil. Fuel, 257, 115779.
  15. Lakhova, A. I., Safiulina, A. G., Islamova, G. G., et al. (2021). Study of the impact of nonionic additives on the composition and structure of petroleum dispersed systems by IR spectroscopy. Processes, 9(3), 553.
  16. Baibekova, L. R., Petrov, S. M., Mukhamatdinov, I. I., Burnina, M. A. (2015). Polymer additive influence on composition and properties of bitumen polymer compound. International Journal of Applied Chemistry, 11(5), 593-599.
  17. Petrov, S. M., Ibragimova, D. A., Abdelsalam, Y. I., Kayukova, G. P. (2016). Influence of rockforming and catalytic additives on transformation of highly viscous heavy oil. Petroleum Chemistry, 56(1), 21-26.
  18. Petrov, S. M., Zakiyeva, R. R., Ibrahim, A. Y., et al. (2015). Upgrading of high-viscosity naphtha in the super-critical water environment. International Journal of Applied Engineering Research, 10(24), 44656-61.
  19. Zaidullin, I. M., Lakhova, A. I., Ivanova, I. A., et al. (2017). Geothermal transformatiom of organic matter in supercritical water with magnetite and coal particles. Chemistry and Technology of Fuels and Oils, 52(6), 756-761.
  20. Petrov, S. M., Kayukova, G. P., Lakhova, A. I., et al. (2016). Steam–air conversion of heavy oil in the presence of nanosized metal oxide particles. Chemistry and Technology of Fuels and Oils, 52(5), 619-625.
  21. Xin, S. M., Liu, Q. K., Wang, K., et al. (2016). Solvation of asphaltenes in supercritical water: A molecular dynamics study. Chemical Engineering Science, 146, 115-125.
  22. Kozhevnikov, I. V., Nuzhdin, A. L., Martyanov, O. N. (2010). Transformation of petroleum asphaltenes in supercritical water. Journal of Supercritical Fluids, 55(1), 217-222.
  23. Petrov S.M., Lakhova A.I., Ibragimova D.A., et al. (2016). Aquatermolisys of heavy crude oil in the presence of metal oxide nanoparticles. Research Journal of Pharmaceutical, Biological and Chemical Sciences, 7(5), 1367-1373.
  24. Hosseinpour, M., Hajialirezaei, A. H., Soltani, M., Nathwani, J. (2019). Thermodynamic analysis of in-situ hydrogen from hot compressed water for heavy oil upgrading. International Journal of Hydrogen Energy, 44(51), 27671-27684.
  25. Hosseinpour, M., Ahmadi, S. J., Fatemi, S. (2015). Successive co-operation of supercritical water and silica-supported iron oxide nanoparticles in upgrading of heavy petroleum residue: Suppression of coke deposition over catalyst. Journal of Supercritical Fluids, 100, 70-78.
  26. Petrov, S. M., Safiulina, A. G., Bashkirtseva, N. Y., et al. (2021). Influence of metal oxides and their precursors on the composition of final products of aquathermolysis of raw Ashalchin oil. Processes, 9(2), 256.
  27. Zakieva, R. R., Vasilev, E. R., Karalin, E. A., et al. (2020). Reactivity of metastable water in hydrothermal heavy crude oil and carbonaceous compounds conversions. Journal of Chemical Technology & Metallurgy, 55(4).
  28. Bradley, R. H., Sutherland, I., Sheng, E. (1996). Carbon surface: area, porosity, chemistry, and energy. Journal of Colloid and Interface Science, 179(2), 561-569.
  29. Valiyev N.A., Jamalbayov M.А., Ibrahimov Kh.M., Hasanov I.R. (2021) On the prospects for the use of CO2 to enhance oil recovery in the fields of Azerbaijan. SOCAR Proceedings, 83–89.
  30. Shamilov V.M. (2020) Potential applications of carbon nanomaterials in oil recovery. SOCAR Proceedings, 3, 90–107.
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DOI: 10.5510/OGP2021SI200566

E-mail: lfm59@mail.ru


Y.Z. Alekberov, R.Z. Khalilov, X.G. Ismailova

Azerbaijan State Oil and Industry University, Baku, Azerbaijan

Research and application of natural zeolite in the processes of gas purification and drying


This article describes the adsorption capability of natural zeolites for the purification and dehydration of natural gases. Studies were carried out with natural clinoptilolite treated with various cadmium and titanium solutions. Zeolite-containing rocks were used as a natural adsorbent and experiments using a synthetic CaA zeolite were also carried for comparison. The experiments showed that zeolite from the Ai-Dag deposits possesses the highest activity in terms of sulfur compound. Its activity is closer to that of synthetic CaA zeolite. Studies showed that natural zeolites and adsorbents obtained on their basis allow the gas to be dehydrated to a dew point temperature of minus 40-45 °C. This is sufficient to prepare gas for transportation directly from the fields under any climatic conditions.

Keywords: gas dehydration; zeolite; adsorbent; sulfur compounds.

This article describes the adsorption capability of natural zeolites for the purification and dehydration of natural gases. Studies were carried out with natural clinoptilolite treated with various cadmium and titanium solutions. Zeolite-containing rocks were used as a natural adsorbent and experiments using a synthetic CaA zeolite were also carried for comparison. The experiments showed that zeolite from the Ai-Dag deposits possesses the highest activity in terms of sulfur compound. Its activity is closer to that of synthetic CaA zeolite. Studies showed that natural zeolites and adsorbents obtained on their basis allow the gas to be dehydrated to a dew point temperature of minus 40-45 °C. This is sufficient to prepare gas for transportation directly from the fields under any climatic conditions.

Keywords: gas dehydration; zeolite; adsorbent; sulfur compounds.

References

  1. Chelishchev, N. F., Berenshtejn, B. G. (1974). Klinoptolit, Seriya IV. Moskva: VIEMS.
  2. Keltcev, N. V. (1984). Osnovy adsorbcionnoj tekhniki. Moskva: Himiya.
  3. Alekberov, Y. Z.,Ismayilova, H. Q., Xalilov, R. Z. (2020). Qazlarin neqle hazirlanmasi ve emalinin texnologiyalari ve eko-iqtisadi aspektleri. Baki: Elm.
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DOI: 10.5510/OGP2021SI200601

E-mail: ruslan.khalilov@bakerhughes.com


A.G. Huseynov1, E.A. Huseynov2

1Azerbaijan State Oil and Industry University, Baku, Azerbaijan; 2«OilGasScientificResearchProject» Institute, SOCAR, Baku, Azerbaijan

The expansion of innovative activity on rise of oil production enterprises in Azerbaijan


The article analysis the oil and gas production condition in the Republic on basis of statistical data of many years as well as the level of investment provision. The article estimates the structure of expenses on innovative techniques, the condition of exploitation of oil and gas boreholes, the implementation of geological and technological actions, the ways of exploitation methods as well as the methods of ledge effects and influence on extra oil production. It also shows up the reserves and ways of their rational usage.

Keywords: innovative activity; geological and technological actions; oil and gas; well.

The article analysis the oil and gas production condition in the Republic on basis of statistical data of many years as well as the level of investment provision. The article estimates the structure of expenses on innovative techniques, the condition of exploitation of oil and gas boreholes, the implementation of geological and technological actions, the ways of exploitation methods as well as the methods of ledge effects and influence on extra oil production. It also shows up the reserves and ways of their rational usage.

Keywords: innovative activity; geological and technological actions; oil and gas; well.

References

  1. (2020). Azerbaycanin senayesi. Statistik mecmue. Baki: DSK.
  2. SOCAR-ın 2015-2019-cu iller uzre illik hesabtlari. Baki: SOCAR.
  3. SOCAR-ın 2015-2019-cu iller uzre esas texniki iqtisadi gostericiler toplulari. Baki: SOCAR.
  4. Huseynov, A. G. (2021). Neft və ekoloji tehlukesizlik: realliqlar və perspektivler. Baki.
  5. Aliyev, M., Huseynov, A. (2016). Neft-qaz senayesinin iqtisadiyyati və idare edilməsi. Baki.
  6. Seferov, Q. A., Mammadova, M. B. (2014). Neftqazchixarmada istehsal semereliliyinin yukseldilmesi ehtiyatlari. Baki.
  7. Genciyev, G. (2007). Transmilli korporasiyalar. Baki.
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DOI: 10.5510/OGP2021SI200574

E-mail: ahuseynov@azfen.com


V.A.Grishchenko, R.R.Gareev, I.M.Tsiklis, V.V.Mukhametshin, R.F.Yakupov

Ufa State Petroleum Technological University, Ufa, Russia

Expanding the amount of preferential royalty facilities with hard-to-recover oil reserves


The article deals with the economic attractiveness of hard-to-recover oil reserves in the Ural-Volga region development. The fuel and energy complex is a budgetforming one for oil-producing regions and contributes to the development of all sectors of the economy, and is bound by social responsibility. The current situation and trends in the global economy demonstrate that oil production intensification is a paramount task to all related industries efficiency improving, taxes being the main share in the cost structure. Therefore, in order to stimulate the reserves from low-permeability reservoirs development, tax exemptions are provided in the form of a reduced tax on mineral extraction. The paper considers an example of development efficiency improving due to tax incentives. According to the assessment results, the option with tax incentives is more beneficial for both the state and the subsoil user.

Keywords: oil fields development; hard-to-recover reserves; taxation; qualified for tax relief; production intensification.

The article deals with the economic attractiveness of hard-to-recover oil reserves in the Ural-Volga region development. The fuel and energy complex is a budgetforming one for oil-producing regions and contributes to the development of all sectors of the economy, and is bound by social responsibility. The current situation and trends in the global economy demonstrate that oil production intensification is a paramount task to all related industries efficiency improving, taxes being the main share in the cost structure. Therefore, in order to stimulate the reserves from low-permeability reservoirs development, tax exemptions are provided in the form of a reduced tax on mineral extraction. The paper considers an example of development efficiency improving due to tax incentives. According to the assessment results, the option with tax incentives is more beneficial for both the state and the subsoil user.

Keywords: oil fields development; hard-to-recover reserves; taxation; qualified for tax relief; production intensification.

References

  1. Energy Strategy of the Russian Federation for the period up to 2035. http://government.ru/docs/39847
  2. Kontorovich, A. E., Livshits, V. R. (2017). New methods of assessment, structure, and development of oil and gas resources of mature petroleum provinces (Volga-Ural province). Russian Geology and Geophysics, 58(12), 1453-1467.
  3. 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.
  4. Muslimov, R. Kh. (2009). Features of exploration and development of oil fields in a market economy. Kazan: FEN.
  5. Mukhametshin, V. Sh., Zeigman, Yu. V., Andreev, A.V. (2017). Rapid assessment of deposit production capacity for determination of nanotechnologies application efficiency and necessity to stimulate their development. Nanotechnologies in Construction, 9(3), 20–34.
  6. Livshitc, V. R. (2021). Distribution of hydrocarbon resources by deposits and fields of various sizes and fields by the number of deposits. Oil Industry, 9, 18-22.
  7. Khuzin, R. R., Bakhtizin, R. N., Andreev, V. E., et al. (2021). Oil recovery enhancement by reservoir hydraulic compression technique employment. SOCAR Proceedings, SI1, 98-108.
  8. 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.
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DOI: 10.5510/OGP2021SI200575

E-mail: vsh@of.ugntu.ru


D. V. Kotov, I. V. Burenina, S. F. Sayfullina

Ufa State Petroleum Technological University, Ufa, Russia

Improving the efficiency of organizational design in the oil and gas business


The article discusses a number of topical issues of modern organizational design. Through the analysis of the approaches of Russian and foreign scientists, the factors that need to be taken into account in organizational design are identified. Out of a multitude of factors, we have selected those that have the greatest impact in various options for the market and technological environment for an oil and gas company. Organizational schemes which can be recommended for organizing management in different market conditions are shown. A method to reconcile the influence of the basic and other factors in the organizational design process is proposed. A mechanism for constructing an organizational structure in modern conditions in oil and gas companies is proposed. In the conclusion, recommendations on the directions for further research on the problems of building organizational structures are given.

Keywords: organizational structure; building organizational structures; competitiveness factors; organizational design.

The article discusses a number of topical issues of modern organizational design. Through the analysis of the approaches of Russian and foreign scientists, the factors that need to be taken into account in organizational design are identified. Out of a multitude of factors, we have selected those that have the greatest impact in various options for the market and technological environment for an oil and gas company. Organizational schemes which can be recommended for organizing management in different market conditions are shown. A method to reconcile the influence of the basic and other factors in the organizational design process is proposed. A mechanism for constructing an organizational structure in modern conditions in oil and gas companies is proposed. In the conclusion, recommendations on the directions for further research on the problems of building organizational structures are given.

Keywords: organizational structure; building organizational structures; competitiveness factors; organizational design.

References

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DOI: 10.5510/OGP2021SI200596

E-mail: iushkova@yandex.ru


A.N. Dmitrievsky1,2, N.A. Eremin1,2, V.E. Stolyarov1,3

1Institute of Oil and Gas Problems of the Russian Academy of Sciences, Moscow, Russia; 2Gubkin Russian State University of Oil and Gas (National Research University), Moscow, Russia; 3PJSC «Gazprom», Moscow, Russia

Current issues and indicators of digital transformation of oil and gas production at the final stage of field operation


The article analyzes the technical and regulatory restrictions that complicate the production of hydrocarbons at the final stage of operation, as well as the directions of resource and innovative development of the fuel and energy complex in the context of sanctions and restrictions in the development of national priorities. The features of regulatory regulation of legislation and indicators of digital transformation for previously developed fields and the preservation of hydrocarbon markets, the development of national economies in the long term, taking into account the widespread use of intelligent technologies and digital platforms, are considered. Taking into account the technological advantages, it is recommended to ensure the digitalization of oil and gas wells using fiber-optic technologies and the creation of intelligent wells and fields on this basis, which, in conditions of limited funding, will ensure an increase in recoverable gas and oil production reserves of at least 10% during operation, a reduction in well downtime of about 50 % of the initial level and a reduction in operating costs of about 10-25 %.

Keywords: inovation; regulation; digital economy; transformation; modeling; intelligent technology; digital platform.

The article analyzes the technical and regulatory restrictions that complicate the production of hydrocarbons at the final stage of operation, as well as the directions of resource and innovative development of the fuel and energy complex in the context of sanctions and restrictions in the development of national priorities. The features of regulatory regulation of legislation and indicators of digital transformation for previously developed fields and the preservation of hydrocarbon markets, the development of national economies in the long term, taking into account the widespread use of intelligent technologies and digital platforms, are considered. Taking into account the technological advantages, it is recommended to ensure the digitalization of oil and gas wells using fiber-optic technologies and the creation of intelligent wells and fields on this basis, which, in conditions of limited funding, will ensure an increase in recoverable gas and oil production reserves of at least 10% during operation, a reduction in well downtime of about 50 % of the initial level and a reduction in operating costs of about 10-25 %.

Keywords: inovation; regulation; digital economy; transformation; modeling; intelligent technology; digital platform.

References

  1. Dmitrievsky, A. N., Mastepanov, A. M., Bushuev, V. V. (2014). Resource and innovation strategy for the development of the Russian economy. Bulletin of the RAS, 84(10), 867-873.
  2. Eremin, N. A., Stolyarov, V. E. (2018). Optimization of gas production processes using digital technologies. Geology, Geophysics and Development of Oil and Gas Fields, 6, 54-61.
  3. Eremin, N. A., Stolyarov, V. E. (2020). On the digitalization of gas production in the late stages of field
    development. SOCAR Proceedings, 1, 59-69.
  4. Eremin, N. A., Stolyarov, V. E., Shulyatikov, V. I. (2020). Application of control systems in oil and gas fields. Automation, Telemechanization and Communication in the Oil Industry, 9(566), 17-29.
  5. Dmitrievsky, A. N., Eremin, N. A., Stolyarov, V. E. (2020). The role of information in the application of artificial intelligence technologies in the construction of wells for oil and gas fields. Scientific Journal of the Russian Gas Society, 2(26), 6-21.
  6. Eremin, N. A., Stolyarov, V. E. (2020). Scientific and technological progress and legal regulation in the oil and gas industry. Automation, Telemechanization and Communication in the Oil Industry, 12(569), 15-26.
  7. Dmitrievsky, A. N., Eremin, N. A., Lozhnikov, P. S., et al. (2021). Intelligent innovative technologies in the
    construction of wells for wells and the operation of oil and gas fields. Gas Industry, 3(813), 6-14.
  8. Dmitrievsky, A. N., Eremin, N. A., Filippova, D. S., Safarova, E. A. (2020). Digital oil and gas complex of Russia. Georesources, Special Issue, 32–35.
  9. Dmitrievsky, A. N., Eremin, N. A., Safarova, E. A., et al. (2020). Qualitative analysis of time series geodata to prevent complications and emergencies during drilling of oil and gas wells. SOCAR Proceedings, 3, 31-37.
  10. Dmitrievsky, A. N., Sboev, A. G., Eremin, N. A., et al. (2020). On increasing the productive time of drilling oil and gas wells using machine learning methods. Georesources, 22(4), 79–85.
  11. Chernikov, A. D., Eremin, N. A., Stolyarov, et al. (2020). Application of artificial intelligence methods for identifying and predicting complications in the construction of oil and gas wells: problems and solutions. Georesources, 22(3), 87–96.
  12. Arkhipov, A. I., Dmitrievsky, A. N., Eremin, N. A., et al. (2020). Data quality analysis of the station of geological and technological researches in recognizing losses and kicks to improve the prediction accuracy of neural network algorithms. Oil Industry, 8, 63-67.
  13. Borozdin, S., Dmitrievsky, A., Eremin, N., et al. (2020). Drilling problems forecast system based on neural network. Paper SPE-202546-MS. In: SPE Annual Caspian Technical Conference. Society of Petroleum Engineers.
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DOI: 10.5510/OGP2021SI200543

E-mail: ermn@mail.ru


V. V. Strelets1, V. M. Loboichenko2, N. A. Leonova3, R. I. Shevchenko2, V. M. Strelets2, A. V. Pruskyi4, O. V. Avramenko5

1RPE “ART-THEH”, Kharkiv, Ukraine; 2National University of Civil Defence of Ukraine, Kharkiv, Ukraine; 3V.N. Karazin Kharkiv National University, Kharkiv, Ukraine; 4Institute of PARCP, Kyiv, Ukraine; 

Comparative assessment of environmental parameters of foaming agents based on synthetic hydrocarbon used for extinguishing the fires of oil and petroleum products


The paper examines in detail the environmental impact of foaming agents used for extinguishing Class B fires, which include oil and petroleum product fires. There is a significant negative impact on the environment of long-chain fluorine-containing foaming agents and the search for alternatives of their use for firefighting. The advantages of calculation methods for determining the environmental parameters of foaming agents to extinguish fires, taking into account their chemical structure, are noted. The method «Quantitative Structure - Property Relationships» was used for obtaining BCF, LC50 (Fathead Minnow, Daphnia Magna), IGC50 (Tetrahymena Pyriformis) for a number of foaming agents with a carbon chain length C8-C14, containing fluorine and fluorine-free. It is shown that according to BCF the safest is sodium lauryl sulfate, according to LC50 (Daphnia Magna) the safest of the studied are foaming agents based on alkyl compounds Sodium decyl sulfate, Sodium lauryl sulphate, Triethanolamine salt of deсyl sulfate (third class of acute toxicity), whereas fluorine-containing compounds (6:2 fluorotelomers) according to LC50 (Daphnia Magna) belong to the first class of acute toxicity (the most dangerous of the studied compounds).

Keywords: fluorine-free foaming agent; fluorotelomer; oil; petroleum products; extinguishing the fires; environmental parameter; calculation method.

The paper examines in detail the environmental impact of foaming agents used for extinguishing Class B fires, which include oil and petroleum product fires. There is a significant negative impact on the environment of long-chain fluorine-containing foaming agents and the search for alternatives of their use for firefighting. The advantages of calculation methods for determining the environmental parameters of foaming agents to extinguish fires, taking into account their chemical structure, are noted. The method «Quantitative Structure - Property Relationships» was used for obtaining BCF, LC50 (Fathead Minnow, Daphnia Magna), IGC50 (Tetrahymena Pyriformis) for a number of foaming agents with a carbon chain length C8-C14, containing fluorine and fluorine-free. It is shown that according to BCF the safest is sodium lauryl sulfate, according to LC50 (Daphnia Magna) the safest of the studied are foaming agents based on alkyl compounds Sodium decyl sulfate, Sodium lauryl sulphate, Triethanolamine salt of deсyl sulfate (third class of acute toxicity), whereas fluorine-containing compounds (6:2 fluorotelomers) according to LC50 (Daphnia Magna) belong to the first class of acute toxicity (the most dangerous of the studied compounds).

Keywords: fluorine-free foaming agent; fluorotelomer; oil; petroleum products; extinguishing the fires; environmental parameter; calculation method.

References

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  28. Tureková, I., Balog, K. (2011). The environmental impacts of fire-fighting foams. Research Papers Faculty of Materials Science and Technology Slovak University of Technology, 18(29), 111-120.
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  45. Kawano, T., Otsuka, K., Kadono, T., et al. (2014). Eco-toxicological evaluation of fire-fighting foams in small-sized aquatic and semi-aquatic biotopes. Advanced Materials Research, 875-877, 699–707.
  46. Dadashov, І., Loboichenko, V, Kireev, А. (2018). Comparative assassment of environmental damage when using gel forming systems of different composition in combustible liquids extinguishing. Transactions of Kremenchuk Mykhailo Ostrohradskyi National University, 1108), 123–129.
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  49. Gurbanova, M., Loboichenko, V., Shevchenko, R., Dadashov, I. (2020). Analysis of environmental characteristics of the basic organic components of the foaming agents usedin fire fighting. Technogenic and Ecological Safety, 7(1/2020), 27–37.
  50. Gurbanova, М., Loboichenko, V., Leonova, N., et al. (2020). Comparative assessment of the ecological characteristics of auxiliary organic compounds in the composition of foaming agents used for fire fighting. Bulletin of the Georgian National Academy of Sciences, 14(4), 58-66.
  51. Gurbanova, M., Loboichenko, V., Leonova, N., Strelets, V. (2020). Effect of inorganic components of fire foaming agents on the aquatic environment. Journal of the Turkish Chemical Society, Section A: Chemistry, 7(3), 833 - 844.
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DOI: 10.5510/OGP2021SI200537

E-mail: vloboichm@gmail.com


B.V. Uspensky1,2, R.R. Khasanov1, R.R. Shagidullin2, Sh.Z. Gafurov1

1Kazan (Volga region) Federal University, Kazan, Russia; 2Institute of Ecology and Subsoil Use of the Academy of Sciences of the Republic of Tatarstan

Problems and prospects for the development of hydrocarbon resources in the context of the global transition to clean energy


Decarbonization of the world economy is one of the main trends in global development of the last decade. The beginning of the transition of the world economy to green energy poses new tasks and challenges for the geological exploration industry as well as for the fuel and energy complex. Currently, the most demanded energy-chemical resources are oil, natural gas and, to a lesser extent, coal. Their production has approached the maximum possible level and in the near future will inevitably begin to decline. However, due to large investments and highly efficient technologies, the process of switching to alternative energy sources may drag on for a long period, during which traditional hydrocarbons will remain the basis of the energy sector in many countries. The share of hard-to-recover reserves in the world is constantly growing; in Russia, it currently exceeds 65%. Hard-to-recover reserves include, in particular, reserves of highviscosity oils and bitumen (with a viscosity of more than 30 mPa·s). The article discusses the prospects and possible ways of developing bitumen and coal deposits within the Volga-Ural oil and gas basin.

Keywords: decarbonization; natural bitumen; heavy oil; coal seams; thermal treatment.

Decarbonization of the world economy is one of the main trends in global development of the last decade. The beginning of the transition of the world economy to green energy poses new tasks and challenges for the geological exploration industry as well as for the fuel and energy complex. Currently, the most demanded energy-chemical resources are oil, natural gas and, to a lesser extent, coal. Their production has approached the maximum possible level and in the near future will inevitably begin to decline. However, due to large investments and highly efficient technologies, the process of switching to alternative energy sources may drag on for a long period, during which traditional hydrocarbons will remain the basis of the energy sector in many countries. The share of hard-to-recover reserves in the world is constantly growing; in Russia, it currently exceeds 65%. Hard-to-recover reserves include, in particular, reserves of highviscosity oils and bitumen (with a viscosity of more than 30 mPa·s). The article discusses the prospects and possible ways of developing bitumen and coal deposits within the Volga-Ural oil and gas basin.

Keywords: decarbonization; natural bitumen; heavy oil; coal seams; thermal treatment.

References

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DOI: 10.5510/OGP2021SI200571

E-mail: borvadus@rambler.ru


Yu.N. Savicheva1, O. N. Budeeva1, V.Sh. Ishmetov2

1Ufa State Petroleum Technological University, Ufa, Russia; 2Bashkir State Medical University, Ufa, Russia

Reducing professional risk based on analysis and evaluation of the effectiveness of application of special drilling clothes


Climatic conditions can also act as harmful factors from which the employee must be protected. But winter conditions are very different depending on the area of the country. Therefore, the standard regulations governing the issuance of warm clothing have established norms depending on climatic zones. The main disadvantage of the existing work clothing is insufficient resistance to the effects of oil and oil products, the inconsistency of the physiological and hygienic properties of the materials used with the production conditions. This
causes significant damage to the health of workers in the production of acids and significantly reduces labor efficiency.

Keywords: occupational risk; driller; occupational disease; special clothing; risk-based approach.

Climatic conditions can also act as harmful factors from which the employee must be protected. But winter conditions are very different depending on the area of the country. Therefore, the standard regulations governing the issuance of warm clothing have established norms depending on climatic zones. The main disadvantage of the existing work clothing is insufficient resistance to the effects of oil and oil products, the inconsistency of the physiological and hygienic properties of the materials used with the production conditions. This
causes significant damage to the health of workers in the production of acids and significantly reduces labor efficiency.

Keywords: occupational risk; driller; occupational disease; special clothing; risk-based approach.

References

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  13. (2012). GOST EN 340-2012. SSBT. Odezhda special'naya zashchitnaya. Obshchie tekhnicheskie trebovaniya. Moskva: Standartinform.
  14. Denisov, E. I., CHesalin, P. V. (2006). Dokazatel'nost' v medicine truda: principy i ocenka svyazi narushenij zdorov'ya s rabotoj. Medicina Truda i Promyshlennaya Ekologiya, 11, 6-13.
  15. Gimranova, G. G., Bakirov, A. B., Karimova, L. K. i dr. (2014). Faktory i pokazateli professional'nogo riska pri dobyche nefti. Vestnik RGMU, 1, 72-75.
  16. (2015). GOST 12.4.280-2014. SSBT. Odezhda special'naya dlya zashchity ot obshchih proizvodstvennyh zagryaznenij i mekhanicheskih vozdejstvij. Obshchie tekhnicheskie trebovaniya. Moskva: Standartinform.
  17. (2007). BS EN 471:2003+A1:2007. High-visibility warning clothing for professional use. Test methods and requirements. British Standard.
  18. (2008). ISO 14116:2008. Protective clothing. Protection against heat and flame. Limited flame spread materials, material assemblies and clothing.
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  24. (2012). Postanovlenie Mintruda Rossii ot 16.12.1997 N 63 (red. ot 05.05.2012) «Ob utverzhdenii Tipovyh otraslevyh norm besplatnoj vydachi rabotnikam special'noj odezhdy, special'noj obuvi i drugih sredstv individual'noj zashchity».
  25. (2016). Postanovlenie Mintruda Rossii ot 25.12.1997 N 66 (red. ot 23.08.2016) «Ob utverzhdenii Tipovyh otraslevyh norm besplatnoj vydachi rabotnikam special'noj odezhdy, special'noj obuvi i drugih sredstv individual'noj zashchity».
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DOI: 10.5510/OGP2021SI200595

E-mail: ufa.savjulia@gmail.com


T.S. Vovchuk1, J.L. Wilk-Jakubowski2, V.M. Telelim3, V.M. Loboichenko1, R.I. Shevchenko1, O.S. Shevchenko1, N.S. Tregub4

1NU of Civil Defence of Ukraine, Kharkiv, Ukraine; 2Kielce University of Technology, Kielce, Poland; 3NDU of Ukraine named after Ivan Cherniakhovskyi, Kyiv, Ukraine; 4Kharkiv State Academy of Design and Arts, Kharkiv, Ukraine

Investigation of the use of the acoustic effect in extinguishing fires of oil and petroleum products


This paper discusses the use of an acoustic effect and technique to extinguish flames when extinguishing fires of oil and petroleum products. The added value is also to analyze the development prospects to familiarize the reader with the current state of knowledge in the use of acoustic waves for extinguishing of oil and petroleum products. Some types and conditions of using the acoustic effect when extinguishing a fire are considered. Various options for using the acoustic effect in fire extinguishers are shown. The prospects and environmental friendliness of the acoustic method in extinguishing the fires of oil and petroleum products are noted.

Keywords: acoustic effect; oil; petroleum product; environment; firefighting; flame; acoustic fire extinguisher.

This paper discusses the use of an acoustic effect and technique to extinguish flames when extinguishing fires of oil and petroleum products. The added value is also to analyze the development prospects to familiarize the reader with the current state of knowledge in the use of acoustic waves for extinguishing of oil and petroleum products. Some types and conditions of using the acoustic effect when extinguishing a fire are considered. Various options for using the acoustic effect in fire extinguishers are shown. The prospects and environmental friendliness of the acoustic method in extinguishing the fires of oil and petroleum products are noted.

Keywords: acoustic effect; oil; petroleum product; environment; firefighting; flame; acoustic fire extinguisher.

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DOI: 10.5510/OGP2021SI200602

E-mail: vloboichm@gmail.com


А.К. Маzitоvа, G.К. Аminovа, I.N. Vikharevа

Ufa State Petroleum Technological University, Ufа, Russia

Modeling the kinetic regularities of the preparation of dibutoxyethyl adipates


Additives are important components of PVC composites, providing polymer modification and retention of its properties throughout the entire period of operation. The development and application of environmentally friendly adipate plasticizers is urgent. The article presents the results of kinetic studies of the esterification of adipic acid with ethoxylated n-butanol of varying degrees of ethoxylation. The effect of various catalysts on the yield of the target ester and the degree of ethoxylation on the rate of the esterification reaction was studied. A mathematical model of the kinetics of the process of obtaining dibutoxyethyl adipates of various degrees of ethoxylation has been developed, which makes it possible to predict the technological indicators of the efficiency of the acid catalyst and the effect of the degree of ethoxylation of the alcohol used.

Keywords: adipate plasticizer; kinetics; mathematical model; polyvinyl chloride; prediction; esterification.

Additives are important components of PVC composites, providing polymer modification and retention of its properties throughout the entire period of operation. The development and application of environmentally friendly adipate plasticizers is urgent. The article presents the results of kinetic studies of the esterification of adipic acid with ethoxylated n-butanol of varying degrees of ethoxylation. The effect of various catalysts on the yield of the target ester and the degree of ethoxylation on the rate of the esterification reaction was studied. A mathematical model of the kinetics of the process of obtaining dibutoxyethyl adipates of various degrees of ethoxylation has been developed, which makes it possible to predict the technological indicators of the efficiency of the acid catalyst and the effect of the degree of ethoxylation of the alcohol used.

Keywords: adipate plasticizer; kinetics; mathematical model; polyvinyl chloride; prediction; esterification.

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DOI: 10.5510/OGP2021SI200597

E-mail: irina.vikhareva2009@yandex.ru