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.

O. A. Zeynalova

on behalf of SOCAR Proceedings Editorial Staff, Managing Editor

«OilGasScientificResearchProject» Institute, SOCAR researchers among World's Ranking of Top 2% Scientists on Stanford University list


The prestigious list of the world's TOP 2% influential scientists has been released by analysts from Stanford University, Elsevier Publishing and SciTech Strategies. Stanford University experts led by Professor John P.A. Ioannidis prepared this analysis based on Scopus data provided by Elsevier through ICSR Lab.

The list covered almost 200,000 scientists from 22 scientific disciplines divided into 176 subfields, including 14 scientists from 6 disciplines working in Azerbaijan scientific centers. This year, two different list of the ranking were published: the Career-long scientific output until 2022 was in first list, and the second list included the citation ranking for single 2022 year data. Deputy director for oil and gas production, Prof., Doctor, Corresponding Member of ANAS Suleimanov Baghir and Head of Laboratory of Analytical Research, Doctor Veliyev Elchin from «OilGasScientificResearchProject» Institute, SOCAR are the ones whose names were chosen to be in the Top 2% Scientists list, which includes scientific output for the entire period of professional work until 2022. Both of them are in Top 3 among Azerbaijani scientists who are in this ranking. In 2021 the Top 2% Scientists list including 6 scientists from Azerbaijan scientific centers and Suleimanov Baghir was in Top 2 among Azerbaijani scientists who are in this ranking.

During preparation of this list, the entire scientific output of researchers according to a bibliometric index, including criteria such as citations, h-index, co-authorship adjusted hm-index, citations to papers in different authorship positions and a composite indicator (c-score) were evaluated.

We congratulate to Founding Editor Suleimanov Baghir and Member of Editorial Board Veliyev Elchin.

DOI: 10.5510/OGP20220400795

E-mail: ofelya.zeynalova@socar.az


G. J. Yetirmishli, S. E. Kazimova, S. S. Ismailova, I. E. Kazimov

Republican Seismic Survey Center of ANAS, Baku, Azerbaijan

Modern geodynamics and seismicity of the Azerbaijani sector of the Caspian Sea


The region’s oil fields are located within the South Caspian oil and gas basin, on the territory of the Absheron Peninsula and the adjacent waters of the Caspian Sea. Here are more than 80 oil and gas fields. To this end, this article presents the geological structure of the South Caspian Depression, as well as the Absheron-Balkhan zone. The analysis of oil and gas content and modern seismicity of the Caspian Sea is carried out. Increasing recoverable oil reserves, reducing water cut, increasing or even stabilizing production at this stage is the number one task for the oil industry. It has been established that in recent years, the level of seismic activity of individual sections of the Caspian water area has increased, and the amount of seismic energy released in the Central Caspian has increased by several dozen times, it can be assumed that the change in oil production in many offshore fields in the northern part of the Absheron-Balkhan fold system is associated with strong (ml>3.0) earthquakes characterized by fault-shear type of movements.

Keywords: Caspian sea; oil and gas deposits; earthquake source mechanisms.

The region’s oil fields are located within the South Caspian oil and gas basin, on the territory of the Absheron Peninsula and the adjacent waters of the Caspian Sea. Here are more than 80 oil and gas fields. To this end, this article presents the geological structure of the South Caspian Depression, as well as the Absheron-Balkhan zone. The analysis of oil and gas content and modern seismicity of the Caspian Sea is carried out. Increasing recoverable oil reserves, reducing water cut, increasing or even stabilizing production at this stage is the number one task for the oil industry. It has been established that in recent years, the level of seismic activity of individual sections of the Caspian water area has increased, and the amount of seismic energy released in the Central Caspian has increased by several dozen times, it can be assumed that the change in oil production in many offshore fields in the northern part of the Absheron-Balkhan fold system is associated with strong (ml>3.0) earthquakes characterized by fault-shear type of movements.

Keywords: Caspian sea; oil and gas deposits; earthquake source mechanisms.

References

  1. Agaev, V. B., Huseynov, H. M., Balammedov, Sh. R., Amirov, E. F. (2006). Caspian Sea: the genesis, geodynamics and stratigraphy. Vestnik Bakinskogo universiteta. Seriya: Yestestvennyye Nauki, 1, 86-101.
  2. Vorob'yev, V. Ya., Ogadzhanov, V. A., Solomin, S. V. (1999). Svyaz' geodinamiki i napryazhennogo sostoyaniya zemnoy kory vostochno-yevropeyskoy platformy s neftegazonosnost'yu. Geofizika, 4, 52-55.
  3. Gadzhi-Kasumov, A. S., Mustayev, R. N., Mukasheva, N. V. i dr. (2012). Osobennosti generatsii UV v YuzhnoKaspiyskom basseyne. V sbornike tezisov 1-y mezhdunarodnoy konferentsii «Uglevodorodnyy potentsial bol'shikh glubin: Energeticheskiye resursy budushchego – real'nost' i prognoz». Baku: Izdatel'stvo «Nafta-Press».
  4. Glumov, I. F., Malovitskiy, Ya. P., Novikov, A. A. i dr. (2004). Regional'naya geologiya i neftegazonosnost' Kaspiyskogo morya. Moskva: Nedra-Biznestsentr.
  5. Guliyev, I. S., Fedorov, D. L., Kulakov, S. I. (2009). Neftegazonosnost' Kaspiyskogo regiona: monografiya. Baku: Nafta-Press.
  6. Dzhafarov, I. S., Kerimov, V. Yu., Shilov, G. ya. (2005). Shel'f, yego izucheniye i znacheniye dlya poiskov i razvedki skopleniy nefti i gaza. Sankt-Peterburg: Nedra.
  7. Donabedov, A. T., Korovina, T. L. (1974). O sootnoshenii seysmichnosti i dinamicheskikh parametrov mestorozhdeniy nefti i gaza. Problemy geologii nefti, 4, 38-50.
  8. Dubinina, N. À. (2015). Prospects of the development of JSC «Lukoil» projects in the Northern Caspian. Vestnik of Astrakhan State Technical University, 1, 102-108.
  9. Etirmishli, G. J., Valiev, G. O., Kazimova, S. E., et al. (2019). Technologies of residual oil extraction. Geology and Geophysics of the South of Russia, 9(1), 84-96.
  10. Etirmishli, G. J., Abdullayeva, R. R., Kazymova, S. E., Ismailova, S. S. (2016). Sil'nyye zemletryaseniya na territorii Azerbaydzhana v period 2004-2015 gg. Materialy mezhdunarodnoy nauchno-prakticheskoy konferentsii «Chrezvychaynyye situatsii i bezopasnaya zhizn'», posvyashchennoy 10-letnemu yubileyu MCHS AR, 140-151.
  11. Kazimova, S. E., Kazimov, I. E. (2016). The modern geodynamics of the middle and southern part of Caspian Sea. Geology and Geophysics of the South of Russia, 2, 140-151.
  12. Kazymova, S. E., Kerimova, R. D. Mamedova, A. Sh., Khalilova, A. A. (2015). Napryazhennoye sostoyaniye litosfery azerbaydzhanskoy chasti Kaspiyskogo regiona na osnove sovremennykh seysmologicheskikh dannykh /v sb. «Sovremennyye metody obrabotki i interpretatsii seysmologicheskikh dannykh». Obninsk.
  13. Kerimov, V. Yu., Averbukh, B. M., Mil'nichuk, V. S. (1990). Tektonika Severnogo Kaspiya i perspektivy neftegazonosnosti. Sovetskaya geologiya, 7, 23-30.
  14. Lebedev, L. I. (2002). Perspektivy neftegazonosnosti Kaspiyskogo morya. Geologiya i poleznyye iskopayemyye shel'fov Rossii. Moskva: GEOS.
  15. Mekhtiyev, Sh. F., Khalilov, Ye. N., Gadzhiyev, F. G. (1987). O vozmozhnosti regional'nogo prognozirovaniya neftegazonosnosti po otsenke parametrov seysmichnosti. Azerbaydzhanskoye neftyanoye khozyaystvo, 6, 1-4.
  16. Milashin, V. A., Pisetskiy, V. B., Trofimov, V. A. i dr. (2000). Prognoz lovushek nefti dinamicheskogo genezisa v karbonatnom basseyne po seysmicheskim dannym. Geofizika, 5, 3-5.
  17. Serikova, U. S. (2013). Hydrocarbonic resources and prospects of development of oil and gas complex of the Caspian region. Oil and Gas Business, 6, 47-55.
  18. Serikova, U. S. (2013). Stanovleniye i razvitiye neftegazovogo kompleksa Kaspiyskogo regiona, Avtoreferat dissertatsii na soiskaniye uchenoy stepeni kandidata tekhnicheskikh nauk. Ufa: UGNTU.
  19. Trofimuk, A. A., Cherskiy, N. V., Tsarev, V. P., Soroko, T. N. (1981). Novyye dannyye po eksperimental'nomu izucheniyu preobrazovaniya iskopayemogo organicheskogo veshchestva s ispol'zovaniyem mekhanicheskikh poley. Doklady AN SSSR, 257(1), 207-211.
  20. Hasanov, A. H., Mammadov, T. X., Abdullayeva, R. R. (1999). Xazar denizinin seysmikliyi ve onun derinlik qurulushu ile elaqesi haqqinda. Azerbaycanda Geofizikа Yenilikleri, 3, 20-21.
  21. Kerimov, K. M., Veliyev, H. O. (1998). Geofiziki va geokimyevi variasiyalarda mushahide olunan qanunauygunluqlar. «Zelzelenin geofiziki va geokimyevi usullarla proqnozu» movzusunda beynalxalq seminarin tezisleri. Baki.
  22. Yetirmishli, G. J. (2000). Geodynamic conditions of the Lower Kura basin and distribution of oil and gas deposits. PhD Thesis. Baku.
  23. Veliyev, H. O. (2001). Geodinamik aktiv zonalarda neft-qaz yataqlari axtarishinin yeni istiqametleri. Azerbaycanda Geofizika Yenilikleri, 1, 18-22.
Read more Read less

DOI: 10.5510/OGP20220400777

E-mail: sabina.k@mail.ru


E. M. Suleymanov, S. H. Novruzova, I. N. Aliev, E. V. Gadashova

Azerbaijan State Oil and Industry University, Baku, Azerbaijan

Evaluation of the influence of reservoir fluid on the occurrence of sticking of drill strings and casing strings under the influence of differential pressure


In the work, a dependence was obtained, analyzing which it is easy to see that the dimensionless parameter of sticking hazard depends very significantly on the permeability of the reservoir and increases in proportion to the increase in pressure drop, which is fully confirmed by the results of numerous experimental studies of sticking under the action of pressure drop. At the same time, one of the main, but previously not taken into account, factors that contribute to the occurrence of sticking in drilling wells is the viscosity of the formation fluid, as it decreases, the dimensionless sticking hazard parameter (i.e., the possible sticking force) in the interval of occurrence of a given permeable formation increases sharply. Indeed, the experience of drilling operations in various regions indicates that when drilling wells in gas fields, the frequency and severity of sticking is much higher than when drilling wells in oil fields, this requires special consideration in the process of drilling wells in gas fields.

Keywords: sticking; drilling and casing strings; differential pressure; filter cake; viscosity; formation fluid.

In the work, a dependence was obtained, analyzing which it is easy to see that the dimensionless parameter of sticking hazard depends very significantly on the permeability of the reservoir and increases in proportion to the increase in pressure drop, which is fully confirmed by the results of numerous experimental studies of sticking under the action of pressure drop. At the same time, one of the main, but previously not taken into account, factors that contribute to the occurrence of sticking in drilling wells is the viscosity of the formation fluid, as it decreases, the dimensionless sticking hazard parameter (i.e., the possible sticking force) in the interval of occurrence of a given permeable formation increases sharply. Indeed, the experience of drilling operations in various regions indicates that when drilling wells in gas fields, the frequency and severity of sticking is much higher than when drilling wells in oil fields, this requires special consideration in the process of drilling wells in gas fields.

Keywords: sticking; drilling and casing strings; differential pressure; filter cake; viscosity; formation fluid.

References

  1. Suleimanov, B. A. (1995). Filtration of disperse systems in a nonhomogeneous porous medium. Colloid Journal, 57(5), 704-707.
  2. Suleimanov, B. A. (1996). Experimental study of the formation of fractal structures in displacement of immiscible fluids using a Hele-Shaw cell. Journal of Engineering Physics and Thermophysics, 69(2), 182-187.
  3. Suleimanov, B. A. (1996). Effect of a surface-active substance on nonequilibrium phenomena in filtration of gas-liquid systems in the subcritical region. Journal of Engineering Physics and Thermophysics, 69(4), 427-431.
  4. Suleimanov, B. A. (1997). Slip effect during filtration of gassed liquid. Colloid Journal, 59(6), 749-753.
  5. Suleimanov, B. A. (1999). The slip effect during filtration of gassed non-Newtonian liquids. Colloid Journal, 61(6), 786-790.
  6. Suleimanov, B. A. (2004). On the effect of interaction between dispersed phase particles on the rheology of fractally heterogeneous disperse systems. Colloid Journal, 66(2), 249–252.
  7. Suleimanov, B. A. (2011). Mechanism of slip effect in gassed liquid flow. Colloid Journal, 73(6), 846–855.
  8. Suleimanov, B. A. (2011). Sand plug washing with gassy fluids. SOCAR Proceedings, 1, 30–36.
  9. Suleimanov, B. A. (2012). The mechanism of slip in the flow of gassed non-Newtonian liquids. Colloid Journal, 74(6), 726–730.
  10. Rabia, H. (1989). Oil drilling technology. Moscow: Nedra.
  11. Samotoy, A. K. (1984). Sticking pipe strings when drilling wells. Moscow: Nedra.
  12. (1999). Gas miqration control technology. USA: Schlumberger Dowell.
  13. Rang, C. L. (1987, April). Evaluation of gas flows in cement. SPE-16385-MS. In: SPE California Regional Meeting, Ventura, California, USA. Society of Petroleum Engineers.
  14. (1995). Schlumberger wireline and testing catalog. USA: Houston, Texas.
  15. Steawart, R. B., Schouten, F. C. (1988). Gas invasion and migration in cemented annuli: causes and cures. SPE-14779-PA. SPE Drilling Engineering, 3(01), 77-82.
  16. Lyons, W. C., Stanley, J. H., Sinisterra, F. J., Weller, T. (2021). Air and gas drilling manual. Gulf Professional Publishing,
    Elsevier Inc.
  17. Rafiqul Islam, M., Enamul Hossain, M. (2021). Drilling engineering. Gulf Professional Publishing, Elsevier Inc.
  18. Xiaozhen, S. (2013). Common well control hazards. Gulf Professional Publishing, Elsevier Inc.
  19. Suleimanov, E. M. (2012). Prevention and elimination of accidents and complications during drilling. Germany: Palmarium Academic Publishing.
  20. Bogdanov, R. K., Bugaev, A. A., Golod, N. V., Livshits, V. N. (1984). Rock-breaking insert. SU Patent 1086110.
Read more Read less

DOI: 10.5510/OGP20220400778

E-mail: sudaba.novruzova@mail.ru


B. А. Suleimanov1, А. Q. Gurbanov2, Sh. Z. Tapdiqov1

1«OilGasScientificResearchProject» Institute, SOCAR, Baku, Azerbaijan; 2Umid Babek Operation Company (UBOC), Баku, Azerbaijan

Isolation of water inflow into the well with a thermosetting gel-forming


A method has been developed for isolating water inflow into a well based on the injection of a thermoactive mixture of solutions of a gel-forming initiator and a gelling agent. The method allows to control the isolation process by regulating the gel-forming time by means of temperature and delivering the mixture to a given formation depth. To ensure mixing of the components of the composition in full and to prevent the formation of sediment, before injection, a solution of a gelling agent is added into the solution of the gel-forming initiator. It is possible to mix the components of the mixture directly in the wellbore by successively pumping solutions of the gel-forming initiator and the gelling agent. The results of oil sweeping experiments showed that the developed technology for isolating water inflow based on the use of a thermoactive gel-forming mixture significantly exceeds the known compositions in terms of technological efficiency. After applying the proposed technology, zones with increased oil saturation are involved in the development, there is also a decrease in the volume of produced water, and the profitability of production increases.

Keywords: water inflow isolation; gelling agent; gel-forming initiator; thermoactivity; sweeping ratio; technological efficiency.

A method has been developed for isolating water inflow into a well based on the injection of a thermoactive mixture of solutions of a gel-forming initiator and a gelling agent. The method allows to control the isolation process by regulating the gel-forming time by means of temperature and delivering the mixture to a given formation depth. To ensure mixing of the components of the composition in full and to prevent the formation of sediment, before injection, a solution of a gelling agent is added into the solution of the gel-forming initiator. It is possible to mix the components of the mixture directly in the wellbore by successively pumping solutions of the gel-forming initiator and the gelling agent. The results of oil sweeping experiments showed that the developed technology for isolating water inflow based on the use of a thermoactive gel-forming mixture significantly exceeds the known compositions in terms of technological efficiency. After applying the proposed technology, zones with increased oil saturation are involved in the development, there is also a decrease in the volume of produced water, and the profitability of production increases.

Keywords: water inflow isolation; gelling agent; gel-forming initiator; thermoactivity; sweeping ratio; technological efficiency.

References

  1. Taha, A., Amani, M. (2019). Overview of water shutoff operations in oil and gas wells; Chemical and mechanical solutions. ChemEngineering, 3(2), 51.
  2. Bergmo, P. E. S., Grimstad, A. (2022, April). Water Shutoff technologies for reduced energy consumption. SPE-209555-MS. In: SPE Norway Subsurface Conference. Society of Petroleum Engineers.
  3. Manyrin, V. N., Shvetsov, I. A. (2002). Physico-chemical methods of enhanced oil recovery by water flooding. Samara: House Press.
  4. Al-Azmi, A. A., Al-Yaqout, T. A., Al-Jutaili, D. Y., et al. (2021, June). Application of specially designed polymers in high water cut wells- a holistic well-intervention technology applied in Umm Gudair field, Kuwait. SPE-200957-MS. In: SPE Trinidad and Tobago Section Energy Resources Conference. Society of Petroleum Engineers.
  5. Yang, Y., Li, X., Sun, C., et al. (2021, November). Innovated water shutoff technology in offshore carbonate reservoir. SPE-204593-MS. In: SPE Middle East Oil & Gas Show and Conference. Society of Petroleum Engineers.
  6. Wang, J., Wang, T., Xu, H., et al. (2022). Graded regulation technology for enhanced oil recovery and water shutoff in porecavity-fracture carbonate reservoirs. Arabian Journal of Chemistry, 15(7), 1-13.
  7. Al-Ebrahim, A. E., Al-Houti, N., Al-Othman, M., et al. (2017, November). A new cost effective and reliable water shutoff system: Case study in Kuwait. In: Abu Dhabi International Petroleum Exhibition & Conference. Society of Petroleum Engineers.
  8. Cottin, C., Al-Amrie, O., Barrois, E. (2017, November). Chemical water shutoff pilot in a mature offshore carbonate field. SPE-188871-MS. In: Abu Dhabi International Petroleum Exhibition & Conference. Society of Petroleum Engineers.
  9. Zhang, G., Qian, J., Shen, Z., et al. (2017, April). The application of water shut-off technique in Jidong oilfield. SPE-188098-MS. In: SPE Kingdom of Saudi Arabia Annual Technical Symposium and Exhibition. Society of Petroleum Engineers.
  10. Rzayeva, S. J. (2020). Selective insulation of water flows in a well based on the use of production waste. SOCAR Proceedings, 3, 118-125.
  11. Veliyev, E. F. (2020). Review of modern in-situ fluid diversion technologies. SOCAR Proceedings, 2, 50-66.
  12. Suleimanov, B. A., Rzayeva, S. J., Akberova, A. F., Akhmedova, U. T. (2021). Deep diversion strategy of the displacement front during oil reservoirs watering. SOCAR Proceedings, 4, 33-42.
  13. Wu, P., Hou, J., Qu, M., et al. (2022). A novel polymer gel with high-temperature and high-salinity resistance for conformance control in carbonate reservoirs. Petroleum Science, In press. https://doi.org/10.1016/j.petsci.2022.05.003
  14. Sharma, P., Kudapa, V. K. (2022). Study on the effect of cross-linked gel polymer on water shutoff in oil wellbores. Materials Today: Proceedings, 48(5), 1103-1106.
  15. Petrov, N. A., Korenyako, A. V., Yangirov, F. N., Yesipenko, A. I. (2005). Ogranicheniye pritoka vody v skvazhinakh. Sankt-Peterburg: Nedra.
  16. Dobroskok, B. E., Kubareva, N. N., Musabirov, R.Kh., et al. (2000). Method of restriction of water influx to well. RU Patent 2160832.
  17. Starkovskij, A. V., Rogova, T. S., Gorbunov, A. T. (1991). Process of isolation of water inflow and absorption zone. RU Patent 1774689.
  18. Shakhverdiev, A. Kh., Panakhov, G. M., Suleimanov, B. A., et al. (1998). Method of restricting water inflow to well. RU Patent 2121570.
  19. Suleimanov, B. А., Abdullayev, V. D., Таpdigov, Sh. Z., et al. (2022). Method of water shut-off to well. Application for a Eurasian patent for an invention № 202292862, 07.09.22.
Read more Read less

DOI: 10.5510/OGP20220400779

E-mail: baghir.suleymanov@socar.az


E. R. Agishev1, R. N. Bakhtizin2, G. S. Dubinsky2, V. V. Mukhametshin2, V. E. Andreev2,3, L. S. Kuleshova4, Sh. G. Mingulov4

1JV «Vietsovpetro», Vung Tau, Vietnam; 2USPTU, Ufa, Russia; 3Institute of Strategic Research of the Republic of Bashkortostan, Ufa, Russia; 4Institute of Oil and Gas, USPTU (branch  in Oktyabrsky), Russia

Optimization of the development of multilayer productive formations by changing the parameters of well completion and their location


Due to the increase in the volume of hard-to-recover oil reserves, in complex deposits, reservoirs with reduced filtration properties, fields in remote, without infrastructure, new tasks have appeared that need to be solved when developing these reserves so that it is cost-effective. It requires the use of new methods for selecting methods and systems of development with the simultaneous introduction of new methods for intensifying production and increasing oil recovery. The article investigates a method for improving the efficiency of the development system of a layered and heterogeneous productive formation of the «ryabchik» type by controlling the parameters of the well grid and well completion. The analyzed method of optimization of development will increase the efficiency of extraction of hard-to-recover oil reserves and increase the degree of their production. Proposals have been made to increase the efficiency of the development of a formation of the «ryabchik» type.

Keywords: horizontal well; trunk orientation; optimization of the well grid; development efficiency; multilayer formation.

Due to the increase in the volume of hard-to-recover oil reserves, in complex deposits, reservoirs with reduced filtration properties, fields in remote, without infrastructure, new tasks have appeared that need to be solved when developing these reserves so that it is cost-effective. It requires the use of new methods for selecting methods and systems of development with the simultaneous introduction of new methods for intensifying production and increasing oil recovery. The article investigates a method for improving the efficiency of the development system of a layered and heterogeneous productive formation of the «ryabchik» type by controlling the parameters of the well grid and well completion. The analyzed method of optimization of development will increase the efficiency of extraction of hard-to-recover oil reserves and increase the degree of their production. Proposals have been made to increase the efficiency of the development of a formation of the «ryabchik» type.

Keywords: horizontal well; trunk orientation; optimization of the well grid; development efficiency; multilayer formation.

References

  1. Shmal, G. I. (2017). Oil and gas complex in response to geopolitical and economic challenges: problems and solutions. Oil
  2. Industry, 5, 8-11.
  3. Kontorovich, A. E., Livshits, V. R., Burshtein, L. M., Kurchikov, A.R. (2021). Assessment of the initial, promising, and predicted geologic and recoverable oil resources of the West Siberian petroleum province and their structure. Russian Geology and Geophysics, 62(5), 576-588.
  4. 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.
  5. Kontorovich, A. E., Filippov, S. P., Alekseenko, S. V., et al. (2019). Discussion on the priority: speachs of academicians A.E. Kontorovich, S.P. Filippov, S.V. Alekseenko, V.I. Bukhtiyarov, S.M. Aldoshin. Herald of the Russian Academy of Sciences, 89(4), 343-347.
  6. Dmitrievsky, A. N. (2017). Resource-innovative strategy for the development of the Russian economy. Oil Industry, 5, 6-7.
  7. Grishchenko, V. A., Gareev, R. R., Tsiklis, I. M., et al. (2021). Expanding the amount of preferential royalty facilities with hard-to-recover oil reserves. SOCAR Proceedings, SI2, 8-18.
  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. Grishchenko, V. A., Pozdnyakova, T. V., Mukhamadiyev, B. M., et al. (2021). Improving the carbonate reservoirs development efficiency on the example of the Tournaisian stage deposits. SOCAR Proceedings, SI2, 238-247.
  10. 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.
  11. Shpurov, I. V., Zakharenko, V. A., Fursov, A. Ya. (2015). A differentiated analysis of the degree of involvement and the depletion of stocks of jurassic deposits in the Western Siberian oil-and-gas province. Subsoil Using – XXI Century, 1(51), 12-19.
  12. 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.
  13. 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.
  14. 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.
  15. Grishchenko, V. A., Asylgareev, I. N., Bakhtizin, R. N., et al. (2021). Methodological approach to the resource base efficiency monitoring in oil fields development. SOCAR Proceedings, SI2, 229-237.
  16. 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.
  17. Muslimov, R. Kh. (2014). Oil recovery: past, present, future (production optimization, maximization of oil recovery). Kazan: FEN.
  18. Economides, J. M., Nolte, K. I. (2000). Reservoir stimulation. West Sussex, England: John Wiley and Sons.
  19. Khisamiev, T. R., Bashirov, I. R., Mukhametshin, V. Sh., et al. (2021). Results of the development system optimization and increasing the efficiency of carbonate reserves extraction of the Turney stage of the Chetyrmansky deposit. SOCAR Proceedings, SI2, 131-142.
  20. 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.
  21. Grishchenko, V. A., Rabaev, R. U., Asylgareev, I. N., et al. (2021). Methodological approach to optimal geological and technological characteristics determining when planning hydraulic fracturing at multilayer facilities. SOCAR Proceedings, SI2, 182-191.
  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.
  23. Veliyev, E. F. (2020). Review of modern in-situ fluid diversion technologies. SOCAR Proceedings, 2, 50-66.
  24. Butorin, A. V., Zinnurova, R. R., Mityaev, M. U., et al. (2015). Estimating the potential of the Tumen formation in the Noyabrsk region of Western Siberia. Oil Indutry, 12, 41-43.
  25. 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.
  26. 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.
  27. Vygon, G. V. (2019). Inventory of stocks: from state expertise to national audit. Oil and Gas Vertical, 18(462), 19-24.
  28. 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.
  29. Veliyev, E. F. (2020). Mechanisms of polymer retention in porous media. SOCAR Procеedings, 3, 126-134.
  30. Grishchenko, V. A., Tsiklis, I. M., Mukhametshin, V. Sh., Yakupov, R. F. (2021). Methodological approaches to increasing the flooding system efficiency at the later stage of reservoir development. SOCAR Proceedings, SI2, 161-171.
  31. Fattakhov, I. G., Kuleshova, L. S., Bakhtizin, R. N., et al. (2021). Complexing the hydraulic fracturing simulation results when hybrid acid-propant treatment performing and with the simultaneous hydraulic fracture initiation in separated intervals. SOCAR Proceedings, SI2, 103-111.
  32. 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.
  33. Mukhametshin, V. V., Bakhtizin, R. N., Kuleshova, L. S., et al. (2021). Screening and assessing the conditions for effective oil recovery enhancing techniques application for hard to recover high-water cut reserves. SOCAR Proceedings, SI2, 48-56.
  34. Agishev, E. R., Zhdanov, L. M., Ramadanov, A. V., et al. (2022) Determination of features of the geological structure of Lower Aptian formation of West Siberian on basis of refined lithological-facial model of reservoir AV11-2. Exposition Oil Gas, 2(87), 20-23.
  35. (2022). US crude oil field production. Ycharts Inc. https://ycharts.com/indicators/us_crude_oil_field_production
  36. Dremin, D. S., Dubinsky, G. S. (2017). Geological substantiation of the transformation of the object development system of the object of the BP of Tarasovo deposit. Сollection of scientific papers «Oil and gas technologies and new materials. Problems and solutions». Ufa: Monografiya.
  37. Brilliant, L. S., Klochkov, A. A., Vydrin, A. G., et al. (2010). Reservoir geological properties effect on the effectiveness of horizontal wells drilling at the Samotlorskoye field AV1 1-2 object. Oil Industry, 10, 82-84.
  38. Badykov, I. Kh., Baikov, V. A., Borshchuk, O. S. (2015). The software package «RN-KIM» as a tool for hydrodynamic modeling of hydrocarbon deposits. Subsoil Using – XXI Century, 4(54), 96-103.
  39. Sarvarov, A. R., Litvin, V. V., Vladimirov, I. V., et al. (2008). The influence of the location of the horizontal well bore on the oil recovery coefficient and the density of the well grid. Geology, Geophysics and Development of Oil and Gas Deposits, 12, 61-63.
  40. Abdulmyanov, S. Kh., Elovikov, S. L., Schekaturova, I. Sh. (2012). Efficiency of formation and specification of value of wells pattern density with account of horizontal well bores. Oilfield Engineering, 11, 38-41.
  41. Emeka, O. J., Durlofsky, L. (2009, October). Development and application of a new well pattern optimization algorithm for optimizing large scale field development. In: SPE Annual Technical Conference and Exhibition. Society of Petroleum Engineers.
  42. Maltsev, V. V., Nikitin, A. N., Kardymon, D. M., et al. (2010). Experience of using special GIS at the fields of LLC «RN– Yuganskneftegaz» for the tasks of hydraulic fracturing optimization. Territory of Neftegaz, 11, 52-57.
  43. (2015). Minutes of the meeting of the Central Committee Rosnedra on UVS No. 6427 dated 12/16/2015.
Read more Read less

DOI: 10.5510/OGP20220400780

E-mail: vv@of.ugntu.ru


R. A. Gasumov1, E. R. Gasumov2

1North Caucasian Federal University, Stavropol, Russia; 2Azerbaijan State University of Oil and Industry, Baku, Azerbaijan

Assessment of reasonability of production wells transfer to well workover stage


The article discusses predicting the critical parameters of production wells to assess the need to transfer them to well workover stage and put on the program of geological and technical measures (GTM). A methodology for substantiating and assessing the influence of critical values of reservoir parameters on the operation of production wells is presented. Three stages of transferring wells to workover are considered: geological, technological and analytical, and the procedure for assessing their effectiveness. The procedure for calculating the shut-in time of wells and gas losses during the transition of production wells to workover, determining the parameters of the technological regime after geological and technical measures are considered. A method has been developed for predicting the time of well shut-in due to flooding (self-killing) and assessing the timing of its operation with production flow rates at the final stage of field development. The results of the study of dependence of the critical height of the liquid column on the bottomhole pressure and the average daily flow rate of the Cenomanian well, the scheme for revealing the dependence of gas water contact level on the reservoir pressure and the volume of the sampled gas are presented. The procedure for calculating the technical and geological-production state of wells is considered according to the diagnostic rating assessment.

Keywords: field; gas well; prediction; critical parameter; cenomanian; flooding; flow rate; pressure.

The article discusses predicting the critical parameters of production wells to assess the need to transfer them to well workover stage and put on the program of geological and technical measures (GTM). A methodology for substantiating and assessing the influence of critical values of reservoir parameters on the operation of production wells is presented. Three stages of transferring wells to workover are considered: geological, technological and analytical, and the procedure for assessing their effectiveness. The procedure for calculating the shut-in time of wells and gas losses during the transition of production wells to workover, determining the parameters of the technological regime after geological and technical measures are considered. A method has been developed for predicting the time of well shut-in due to flooding (self-killing) and assessing the timing of its operation with production flow rates at the final stage of field development. The results of the study of dependence of the critical height of the liquid column on the bottomhole pressure and the average daily flow rate of the Cenomanian well, the scheme for revealing the dependence of gas water contact level on the reservoir pressure and the volume of the sampled gas are presented. The procedure for calculating the technical and geological-production state of wells is considered according to the diagnostic rating assessment.

Keywords: field; gas well; prediction; critical parameter; cenomanian; flooding; flow rate; pressure.

References

  1. Gasumov, R. A., Gasumov, E. R. (2020). Calculation of the processes of periodic blowdowns of self-killing gas wells. Construction of Oil and Gas Wells on Land and at Sea, 1(337), 49-55.
  2. Gasumov, R. A., Gasumov, E. R., Veliyev, V. M. (2020). Evaluation of production gas well efficiency and its transfer to well workover stage. International Scientific Research Journal, 11(101), 56-63.
  3. Gasumov, R. A., Tolpaev, V. A., Akhmedov, K. S. (2021). Theoretical foundations of planning geological and technical measures on gas wells. Gazovaya Promyshlennost, 5, 60-72.
  4. Gasumov, R. A., Gasumov, E. R., Veliyev, V. M. (2020). Prediction of critical parameters of production wells transfer to well workover stage. Science and Technology in the Gas Industry, 4(84), 52-61.
  5. Gasumov, R. A., Tolpaev, V. A., Akhmedov, K. S. (2020). Model for calculating predicted well flow rates with accumulated field data. Gazovaya Promyshlennost, 9(806), 76-84.
  6. Karnaukhov, V. L., Pyankova, E. M. (2010). Modern methods of well testing. Moscow: Infra-Engineering.
  7. Korotaev, Yu. P. (1996). Selected works. Moscow: Nedra.
  8. Gasumov, R. A., Gasumov, E. R. (2020). Innovative risk management for geological and technical (technological) measures at oil and gas fields. SOCAR Proceedings, 2, 8-16.
  9. Khanin, A. A. (1969). Rocks-reservoirs of oil and gas and their study. Moscow: Nedra.
  10. Wallis, G. (1972). One-dimensional two-phase flows. Moscow: Mir.
  11. Odisharia, G. E., Tochigin, A. A. (1998). Applied hydrodynamics of gas-liquid mixtures. Moscow: VNIIgaz.
  12. Gasumov, R. A., Gasumov, E. R. (2020). Assessment of production gas well efficiency and its transfer to well workover stage. Nauka. Innovation. Technologies, 3, 49-64.
  13. Gasumov, R. A., Tolpaev, V. A., Akhmedov, K. S., et al. (2019). Approximating mathematical models of the operational properties of gas wells and their application to the calculation of predicted flow rates. Oilfield Engineerings, 5, 53-59.
  14. Gasumov, R. A., Tolpaev, V. A., Akhmedov, K. S., Gogoleva, S. A. (2016). Approximating models of gas inflows to wells and calculations of predicted flow rates. Automation, Telemechanization and Communication, 9, 25-37.
  15. Gasumov, R. A., Tolpaev, V. A., Akhmedov, K. S., Vinnichenko, I. A. (2012). Medium-term prediction of production wells flow rates in MS Excel. Automation, Telemechanization and Communication in the Oil Industry, 7, 32-36.
  16. Degtyarev, B. V., Bukhgalter, E. B. (1976). Prevention forming of hydrates during the operation of gas wells in the northern regions. Moscow: Nedra.
  17. Gasumov, R. A., Gasumov, E. R. (2020). A mathematical model for calculating the processes of tubing self-compression with liquid by blowing wells. Oilfield Engineering, 8(620), 46-51.
Read more Read less

DOI: 10.5510/OGP20220400781

E-mail: priemnaya@scnipigaz.ru


G. I. Dzhalalov1, G. Zh. Moldabayeva2, G. E. Kunayeva3

1Institute of Oil and Gas Azerbaijan National Academy of Sciences, Baku, Azerbaijan; 2Satbayev University, Almaty, Kazakhstan; 3Sh. Yessenov ofCaspian State University of Technologies and Engineering, Aktau, Kazakhstan

Parametric identification of the hydrodynamic model of the reservoir by the actual indicators of the event


At the present stage of the development of the oil industry, mathematical modeling is widely used in the design and analysis of development during the entire cycle of field operation. The most laborious and difficult stage in the creation of geological and hydrodynamic models is their identification to the actual development data and resolution of uncertainties associated with the analysis of geological and physical parameters. Parametric identification is the most important procedure in the modeling process, because the degree of reliability of predictive indicators of object development depends on the quality of the results obtained at this stage. The paper presents the main methods and results of adapting the hydrodynamic model in the history of oil field development in order to use the model to calculate forecast options. When creating a geological and hydrodynamic simulation model for the selected block of the Kenkiyak deposit of Kazakhstan, geological and field data and research data on the determination of thermobaric parameters of fluids and rocks were used. To solve this problem, the Masket-Meres model of isothermal unsteady spatial filtration of reservoir fluids was adopted. The desired parameters are refined on the basis of gradient procedures using optimal control theory. The predictive problem of the feasibility of using horizontal wells to increase the oil recovery coefficient of the specified sector of the field has been solved.

Keywords: adaptation; predictive task; oil recovery; oil reservoir; phase permeability; hydrodynamic model.

At the present stage of the development of the oil industry, mathematical modeling is widely used in the design and analysis of development during the entire cycle of field operation. The most laborious and difficult stage in the creation of geological and hydrodynamic models is their identification to the actual development data and resolution of uncertainties associated with the analysis of geological and physical parameters. Parametric identification is the most important procedure in the modeling process, because the degree of reliability of predictive indicators of object development depends on the quality of the results obtained at this stage. The paper presents the main methods and results of adapting the hydrodynamic model in the history of oil field development in order to use the model to calculate forecast options. When creating a geological and hydrodynamic simulation model for the selected block of the Kenkiyak deposit of Kazakhstan, geological and field data and research data on the determination of thermobaric parameters of fluids and rocks were used. To solve this problem, the Masket-Meres model of isothermal unsteady spatial filtration of reservoir fluids was adopted. The desired parameters are refined on the basis of gradient procedures using optimal control theory. The predictive problem of the feasibility of using horizontal wells to increase the oil recovery coefficient of the specified sector of the field has been solved.

Keywords: adaptation; predictive task; oil recovery; oil reservoir; phase permeability; hydrodynamic model.

References

  1. Abasov M. T., Jalalov G. I., Ibragimov T. M., et all. (2012). Hydro-gas dynamics of deep-lying deformed reservoirs of oil and gas fields. Baku: Nafta-Press.
  2. Bulygin V. Ya., Bulygin D. V. (1990). Imitation of oil deposits development. Moscow: Nedra.
  3. Zakirov S. N., Vasiliev V. I., Gutnikov A. I. et al. (1984). Forecasting and regulation of gas field development. Moscow: Nedra.
  4. Zakirov E. S. (2001). Three-dimensional multiphase problems of forecasting, analysis and regulation of oil and gas field development. Moscow Nedra.
  5. Khairullin M.H. (1996). On the solution of inverse coefficient problems of filtration of multilayer layers by the regularization method. DAN RAS, 347(1), 103-105.
  6. Votsalevsky E. S., Kuandykov B. M., Bulekboev Z. E., etc. (1993). Oil and gas fields of Kazakhstan. Handbook. Moscow: Nedra.
  7. Jalalov G. I., Dadashov A. M. (2005). Phase permeability of oil and gas reservoirs. (Bibliographic index of literature). Baku: Nafta-Press.
  8. Kanevskaya R. D. (2002). Mathematical modeling of hydrodynamic processes of hydrocarbon deposits development. Moscow-Izhevsk.
  9. Jalalov G. I., Ibragimov T. M., Aliyev A. A., Gorshkova E. V. (2018). Modeling and investigation of filtration processes in deep-lying oil and gas fields. Baku: «Elm ve tehsil» IPP.
  10. Palatnik B. M., Zakirov I. S. (1990). Identification of parameters of gas deposits under gas and water-pressure modes of development. VNIIE - Gazprom. Moscow.
  11. Jalalov G. I., Dadashov A. M., Zhidkov E. E. (2002). Application of horizontal wells in the development of oil and gas fields (Bibliographic index of literature) Baku: Nafta-Press.
Read more Read less

DOI: 10.5510/OGP20220400782

E-mail: dzhalalovgarib@rambler.ru


R. R. Kadyrov1, V. V. Mukhametshin1, R. U. Rabaev2, L. S. Kuleshova1, V. I. Shchetnikov3, I. F. Galiullina1, A. Kh. Gabzalilova1, Z. A. Garifullina1

1Institute of Oil and Gas, USPTU, (branch in Oktyabrsky), Russia; 22Ufa State Petroleum Technological University, Ufa, Russia; 3JV «Vietsovpetro», Vung Tau, Vietnam

Study of the possibility of reservoir water solutions as a well-killing fluid using


The possibility and expediency of using reservoir and oilfield wastewater in areas of depleted and exhausted deposits in oil production for the preparation of liquids used for well killing, cement slurry mixing; table salt suitable as a food product producing. Based on laboratory studies, it has been found out that from one ton of water, on average, 180–210 kg of well killing fluid and 140–150 kg of common salt can be obtained, and dilution of heavy brine with fresh technical water can significantly increase the cement stone strength when fixing wells. The carried out simulation tests indicate that there is no deterioration in the reservoir properties of productive formations when they come into contact with heavy brines and the possibility of using such brines as a well killing fluid. A method has been developed for well-killing fluid and sodium chloride obtaining from oil field formation waters, including the initial formation water of calcium chloride type purification from mechanical impurities, oil residues, bringing its density to the concentration of calcium chloride, at which sodium chloride precipitates.

Keywords: reservoir water; well killing fluid; table salt; cement stone strength; sodium chloride salting.

The possibility and expediency of using reservoir and oilfield wastewater in areas of depleted and exhausted deposits in oil production for the preparation of liquids used for well killing, cement slurry mixing; table salt suitable as a food product producing. Based on laboratory studies, it has been found out that from one ton of water, on average, 180–210 kg of well killing fluid and 140–150 kg of common salt can be obtained, and dilution of heavy brine with fresh technical water can significantly increase the cement stone strength when fixing wells. The carried out simulation tests indicate that there is no deterioration in the reservoir properties of productive formations when they come into contact with heavy brines and the possibility of using such brines as a well killing fluid. A method has been developed for well-killing fluid and sodium chloride obtaining from oil field formation waters, including the initial formation water of calcium chloride type purification from mechanical impurities, oil residues, bringing its density to the concentration of calcium chloride, at which sodium chloride precipitates.

Keywords: reservoir water; well killing fluid; table salt; cement stone strength; sodium chloride salting.

References

  1. Kovalev, A. A., Mikhaylov, N. N., Sergeeva, E. V. (2017). Physical grounds of hydrocarbons recovery from a productive reservoir containing oil of different properties. Oilfield Engineering, 2, 13-18.
  2. Galkin, V. I., Rastegaev, A. V., Kozlova, I. A. (2013). Studying of geological data influence on efficiency of a formation hydraulic fracturing. Oilfield Engineering, 9, 54-57.
  3. Khisamiev, T. R., Bashirov, I. R., Mukhametshin, V. Sh., et al. (2021). Results of the development system optimization and increasing the efficiency of carbonate reserves extraction of the Turney stage of the Chetyrmansky deposit. SOCAR Proceedings, SI2, 131-142.
  4. Fattakhov, I. G., Kuleshova, L. S., Bakhtizin, R. N., et al. (2021). Complexing the hydraulic fracturing simulation results when hybrid acid-propant treatment performing and with the simultaneous hydraulic fracture initiation in separated intervals. SOCAR Proceedings, SI2, 103-111.
  5. Veliyev, E. F. (2020). Review of modern in-situ fluid diversion technologies. SOCAR Proceedings, 2, 50-66.
  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. Grishchenko, V. A., Tsiklis, I. M., Mukhametshin, V. Sh., Yakupov, R. F. (2021). Methodological approaches to increasing the flooding system efficiency at the later stage of reservoir development. SOCAR Proceedings, SI2, 161-171.
  8. Mukhametshin, V. V., Bakhtizin, R. N., Kuleshova, L. S., et al. (2021). Screening and assessing the conditions for effective oil recovery enhancing techniques application for hard to recover high-water cut reserves. SOCAR Proceedings, SI2, 48-56.
  9. Kontorovich, A. E., Eder, L. V. (2020). A new paradigm of the development strategy for the mineral resource base of the oil producing industry in the Russian Federation. Mineral resources of Russia. Economics and Management, 5, 8-17.
  10. 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.
  11. 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.
  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. Khisamov, R. S., Abdrakhmanov, G. S., Nuriev, I. A., et al. (2012). Method for restriction of brine water inflow to production well. Patent RF 2451165.
  14. Kadyrov, R. R., Mukhametshin, V. V., Galiullina, I. F., et al. (2020). Prospects of applying formation water and heavy brines derived therefrom in oil production and national economy. IOP Conference Series: Materials Science and Engineering, 905, 012081.
  15. Kadyrov, P. P., Zhirkeev, A. S., Sakhapov, A. K., et al. (2012). Instructions on the technology of repair of insulation works using cement-fiber materials. RD 153-39.0-777-12.
  16. Ghatrifi, S., Sulaimi, G., Chavez, M. J., Sivrikoz, A. (2018, November). Oil gain from successful water shut-off strategy. SPE-193245-MS. In: Abu Dhabi International Petroleum Exhibition and Conference. Society of Petroleum Engineers.
  17. Galiullina, I. F., Kadyrov, R. R. (2016). Produced-water-based products used in oil production, livestock sector and food industry. Oil Province, 3(7), 147-156.
  18. Chizhov, A. P., Andreev, V. E., Chibisov, A. V., et al. (2020). Hydraulically perfect modes of injection of grouting mixtures when isolating absorbing formations. IOP Conference Series: Materials Science and Engineering, 952, 012040.
  19. Kudryashova, L. V., Galiullina, I. F., Kadyrov, R. R., Idiyatullin, A. F. (2017). Methods of obtaining table salt from reservoir water. Collection of scientific works of TatNIPIneft. Naberezhnye Chelny: Oil and Gas Exposition, 85, 437-440.
  20. Muslimov, R. Kh., Kadyrov, R. R., Ovchinnikov, A. I., et al. (1998). A method for producing bromine from the reservoir water of an oil field. Patent RF 2107021.
  21. Muslimov, R. Kh., Yusupov, I. G., Kadyrov, R. R. (2005). Obtaining valuable chemical products from reservoir waters of the Republic of Tatarstan. Kazan: Pluto.
  22. 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.
  23. Grishchenko, V. A., Gareev, R. R., Tsiklis, I. M., et al. (2021). Expanding the amount of preferential royalty facilities with hard-to-recover oil reserves. SOCAR Proceedings, SI2, 8-18.
  24. Grishchenko, V. A., Rabaev, R. U., Asylgareev, I. N., et al. (2021). Methodological approach to optimal geological and technological characteristics determining when planning hydraulic fracturing at multilayer facilities. SOCAR Proceedings, SI2, 182-191.
  25. Grishchenko, V. A., Pozdnyakova, T. V., Mukhamadiyev, B. M., et al. (2021). Improving the carbonate reservoirs development efficiency on the example of the Tournaisian stage deposits. SOCAR Proceedings, SI2, 238-247.
  26. Shmal, G. I. (2017). Oil and gas complex in response to geopolitical and economic challenges: problems and solutions. Oil Industry, 5, 8-11.
  27. Dmitrievsky, A. N. (2017). Resource-innovative strategy for the development of the Russian economy. Oil Industry, 5, 6-7.
  28. 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.
  29. Grishchenko, V. A., Asylgareev, I. N., Bakhtizin, R. N., et al. (2021). Methodological approach to the resource base efficiency monitoring in oil fields development. SOCAR Proceedings, SI2, 229-237.
  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., Kadyrov, R. R. (2017). Influence of nanoadditives on mechanical and isolating properties of cement-based compositions. Nanotechnologies in Construction, 9(6), 18-36.
  32. Veliyev, E. F. (2021). Polymer dispersed system for in-situ fluid diversion. Prospecting and Development of Oil and Gas Fields, 1(78), 61-72.
  33. Zeigman, Yu. V., Mukhametshin, V. Sh., Khafizov, A. R., Kharina, S. B. (2016). Prospects of Application of Multi-Functional Well Killing Fluids in Carbonate Reservoirs. SOCAR Procеedings, 3, 33-39.
  34. 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.
  35. Zeigman, Yu. V., Mukhametshin, V. Sh., Khafizov, A. R., et al. (2017). Peculiarities of selecting well-killng fluids composition for difficult conditions. Oil Industry, 1, 66-69.
  36. Khisamov, R. S., Abdrakhmanov, G. S., Kadyrov, R. R., Mukhametshin, V. V. (2017). New technology of bottom water shut-off. Oil Industry, 11, 126-128.
  37. Polyakov, V. N., Chizhov, A. P., Kotenev, Yu. A., Mukhametshin, V. Sh. (2019). Results of system drilling techniques and completion of oil and gas wells. IOP Conference Series: Earth and Environmental Science, 378, 012119.
  38. GOST 13830-91. (1993). Food common salt. General specifications. Moscow: Standards Publishing.
  39. Sergeev, B. Z., Reznik, E. G., Gaidenko, I. F., Kovalev, N. I. (1994). Method for isolation of water encroached beds. Patent RF 2013521.
  40. Mukhametshin, V. V. (2018). Efficiency estimation of nanotechnologies applied in constructed wells to accelerate field development. Nanotechnologies in Construction, 10(1), 113-131.
  41. Okromelidze, G. V., Nekrasova, I. L., Garshina, O. V., et al. (2016). Well killing operation using viscoelastic gels. Oil Industry, 10, 56-61.
  42. Mukhametshin, V. Sh., Popov, A. M., Goncharov, A. M. (1991). The commercial rationale for the wells and impact parameters selection while hydrochloric acid treatments carrying out. Oil Industry, 6, 32-33.
  43. Kadyrov, R. R., Galiullina, I. F., Mukhametshin, V. V. (2018). Method for producing well-killing fluid and sodium chloride from reservoir water of an oil field. Patent RF 2661948.
Read more Read less

DOI: 10.5510/OGP20220400783

E-mail: vv@of.ugntu.ru


V. A. Grishchenko1, M. N. Kharisov2, R. U. Rabaev2, V. Sh. Mukhametshin1, K. T. Tyncherov1

1Institute of Oil and Gas, Ufa State Petroleum Technological University, (branch in the city of Oktyabrsky), Oktyabrsky, Russia; 2Ufa State Petroleum Technological University, Ufa, Russia

Solving the material balance equation in a context of uncertainty by the genetic optimization method


The article proves that the solution of the material balance equation in conditions of a limited amount of information about small oil deposits must be carried out using the genetic optimization method. The use of the proposed algorithm management decisions risks reducing the in drilling and oil production in conditions of insignificant oil reserves allows to reduce the cost of production, which makes it possible to increase the pace of hard-to-recover reserves bringing into development and the degree of their development.

Keywords: oil field development; oil reserves; well drilling; material balance method; genetic algorithm.

The article proves that the solution of the material balance equation in conditions of a limited amount of information about small oil deposits must be carried out using the genetic optimization method. The use of the proposed algorithm management decisions risks reducing the in drilling and oil production in conditions of insignificant oil reserves allows to reduce the cost of production, which makes it possible to increase the pace of hard-to-recover reserves bringing into development and the degree of their development.

Keywords: oil field development; oil reserves; well drilling; material balance method; genetic algorithm.

References

  1. Muslimov, R. Kh. (2009). Features of exploration and development of oil fields in a market economy. Kazan: FEN.
  2. 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.
  3. Kontorovich, A. E., Livshits, V. R., Burshtein, L. M., Kurchikov, A. R. (2021). Assessment of the initial, promising, and predicted geologic and recoverable oil resources of the West Siberian petroleum province and their structure. Russian Geology and Geophysics, 62(5), 576-588.
  4. 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.
  5. Grishchenko, V. A., Tsiklis, I. M., Mukhametshin, V. Sh., Yakupov, R. F. (2021). Methodological approaches to increasing the flooding system efficiency at the later stage of reservoir development. SOCAR Proceedings, SI2, 161-171.
  6. Mukhametshin, V. V., Bakhtizin, R. N., Kuleshova, L. S., et al. (2021). Screening and assessing the conditions for effective oil recovery enhancing techniques application for hard to recover high-water cut reserves. SOCAR Proceedings, SI2, 48-56.
  7. Kuleshova, L. S., Mukhametshin, V. Sh. (2022). Research and justification of innovative techniques employment for hydrocarbons production in difficult conditions. SOCAR Proceedings, SI1, 71-79.
  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. Mishchenko, I. T., Kondratyuk, A. T. (1996). Features of the development of oil fields with hard-to-recover reserves. Moscow: Nedra.
  10. Abyzbaev, I. I., Andreev, V. E. (2005). Prognosis of the physical and chemical method to increase flooding efficiency. Petroleum Engineering, 3, 167-176.
  11. 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.
  12. Veliyev, E. F. (2020). Review of modern in-situ fluid diversion technologies. SOCAR Proceedings, 2, 50-66.
  13. Khisamiev, T. R., Bashirov, I. R., Mukhametshin, V. Sh., et al. (2021). Results of the development system optimization and increasing the efficiency of carbonate reserves extraction of the Turney stage of the Chetyrmansky deposit. SOCAR Proceedings, SI2, 131-142.
  14. Fattakhov, I. G., Kuleshova, L. S., Bakhtizin, R. N., et al. (2021). Complexing the hydraulic fracturing simulation results when hybrid acid-propant treatment performing and with the simultaneous hydraulic fracture initiation in separated intervals. SOCAR Proceedings, SI2, 103-111.
  15. Grishchenko, V. A., Rabaev, R. U., Asylgareev, I. N., et al. (2021). Methodological approach to optimal geological and technological characteristics determining when planning hydraulic fracturing at multilayer facilities. SOCAR Proceedings, SI2, 182-191.
  16. Grishchenko, V. A., Gareev, R. R., Tsiklis, I. M., et al. (2021). Expanding the amount of preferential royalty facilities with hard-to-recover oil reserves. SOCAR Proceedings, SI2, 8-18.
  17. Ibragimov, N. G., Musabirov, M. Kh., Yartiev, A. F. (2014). Effectiveness of well stimulation technologies package developed by Tatneft OAO. Oil Industry, 7, 44-47.
  18. Mandrick, I. E., Panakhov, G. M., Shakhverdiev, A. Kh. (2010). Scientific-methodological and technological bases for optimizing the process of increasing oil recovery. Moscow: Oil Industry.
  19. Khasanov, M. M., Mukhamedshin, R. K., Khatmullin, I. F. (2001). Computer technologies for solving multi-criteria tasks of monitoring the development of oil fields. Bulletin of the YUKOS Engineering center, 2, 26-29.
  20. Milovidov, V. D. (2015). Proactive innovation management: knowledge mapping. Oil Industry, 8, 16-21.
  21. Mukhametshin, V. Sh. (2022). Oil recovery factor express evaluation during carbonate reservoirs development in natural regimes. SOCAR Proceedings, SI1, 27-37.
  22. Grishchenko, V. A., Pozdnyakova, T. V., Mukhamadiyev, B. M., et al. (2021). Improving the carbonate reservoirs development efficiency on the example of the Tournaisian stage deposits. SOCAR Proceedings, SI2, 238-247.
  23. Shakhverdiev, A. Kh. (2017). Some conceptual aspects of systematic optimization of oil field development. Oil Industry, 2, 58-63.
  24. Hodgin, J. E., Harrell, D. R. (2006, September). The selection, application, and misapplication of reservoir analogs for the estimation of petroleum reserves. In: SPE Annual Technical Conference and Exhibition. Society of Petroleum Engineers.
  25. Mukhametshin, V. Sh. Oil flooding in carbonate reservoirs management. SOCAR Proceedings, SI1, 38-44.
  26. 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.
  27. Kanevskaya, R. D. (1999). Mathematical modeling of oil and gas field development using hydraulic fracturing. Moscow: Nedra-Business Center.
  28. Alvarado, V., Manrik, E. (2011). Methods of increasing oil recovery. Planning and application strategies. Moscow: Premium Engineering.
  29. Alvarado, V., Thyne, G., Murrel, G. R. (2008, September). Screening strategy for chemical enhanced oil recovery in Wyoming Basin. SPE-115940-MS. In: SPE Annual Technical Conference and Exhibition. Society of Petroleum Engineers.
  30. Kudryashov, S. I., Belkina, E. Yu., Khasanov, M. M., et al. (2015). Quantitative approach of using of analogs in exploration and field development. Oil Industry, 4, 43-47.
  31. 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.
  32. Grishchenko, V. A., Asylgareev, I. N., Bakhtizin, R. N., et al. (2021). Methodological approach to the resource base efficiency monitoring in oil fields development. SOCAR Proceedings, SI2, 229-237.
  33. 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.
  34. 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.
  35. Milovidov, V. D. (2015). Management of innovations: how to effectively use the information. Oil Industry, 6, 10-16.
  36. Tokarev, M. A. (1990). Comprehensive geological and field control of the current oil recovery when oil is displaced by water. Moscow: Nedra.
  37. 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.
  38. Mukhametshin, V. V., Kuleshova, L. S. (2022). Improving the lower cretaceous deposits development efficiency in Western Siberia employing enhanced oil recovery. SOCAR Proceedings, SI1, 9-18.
  39. 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.
  40. Sun, S. Q., Wan, J. C. (2002). Geological analogs usage rates high in global survey. Oil & Gas Journal, 100(46), 49-50.
  41. Mukhametshin, V. Sh., Khakimzyanov, I. N. (2021). Features of grouping low-producing oil deposits in carbonate reservoirs for the rational use of resources within the Ural-Volga region. Journal of Mining Institute, 252, 896-907.
  42. Mukhametshin, V. V. (2021). Improving the efficiency of managing the development of the West Siberian oil and gas province fields on the basis of differentiation and grouping. Russian Geology and Geophysics, 62(12), 1373–1384.
  43. Ibatullin, R. R. (2011). Technological processes of oil field development. Moscow: JSC «VNIIOENG».
  44. Vasiliev, F. P. (2002). Optimization methods. Moscow: Factorial Press.
  45. Panchenko, T. V. (2007). Genetic algorithms. Astrakhan: Publishing House «Astrakhan University».
Read more Read less

DOI: 10.5510/OGP20220400784

E-mail: vsh@of.ugntu.ru


E. F. Veliyev1,2, S. V. Shirinov3, T. E. Mammedbeyli1

1«OilGasScientificResearchProject» Institute, SOCAR, Baku, Azerbaijan; 2Composite Materials Scientific Research Center, Azerbaijan Sate University of Economics (UNEC), Baku, Azerbaijan; 3Azerbaijan State University of Economics (UNEC), Baku, Azerbaijan

Intelligent oil and gas field based on artificial intelligence technology


Artificial Intelligence (AI) is a system that simulates the thinking process. AI involves a simple structural approach to the development of complex decision-making systems, allowing the user to set and solve problems of varying degrees of complexity. Today, AI technologies are increasingly being used in many areas of human activity, and the oil and gas industry is no exception. Application of AI in oil and gas industry is rapidly developing and gradually being introduced in various areas such as: smart drilling, smart pipeline, smart refinery, etc. Based on AI, it is possible to create an ecosystem in which coordination and cooperation of all levels, sectors and areas can be implemented to extend the life cycle of the oil field, improve efficiency and quality of decision-making, reduce costs and increase economic benefits.

Keywords: Artificial Intelligence; neural network; enhanced oil recovery; production forecast; support vector machines; genetic algorithm.

Artificial Intelligence (AI) is a system that simulates the thinking process. AI involves a simple structural approach to the development of complex decision-making systems, allowing the user to set and solve problems of varying degrees of complexity. Today, AI technologies are increasingly being used in many areas of human activity, and the oil and gas industry is no exception. Application of AI in oil and gas industry is rapidly developing and gradually being introduced in various areas such as: smart drilling, smart pipeline, smart refinery, etc. Based on AI, it is possible to create an ecosystem in which coordination and cooperation of all levels, sectors and areas can be implemented to extend the life cycle of the oil field, improve efficiency and quality of decision-making, reduce costs and increase economic benefits.

Keywords: Artificial Intelligence; neural network; enhanced oil recovery; production forecast; support vector machines; genetic algorithm.

References

  1. Gilman, H., Nordtvedt, J. E. (2014). Intelligent energy: the past, the present, and the future. SPE Economics & Management, 6(04), 185-190.
  2. Lee, J., Davari, H., Singh, J., Pandhare, V. (2018). Industrial artificial intelligence for industry 4.0-based manufacturing systems. Manufacturing Letters, 18, 20-23.
  3. Yusupov, S. (2022). Legalization of artificial intelligence: Significance and necessity. Miasto Przysz.o.ci, 26, 48-50.
  4. Watson, D. S., Gultchin, L., Taly, A., Floridi, L. (2021, December). Local explanations via necessity and sufficiency: Unifying theory and practice. In: 37th Conference on Uncertainty in Artificial Intelligence (UAI 2021).
  5. Samek, W., Wiegand, T., Muller, K. R. (2017). Explainable artificial intelligence: Understanding, visualizing and interpreting deep learning models. https://doi.org/10.48550/arXiv.1708.08296
  6. Kuang, L., He, L. I. U., Yili, R. E. N., et al. (2021). Application and development trend of artificial intelligence in petroleum exploration and development. Petroleum Exploration and Development, 48(1), 1-14.
  7. Rahmanifard, H., Plaksina, T. (2019). Application of artificial intelligence techniques in the petroleum industry: a review. Artificial Intelligence Review, 52(4), 2295-2318.
  8. Gharbi, R. B., Mansoori, G. A. (2005). An introduction to artificial intelligence applications in petroleum exploration and production. Journal of Petroleum Science and Engineering, 49(3-4), 93-96.
  9. Veliyev, E., Aliyev, A., Mammadbayli, T. (2021). Machine learning application to predict the efficiency of water coning prevention techniques implementation. SOCAR Proceedings, 1, 104-113.
  10. Bahaloo, S., Mehrizadeh, M., Najafi-Marghmaleki, A. (2022). Review of application of artificial intelligence techniques in petroleum operations. Petroleum Research. In press.
  11. Al-Bulushi, N. I., King, P. R., Blunt, M. J., Kraaijveld, M. (2012). Artificial neural networks workflow and its application in the petroleum industry. Neural Computing and Applications, 21(3), 409-421.
  12. Hojageldiyev, D. (2018, November). Artificial intelligence in HSE. SPE-192820-MS. In: Abu Dhabi International Petroleum Exhibition & Conference. Society of Petroleum Engineers.
  13. Mohaghegh, S., Arefi, R., Ameri, S., et al. (1996). Petroleum reservoir characterization with the aid of artificial neural networks. Journal of Petroleum Science and Engineering, 16(4), 263-274.
  14. Al-Shabandar, R., Jaddoa, A., Liatsis, P., Hussain, A. J. (2021). A deep gated recurrent neural network for petroleum production forecasting. Machine Learning with Applications, 3, 100013.
  15. Giuliani, M., Cadei, L., Montini, M., et al. (2020, January). Hybrid artificial intelligence techniques for automatic simulation models matching with field data and constrained production optimization. IPTC-19621-Abstract. In: International Petroleum Technology Conference. Society of Petroleum Engineers.
  16. Mohaghegh, S. D. (2011). Reservoir simulation and modeling based on artificial intelligence and data mining (AI&DM). Journal of Natural Gas Science and Engineering, 3(6), 697-705.
  17. Amini, S., Mohaghegh, S. (2019). Application of machine learning and artificial intelligence in proxy modeling for fluid flow in porous media. Fluids, 4(3), 126.
  18. He, Q., Zhong, Z., Alabboodi, M., Wang, G. (2019, October). Artificial intelligence assisted hydraulic fracturing design in shale gas reservoir. SPE-196608-MS. In: SPE Eastern Regional Meeting. Society of Petroleum Engineers.
  19. Keshavarzi, R., Jahanbakhshi, R. (2013, May). Investigation of hydraulic and natural fracture interaction: numerical modeling or artificial intelligence?. ISRM-ICHF-2013-025. In: ISRM International Conference for Effective and Sustainable Hydraulic Fracturing. Society of Petroleum Engineers.
  20. Mohammadpoor, M., Torabi, F. (2020). Big Data analytics in oil and gas industry: An emerging trend. Petroleum, 6(4), 321-328.
  21. Patel, H., Prajapati, D., Mahida, D., Shah, M. (2020). Transforming petroleum downstream sector through big data: a holistic review. Journal of Petroleum Exploration and Production Technology, 10(6), 2601-2611.
  22. Feblowitz, J. (2013, March). Analytics in oil and gas: The big deal about big data. SPE-163717-MS. In: SPE Digital Energy Conference. Society of Petroleum Engineers.
  23. Baaziz, A., Quoniam, L. (2013). How to use Big Data technologies to optimize operations in Upstream Petroleum Industry. International Journal of Innovation, 1(1), 19-25.
  24. Veliyev, E. F., Aliyev, A. A. (2022). Comparative analysis of the geopolymer and Portland cement application as plugging material under conditions of incomplete displacement of drilling mud from the annulus. SOCAR Proceedings, 1, 108-115.
  25. Veliyev, E. F., Aliyev, A. A. (2021). Innovative technologies as a priority factor of the oil and gas industry development. ANAS Transactions. Earth Sciences, 2, 81–93.
  26. Suleimanov, B. A.,Veliyev, E. F., Aliyev, A. A. (2021). Impact of nanoparticle structure on the effectiveness of pickering emulsions for eor applications. ANAS Transactions. Earth Sciences, 1, 82–92.
  27. Akhmetov, R. T., Kuleshova, L. S., Veliyev, E. F. O., et al. (2022). Substantiation of an analytical model of reservoir pore channels hydraulic tortuosity in Western Siberia based on capillary research data. Bulletin of the Tomsk Polytechnic University, Geo Assets Engineering, 333(7), pp. 86–95.
  28. Veliyev, E. F., Aliyev, A. A. (2022). The application of nanoparticles to stabilise colloidal disperse systems. ANAS Transactions. Earth Sciences, 1, 37–50.
  29. Suleimanov, B. A., Guseynova, N. I., Veliyev, E. F. (2017, October). Control of displacement front uniformity by fractal dimensions. SPE-187784-MS. In: SPE Russian Petroleum Technology Conference. Society of Petroleum Engineers.
  30. Suleimanov, B. A., Veliyev, E. F., Azizagha, A. A. (2020). Colloidal dispersion nanogels for in-situ fluid diversion. Journal of Petroleum Science and Engineering, 193, 107411.
  31. Veliyev, E. F. (2021). Prediction methods for coning process. Azerbaijan Oil Industry, 3, 18-25.
  32. Korovin, I. S., Tkachenko, M. G. (2016). Intelligent oilfield model. Procedia Computer Science, 101, 300-303.
  33. Markov, N. G., Vasilyeva, E. E., Evsyutkin, I. V. (2017). The intellectual information system for management of geological and technical arrangements during oil field exploitation. Journal of Physics: Conference Series, 803(1), 012093).
  34. Shahkarami, A., Mohaghegh, S. D., Gholami, V., Haghighat, S. A. (2014, April). Artificial intelligence (AI) assisted history matching. SPE-169507-MS. In: SPE western North American and Rocky Mountain Joint Meeting. Society of Petroleum Engineers.
  35. Taklimy, S. Z., Rasaei, M. R. (2015). An intelligent framework for history matching an oil field with a long production history. Energy Sources, Part A: Recovery, Utilization, and Environmental Effects, 37(17), 1904-1914.
  36. Sengel, A., Turkarslan, G. (2020, December). Assisted history matching of a highly heterogeneous carbonate reservoir using hydraulic flow units and artificial neural networks. SPE-200541-MS. In: SPE Europec. Society of Petroleum Engineers.
  37. Suwito, E., Sianturi, J. A. D., Irawan, A., et al. (2022, October). Novel machine learning and data analytics approach for history matching giant mature multilayered oil field. SPE-211398-MS. In: ADIPEC. Society of Petroleum Engineers.
  38. Suleimanov, B. A., Veliyev, E. F., Vishnyakov, V. (2022). Nanocolloids for petroleum engineering: Fundamentals and practices. John Wiley & Sons.
  39. Suleimanov, B. A., Rzayeva, S. J., Akberova, A. F., Akhmedova, U. T. (2022). Self-foamed biosystem for deep reservoir conformance control. Petroleum Science and Technology, 1-18.
  40. Veliyev, E. F., Aliyev, A. A. (2021, October). Propagation of nano sized CDG deep into porous media. SPE-207024-MS. In: SPE Annual Caspian Technical Conference. Society of Petroleum Engineers.
  41. Ismailov, R. G., Veliyev, E. F. (2021). Emulsifying composition for increase of oil recovery efficiency of high viscous oils. Azerbaijan Oil Industry, 5, 22-28.
  42. Veliyev, E. F. (2021). A combined method of enhanced oil recovery based on ASP technology. Prospecting and Development of Oil and Gas Fields, 4(81), 41-48.
  43. Suleimanov, B. A., Veliyev, E. F., Naghiyeva, N. V. (2021). Colloidal dispersion gels for in-depth permeability modification. Modern Physics Letters B, 35(01), 2150038.
  44. Veliyev, E. F. (2020). Mechanisms of polymer retention in porous media. SOCAR Proceedings, 3, 126-134.
  45. Suleimanov, B. A., Latifov, Y. A., Veliyev, E. F. (2019). Softened water application for enhanced oil recovery. SOCAR Proceedings, 1, 19-29.
  46. Suleimanov, B. A., Veliyev, E. F., Naghiyeva, N. V. (2020). Preformed particle gels for enhanced oil recovery. International Journal of Modern Physics B, 34(28), 2050260.
  47. Veliyev, E. F. (2021). Application of amphiphilic block-polymer system for emulsion flooding. SOCAR Proceedings, 3, 78-86.
  48. Suleimanov, B. A., Latifov, Y. A., Ibrahimov, K. M., Guseinova, N. I. (2017). Field testing results of enhanced oil recovery technologies using thermoactive polymer compositions. SOCAR Proceedings, (3), 17-31.
  49. Zhou, C. C., Li, J., Zhang, X. G. (2008). Predication for EOR by polymer flooding based on artificial neural network comparison between ANN and quadratic. Polynomial Stepwise Regres Method, 27(3), 113-116.
  50. Shi, S. Z., Yu, H. Y., Sun, Z. L. (2014). Forecast of fracturing effect based on gray correlation analysis and BP neural network. Journal of Changjiang University (Self Publ Ed), 31, 154-156.
  51. Costa, L. A. N., Maschio, C., Schiozer, D. J. (2014). Application of artificial neural networks in a history matching process. Journal of Petroleum Science and Engineering, 123, 30-45.
  52. Masini, S. R., Goswami, S., Kumar, A., Chennakrishnan, B., Baghele, A. (2020, November). Artificial intelligence assisted production forecasting and well surveillance. OTC-30332-MS. In: Offshore Technology Conference Asia. Society of Petroleum Engineers.
  53. Alarifi, S., AlNuaim, S., Abdulraheem, A. (2015, March). Productivity index prediction for oil horizontal wells using different artificial intelligence techniques. SPE-172729-MS. In: SPE Middle East Oil & Gas Show and Conference. Society of Petroleum Engineers.
  54. Denney, D. (2000). Artificial neural networks identify restimulation candidates. Journal of Petroleum Technology, 52(02), 44-45.
Read more Read less

DOI: 10.5510/OGP20220400785

E-mail: elchinf.veliyev@socar.az


Y. Sh. Seitkhaziyev

Atyrau branch of KMG Engineering, Atyrau city, Kazakhstan

Geochemical analysis of oil and core samples derived from oil and gas fields in the South-Mangyshlak basin


This paper presents the results of biomarker analysis of 183 oil samples derived from 19 oil and gas fields and Rock-Eval pyrolysis performed on 93 core samples from 12 fields in the South Mangyshlak basin. According to the biomarkers, oils of studied fields were formed from shaly OM and can be divided into 3 groups: the first group includes Oymasha, Ashiagar, Atambay-Sartobe, Alatyube, Karagie North and Akkar North, which have OM of marine origin, while the second group includes oils from the Pridorozhnoye, Airantakyr, Burmasha and Bekturly fields, which have OM of lacustrine origin. The third group includes oils from rest fields, within each of which there are at least two sources: the oils of the lower pay zones have shaly OM of marine origin, and the OM of the oils of the upper horizons was formed in the lacustrine environment. Rock-Eval pyrolysis revealed that some fields can be considered synclinal.

Keywords: chromatography; biomarkers; steranes; hopanes; Rock-Eval pyrolysis; South-Mangyshlak.

This paper presents the results of biomarker analysis of 183 oil samples derived from 19 oil and gas fields and Rock-Eval pyrolysis performed on 93 core samples from 12 fields in the South Mangyshlak basin. According to the biomarkers, oils of studied fields were formed from shaly OM and can be divided into 3 groups: the first group includes Oymasha, Ashiagar, Atambay-Sartobe, Alatyube, Karagie North and Akkar North, which have OM of marine origin, while the second group includes oils from the Pridorozhnoye, Airantakyr, Burmasha and Bekturly fields, which have OM of lacustrine origin. The third group includes oils from rest fields, within each of which there are at least two sources: the oils of the lower pay zones have shaly OM of marine origin, and the OM of the oils of the upper horizons was formed in the lacustrine environment. Rock-Eval pyrolysis revealed that some fields can be considered synclinal.

Keywords: chromatography; biomarkers; steranes; hopanes; Rock-Eval pyrolysis; South-Mangyshlak.

References

  1. Suleimanov, B. A., Veliyev, E. F., Vishnyakov, V. (2022). Nanocolloids for petroleum engineering: Fundamentals and practices. John Wiley & Sons.
  2. Veliyev, E. F., Aliyev, A. A. (2021). Innovative technologies as a priority factor of the oil and gas industry development. ANAS Transactions. Earth Sciences, 2, 81-93.
  3. Suleimanov, B. A., Veliyev, E. F., Naghiyeva, N. V. (2020). Preformed particle gels for enhanced oil recovery. International Journal of Modern Physics B, 34(28), 2050260.
  4. Suleimanov, B. A., Veliyev, E. F., Naghiyeva, N. V. (2021). Colloidal dispersion gels for in-depth permeability modification. Modern Physics Letters B, 35(01), 2150038.
  5. Veliyev, E. F. (2020). Mechanisms of polymer retention in porous media. SOCAR Proceedings, 3, 126-134.
  6. Suleimanov, B. A., Latifov, Y. A., Veliyev, E. F. (2019). Softened water application for enhanced oil recovery. SOCAR Proceedings, 1, 19-29.
  7. Veliyev, E. F. (2021). Application of amphiphilic block-polymer system for emulsion flooding. SOCAR Proceedings, 3, 78-86.
  8. Suleimanov, B. A. (1995). Filtration of disperse systems in a nonhomogeneous porous medium. Colloid Journal, 57(5), 704-707.
  9. Suleimanov, B. A. (1996). Experimental study of the formation of fractal structures in displacement of immiscible fluids using a Hele-Shaw cell. Journal of Engineering Physics and Thermophysics, 69(2), 182-187.
  10. Suleimanov, B. A. (1996). Effect of a surface-active substance on nonequilibrium phenomena in filtration of gas-liquid systems in the subcritical region. Journal of Engineering Physics and Thermophysics, 69(4), 427-431.
  11. Suleimanov, B. A. (1997). Slip effect during filtration of gassed liquid. Colloid Journal, 59(6), 749-753.
  12. Suleimanov, B. A. (1999). The slip effect during filtration of gassed non-Newtonian liquids. Colloid Journal, 61(6), 786-790.
  13. Suleimanov, B. A., Latifov, Y. A., Ibrahimov, K. M., Guseinova, N. I. (2017). Field testing results of enhanced oil recovery technologies using thermoactive polymer compositions. SOCAR Proceedings, 3, 17-31.
  14. Suleimanov, B. A., Guseynova, N. I., Veliyev, E. F. (2017, October). Control of displacement front uniformity by fractal dimensions. SPE-187784-MS. In: SPE Russian Petroleum Technology Conference. Society of Petroleum Engineers.
  15. Suleimanov, B. A., Veliyev, E. F., Aliyev, A. A. (2020). Colloidal dispersion nanogels for in-situ fluid diversion. Journal of Petroleum Science and Engineering, 193, 107411.
  16. Ismailov, R. G., Veliyev, E. F. (2021). Emulsifying composition for increase of oil recovery efficiency of high viscous oils. Azerbaijan Oil Industry, 5, 22-28.
  17. Suleimanov, B. A., Rzayeva, S. J., Akberova, A. F., Akhmedova, U. T. (2022). Self-foamed biosystem for deep reservoir conformance control. Petroleum Science and Technology, 40(20), 2450-2467.
  18. Suleimanov, B. A.,Veliyev, E. F., Aliyev, A.A. (2021). Impact of nanoparticle structure on the effectiveness of pickering emulsions for eor applications. ANAS Transactions. Earth Sciences, 1, pp. 82-92.
  19. Votsalevskiy, E. S., Shlygin, D. A. (2003). Neftegazovyye sistemy Yuzhnogo Mangistau i prilegayushchey akvotarial'noy chasti kazakhstanskogo Srednego Kaspiya. Izvestiya NAN RK. Seriya geologicheskaya, 3-14.
  20. Seitkhaziyev, Y. Sh. (2016). Otchet po geokhimicheskim issledovaniyam nefti i kerna mestorozhdeniy AO «Mangistaumunaygaz». TOO «Kaspiymunaygaz».
  21. Seitkhaziyev, Y. Sh., Sarsenbekov, N. D., Uteyev, R. N. (2022, November). Geochemical atlas of oils and source rocks and oil-source rock correlations: a case study of oil and gas fields in the Mangyshlak basin (Kazakhstan). SPE-212078-MS. In: SPE Annual Caspian Technical Conference. Society of Petroleum Engineers.
  22. Peters, K. C., Walters, C. C. (2005). Moldowan the biomarker guide. Volume 2. Biomarkers and isotopes in petroleum systems and earth history. Cambridge, New York, Melborne: Cambridge University Press.
  23. Peters, K. E., Fowler, M. G. (2002). Applications of petroleum geochemistry to exploration and reservoir management. review. Organic Geochemistry, 33, 5-36.
  24. Ganz, H., Hempton, M., van der Veen, F., Kreulen, R. (1999) Integrated reservoir geochemistry: finding oil by reconstructing migration pathways and paleo oil-water condition. SPE 56896. Society of Petroleum Engineers.
  25. Seitkhaziyev, Y. Sh, Uteyev, R. N, Sarsenbekov, N. D. Tassemenov, Y. R. (2020). Integrating biomarker analysis with carbon stable isotope signatures for genetic classification and tracing possible migration pathways of hydrocarbon of Pre-Caspian Basin. SPE-202514-MS. In: SPE Annual Caspian Technical Conference. Society of Petroleum Engineers.
  26. Seitkhaziyev, Y. Sh., Uteyev, R. N., Sarsenbekov, N. D. (2021, October). Application of biomarkers and oil fingerprinting for genetic classification of oil and prediction of petroleum migration pathways of Aryskum downfold of South-Torgay depression. SPE-207037-MS. In: SPE Annual Caspian Technical Conference. Society of Petroleum Engineers.
  27. Seitkhaziyev, Y. Sh. (2019). Genetic classification of oil samples of carbonate origin from fields of the southern part of the Caspian Basin. SOCAR Proceedings, 3, 40-60.
  28. Seitkhaziyev, Y. Sh. (2020). Comprehensive geochemical study of core and cutting samples from postsalt deposits of southern parts of precaspian basin and «oil-source rocks» correlation studies. SOCAR Proceedings, 2, 30-49.
  29. Seitkhaziyev, Y. Sh. (2021). Geochemical studies of gases from oil and gas fields in the southern part of the Caspian basin and their correlation with the results of oil geochemistry. SOCAR Proceedings, 4, 43-51.
Read more Read less

DOI: 10.5510/OGP20220400786

E-mail: y.seitkhaziyev@kmge.kz


V. Sh. Mukhametshin1, V. A. Shaidullin1, Sh. Kh. Sultanov2, L. S. Kuleshova1, R. F. Yakupov1, M. R. Yakupov3

1Institute of Oil and Gas, USPTU, (branch in the city of Oktyabrsky), Russia; 2Ufa State Petroleum Technological University, Ufa, Russia; 3Kazan (Volga Region) Federal University, Kazan, Russia

Assessment of the effect of silencing fluids on filtration and capacitance properties of productive deposits based on laboratory studies of core samples


Based on the results of physical modeling of the effect of the applied jamming fluids on the filtration-capacitance properties of rock samples in a water-saturated porous medium, it is shown that the recovery coefficient of the core sample of the development object after filtering the jamming fluid of some core samples was less than 90%. Based on analytical calculations by the method of J.E. Oddo and M.B. Thomson's analysis of the mixing processes used in the process of silencing waters on the compatibility and degree of salt deposition revealed that when mixing reservoir water and water of the silencing fluid under reservoir conditions at T = 30 °C and P = 7 MРa, the precipitation of non-organic salts of calcite CaCO3 with a sediment mass in the range of 0.39-0.77 g is predicted/l and CaSO4 anhydrite – 0.01-0.03 g/l. Experimental studies on the hydrodynamic modeling of the process of pumping silencing fluids based on potassium chloride and determining the degree of change in filtration characteristics have shown an increase in the coefficient of recovery of acceptance.

Keywords: silencing fluid; filtration experiment; modeling; permeability coefficient; calcite salt deposition; reservoir water compatibility.

Based on the results of physical modeling of the effect of the applied jamming fluids on the filtration-capacitance properties of rock samples in a water-saturated porous medium, it is shown that the recovery coefficient of the core sample of the development object after filtering the jamming fluid of some core samples was less than 90%. Based on analytical calculations by the method of J.E. Oddo and M.B. Thomson's analysis of the mixing processes used in the process of silencing waters on the compatibility and degree of salt deposition revealed that when mixing reservoir water and water of the silencing fluid under reservoir conditions at T = 30 °C and P = 7 MРa, the precipitation of non-organic salts of calcite CaCO3 with a sediment mass in the range of 0.39-0.77 g is predicted/l and CaSO4 anhydrite – 0.01-0.03 g/l. Experimental studies on the hydrodynamic modeling of the process of pumping silencing fluids based on potassium chloride and determining the degree of change in filtration characteristics have shown an increase in the coefficient of recovery of acceptance.

Keywords: silencing fluid; filtration experiment; modeling; permeability coefficient; calcite salt deposition; reservoir water compatibility.

References

  1. Muslimov, R. Kh. (2008). Methods of increasing an oil fields development efficiency at a late stage. Oil Industry, 3, 30-35.
  2. Dmitrievsky, A. N. (2017). Resource-innovative strategy for the development of the Russian economy. Oil Industry, 5, 6-7.
  3. Khisamiev, T. R., Bashirov, I. R., Mukhametshin, V. Sh., et al. (2021). Results of the development system optimization and increasing the efficiency of carbonate reserves extraction of the turney stage of the Chetyrmansky deposit. SOCAR Proceedings, SI2, 131-142.
  4. Shmal, G. I. (2017). Oil and gas complex in response to geopolitical and economic challenges: problems and solutions. Oil Industry, 5, 8-11.
  5. Grishchenko, V. A., Tsiklis, I. M., Mukhametshin, V. Sh., Yakupov, R. F. (2021). Methodological approaches to increasing the flooding system efficiency at the later stage of reservoir development. SOCAR Proceedings, SI2, 161-171.
  6. Dmitrievsky, A. N., Eremin, N. A. (2015). Modern scientific and technological revolution and a paradigm shift in the development of hydrocarbon resources. Problems of Economics Project: Digital Fields and Wells, 6, 10-16.
  7. Fattakhov, I. G., Kuleshova, L. S., Bakhtizin, R. N., et al. (2021). Complexing the hydraulic fracturing simulation results when hybrid acid-propant treatment performing and with the simultaneous hydraulic fracture initiation in separated intervals. SOCAR Proceedings, SI2, 103-111.
  8. Mingulov, I. Sh., Valeev, M. D., Mukhametshin, V. V., Kuleshova, L. S. (2021). Wells production viscosity measurement results application for pumping equipment operation diagnostics. SOCAR Proceedings, SI2, 152-160.
  9. Kleshchev, K. A. (2005). Prospects for the development of the raw material base of oil and gas production in Russia. Actual problems of oil and gas geology: anniversary collection of scientific papers of the Geological Faculty of the Gubkin Russian State University. Moscow: Oil and Gas, 29-57.
  10. Gavrilov, A. E., Zhukovskaya, E. A., Tugarova, M. A., Ostapchuk, M. A. (2015). Objective bazhenov rocks classification (the case of the Western Siberia central part fields). Oil Industry, 12, 38-40.
  11. Mukhametshin, V. Sh. (2022). Oil flooding in carbonate reservoirs management. SOCAR Proceedings, SI1, 38-44.
  12. Yaskin, S. A., Mukhametshin, V. V., Kuleshova, L. S. (2021). Geological and technological justification of the bottomhole zone treatment of wells and formations of the Langepas group of fields. IOP Conference Series: Materials Science and Engineering, 1064, 012073, 1-5.
  13. Butorin, A. V., Zinnurova, R. R., Mityaev, M. U., et al. (2015). Estimating the potential of the Tumen formation in the Noyabrsk region of Western Siberia. Oil Indutry, 12, 41-43.
  14. Shpurov, I. V., Zakharenko, V. A., Fursov, A. Ya. (2015). A differentiated analysis of the degree of involvement and the depletion of stocks of jurassic deposits in the Western Siberian oil-and-gas province. Subsoil Using – XXI Century, 1(51), 12-19.
  15. Mukhametshin, V. Sh. (2022). Oil recovery factor express evaluation during carbonate reservoirs development in natural regimes. SOCAR Proceedings, SI1, 27-37.
  16. Mukhametshin, V. V., Kuleshova, L. S. (2022). Improving the lower cretaceous deposits development efficiency in Western Siberia employing enhanced oil recovery. SOCAR Proceedings, SI1, 9-18.
  17. 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.
  18. Veliyev, E. F. (2020). Review of modern in-situ fluid diversion technologies. SOCAR Proceedings, 2, 50-66.
  19. Mukhametshin, V. V., Bakhtizin, R. N., Kuleshova, L. S., et al. (2021). Screening and assessing the conditions for effective oil recovery enhancing techniques application for hard to recover high-water cut reserves. SOCAR Proceedings, SI2, 48-56.
  20. Grishchenko, V. A., Rabaev, R. U., Asylgareev, I. N., et al. (2021). Methodological approach to optimal geological and technological characteristics determining when planning hydraulic fracturing at multilayer facilities. SOCAR Proceedings, SI2, 182-191.
  21. Veliyev, E. F. (2021). Application of amphiphilic block-polymer system for emulsion flooding. SOCAR Proceedings, 3, 78-86.
  22. Veliyev, E. F. (2021). Polymer dispersed system for in-situ fluid diversion. Prospecting and Development of Oil and Gas Fields, 1(78), 61–72.
  23. Grishchenko, V. A., Pozdnyakova, T. V., Mukhamadiyev, B. M., et al. (2021). Improving the carbonate reservoirs development efficiency on the example of the tournaisian stage deposits. SOCAR Proceedings, SI2, 238-247.
  24. Kuleshova, L. S., Mukhametshin, V. Sh. (2022). Research and justification of innovative techniques employment for hydrocarbons production in difficult conditions. SOCAR Proceedings, SI1, 71-79.
  25. 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.
  26. 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.
  27. Grishchenko, V. A., Asylgareev, I. N., Bakhtizin, R. N., et al. (2021). Methodological approach to the resource base efficiency monitoring in oil fields development. SOCAR Proceedings, SI2, 229-237.
  28. Mukhametshin, V. Sh., Khakimzyanov, I. N. (2021). Features of grouping low-producing oil deposits in carbonate reservoirs for the rational use of resources within the Ural-Volga region. Journal of Mining Institute, 252, 896-907.
  29. 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.
  30. 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.
  31. Mukhametshin, V. G., Dubinskiy, G. S., Andreev, V. E., et al. (2021). Geological, technological and technical justification for choosing a design solution for drilling wells under different geological conditions. IOP Conference Series: Materials Science and Engineering, 1064, 012061, 1-9.
  32. 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.
  33. Mukhametshin, V. V. (2021). Improving the efficiency of managing the development of the West Siberian oil and gas province fields on the basis of differentiation and grouping. Russian Geology and Geophysics, 62(12), 1373–1384.
  34. Economides, J. M., Nolte, K. I. (2000). Reservoir stimulation. West Sussex, England: John Wiley and Sons.
  35. 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.
  36. 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.
  37. Khasanov, M. M., Kostrigin, I. V., Khatmullin, I. F., Khatmullina, E. I. (2009). The accounting of data on carrying out of operating repairs in wells for an estimation of a energy state of a layer. Oil Industry, 9, 52-55.
  38. Kunakova, A. M., Gumerov, R. R., Sukovatyj, V. A., et al. (2014). Development of process liquid selection method for Orenburg oil and gas field conditions during killing wells process. Oil Industry, 7, 102-103.
  39. 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.
  40. 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.
  41. 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.
  42. Mardashov, D. V., Rogachev, M. K. (2014). Development of blocking hydrophobic-emulsion composition at well killing before well servicing. Life Science Journal, 11(6s), 283-285.
  43. Mukhametshin, V. V., Kuleshova, L. S. (2021). Using the method of canonical discriminant functions for a qualitative assessment of the response degree of producing wells to water injection during the development of carbonate deposits. IOP Conference Series: Materials Science and Engineering, 1064, 012069.
  44. 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.
  45. Rzayeva, S. J. (2019). New microbiological method of oil recovery increase containing highly mineralized water. SOCAR Procеedings, 2, 38-44.
  46. Kashchavtsev, V. E., Mishchenko, I. T. (2004). Salt formation during oil production. Moscow: Orbita.
  47. Zeigman, Yu. V., Mukhametshin, V. Sh., Khafizov, A. R., et al. (2017). Peculiarities of selecting well-killng fluids composition for difficult conditions. Oil Industry, 1, 66-69.
  48. Vahrushev, S. A., Gamolin, O. E., Belenkova, N. G., et al. (2018). Special aspects of selection of high-pressure wellkilling technology at oilfields of Bashneft-Dobycha LLC. Oil Industry, 9, 111-115.
  49. Yakupov, R. F., Veliyev, E. F., Mukhametshin, V. Sh., et al. (2021). Rationale for different types of agent using to improve development efficiency. Petroleum Engineering, 19(6), 81-91.
Read more Read less

DOI: 10.5510/OGP20220400787

E-mail: vsh@of.ugntu.ru


R. F. Yakupov1, R. U. Rabaev2, V. V. Mukhametshin2, L. S. Kuleshova3, V. E. Trofimov4, T. V. Pozdnyakova4, S. V. Popova4

1«Bashneft-Dobycha» LLC, Ufa, Russia; 2Ufa State Petroleum Technological University, Ufa, Russia; 3Institute of Oil and Gas, USPTU (branch in the city of Oktyabrsky), Russia; 4«RN-BashNIPIneft» LLC, Ufa, Russia

Analysis of the implemented development system effectiveness, horizontal wells drilling and well interventions in the conditions of carbonate deposits of the Tournaisian tier of the Znamenskoye oil field


The paper analyzes the implemented system for the oil deposits of the Tournaisian tier of the Znamenskoye field development, as well as factors reducing its effectiveness, assessment of the features of the geological structure affecting oil production, and the development of proposals to improve the development system efficiency. It is noted that during the development of the field, the geological structure of the Tournaisian tier oil deposits has significantly changed because of the additional study of the development facility, the high efficiency of the use of horizontal wells has been confirmed. It shows an increase in the initial well flow rate and the specific accumulated oil production per meter of oil-saturated reservoir thickness, a decrease in the initial water content of well production, the growth rate of water content, a decrease in the accumulated oil-water factor for the first year of well operation, depending on the increase in the capacity of the bridge between the oil and water-saturated layers.

Keywords: oil reserves production; bridge; oil recovery factor; oil-water factor; well.

The paper analyzes the implemented system for the oil deposits of the Tournaisian tier of the Znamenskoye field development, as well as factors reducing its effectiveness, assessment of the features of the geological structure affecting oil production, and the development of proposals to improve the development system efficiency. It is noted that during the development of the field, the geological structure of the Tournaisian tier oil deposits has significantly changed because of the additional study of the development facility, the high efficiency of the use of horizontal wells has been confirmed. It shows an increase in the initial well flow rate and the specific accumulated oil production per meter of oil-saturated reservoir thickness, a decrease in the initial water content of well production, the growth rate of water content, a decrease in the accumulated oil-water factor for the first year of well operation, depending on the increase in the capacity of the bridge between the oil and water-saturated layers.

Keywords: oil reserves production; bridge; oil recovery factor; oil-water factor; well.

References

  1. Dmitrievsky, A. N. (2017). Resource-innovative strategy for the development of the Russian economy. Oil Industry, 5, 6-7.
  2. Shakhverdiev, A. Kh. (2017). Some conceptual aspects of systematic optimization of oil field development. Oil Industry, 2, 58-63.
  3. Dmitrievsky, A. N., Eremin, N. A., Stolyarov, V. E. (2021). Current issues and indicators of digital transformation of oil and gas production at the final stage of field operation. SOCAR Proceedings, SI2, 1-13.
  4. 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.
  5. Grishchenko, V. A., Gareev, R. R., Tsiklis, I. M., et al. (2021). Expanding the amount of preferential royalty facilities with hard-to-recover oil reserves. SOCAR Proceedings, SI2, 8-18.
  6. Kuleshova, L. S., Mukhametshin, V. Sh. (2022). Research and justification of innovative techniques employment for hydrocarbons production in difficult conditions. SOCAR Proceedings, SI1, 71-79.
  7. Grishchenko, V. A., Tsiklis, I. M., Mukhametshin, V. Sh., Yakupov, R. F. (2021). Methodological approaches to increasing the flooding system efficiency at the later stage of reservoir development. SOCAR Proceedings, SI2, 161-171.
  8. Kadyrov, R. R., Mukhametshin, V. V., Galiullina, I. F., et al. (2020). Prospects of applying formation water and heavy brines derived therefrom in oil production and national economy. IOP Conference Series: Materials Science and Engineering, 905, 012081.
  9. Ibragimov, N. G., Musabirov, M. Kh., Yartiev, A. F. (2015). Tatneft''s experience in commercialization of import-substituting well stimulation technologies. Oil Industry, 8, 86-89.
  10. 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.
  11. Mukhametshin, V. Sh., Khakimzyanov, I. N. (2021). Features of grouping low-producing oil deposits in carbonate reservoirs for the rational use of resources within the Ural-Volga region. Journal of Mining Institute, 252, 896-907.
  12. Dubinskiy, G. S., Andreev, V. E., Kuleshova, L. S., Mukhametshin, V. V. (2020). Intensification of the gas inflow when bringing wells into production. IOP Conference Series: Materials Science and Engineering, 952, 012042.
  13. Pavlovskaia, E., Poplygin, V. V., Ivanov, D. Yu., Eliseyev, I. Yu. (2015). Effectiveness of acidizing in bashkir deposits of Perm region. Oil Industry, 3, 28-30.
  14. Khisamiev, T. R., Bashirov, I. R., Mukhametshin, V. Sh., et al. (2021). Results of the development system optimization and increasing the efficiency of carbonate reserves extraction of the turney stage of the Chetyrmansky deposit. SOCAR Proceedings, SI2, 131-142.
  15. Muslimov, R. Kh. (2008). Methods of increasing an oil fields development efficiency at a late stage. Oil Industry, 3, 30-35.
  16. Mukhametshin, V. V., Kuleshova, L. S. (2022). Improving the lower cretaceous deposits development efficiency in Western Siberia employing enhanced oil recovery. SOCAR Proceedings, SI1, 9-18.
  17. 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.
  18. 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.
  19. Dmitrievsky, A. N., Eremin, N. A. (2015). Modern scientific and technological revolution and a paradigm shift in the development of hydrocarbon resources. Problems of Economics Project: Digital Fields and Wells, 6, 10-16.
  20. Mukhametshin, V. V., Bakhtizin, R. N., Kuleshova, L. S., et al. (2021). Screening and assessing the conditions for effective oil recovery enhancing techniques application for hard to recover high-water cut reserves. SOCAR Proceedings, SI2, 48-56.
  21. Arzhilovsky, A. V., Guseva, D. N. (2016). Comparison of the methods applied to analyze the residual resources recovery. Oilfield Engineering, 10, 14-19.
  22. Grishchenko, V. A., Rabaev, R. U., Asylgareev, I. N., et al. (2021). Methodological approach to optimal geological and technological characteristics determining when planning hydraulic fracturing at multilayer facilities. SOCAR Proceedings, SI2, 182-191.
  23. Huseynov, A. G., Huseynov, E. A. (2021). The expansion of innovative activity on rise of oil production enterprises in Azerbaijan. SOCAR Proceedings, SI2, 1-7.
  24. Chizhov, A. P., Andreev, V. E., Chibisov, A. V., et al. (2020). Hydraulically perfect modes of injection of grouting mixtures when isolating absorbing formations. IOP Conference Series: Materials Science and Engineering, 952, 012040.
  25. Veliyev, E. F. (2021). Application of amphiphilic block-polymer system for emulsion flooding. SOCAR Proceedings, 3, 78-86.
  26. 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.
  27. Gasimov, A. A., Hajiyev, G. B. (2021). On management evaluation of oil-gas industry enteprises in modern economic condition. SOCAR Procеedings, 3, 100-105.
  28. Akmetshina, D. I., Batalov, D. A., Mukhametshin, V. V., Kuleshova, L. S. (2021). Scientific and methodological basic principles for determining design of clay acid treatments applied to wells. IOP Conference Series: Materials Science and Engineering, 1064, 012056.
  29. 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.
  30. Mukhametshin, V. V. (2021). Improving the efficiency of managing the development of the West Siberian oil and gas province fields on the basis of differentiation and grouping. Russian Geology and Geophysics, 62(12), 1373–1384.
  31. Mukhametshin, V. G., Dubinskiy, G. S., Andreev, V. E., et al. (2021). Geological, technological and technical justification for choosing a design solution for drilling wells under different geological conditions. IOP Conference Series: Materials Science and Engineering, 1064, 012061.
  32. 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.
  33. Yaskin, S. A., Mukhametshin, V. V., Kuleshova, L. S. (2021). Geological and technological justification of the bottom-hole zone treatment of wells and formations of the Langepas group of fields. IOP Conference Series: Materials Science and Engineering, 1064, 012073.
  34. Sun, S. Q., Wan, J. C. (2002). Geological analogs usage rates high in global survey. Oil & Gas Journal, 100(46), 49-50.
  35. Chervyakova, A. N., Zubik, A. O., Dushin, A. S., et al. (2017). Methodological approaches, experience and prospects of tournaisian stage oil deposits development by horizontal wells at Znamenskoye oil field. Oil Industry, 10, 33-35.
  36. Yakupov, R. F., Mukhametshin, V. Sh. (2013). Problem of efficiency of low-productivity carbonate reservoir development on example of Turnaisian stage of Tuymazinskoye field. Oil Industry, 12, 106–110.
  37. Mukhametshin, V. Sh. (2022). Oil flooding in carbonate reservoirs management. SOCAR Proceedings, SI1, 38-44.
  38. Zeigman, Yu. V., Mukhametshin, V. V., Kuleshova, L. S. (2020). Differential impact on wellbore zone based on hydrochloric-acid simulation. IOP Conference Series: Materials Science and Engineering, 952, 012069.
  39. Mukhametshin, V. Sh. (2022). Oil recovery factor express evaluation during carbonate reservoirs development in natural regimes. SOCAR Proceedings, SI1, 27-37.
  40. Kudayarova, A. R., Rykus, M. V., Kondrateva, N. R., et al. (2015). Methods of geological and hydrodynamic modeling tournaisian carbonate deposits of Znamenskoye field (the Republic of Bashkortostan). Oil Industry, 1, 18–20.
  41. Kudayarova, A. R., Rykus, M. V., Dushin, A. S. (2016). Sedimentation models and petrophysical properties of upper tournaisian carbonate deposits of the South-Tatar arch of platform Bashkiria. Petroleum Engineering, 14(1), 20–29.
  42. Merzlyakov, V. F., Volochkov, N. S., Popov, A. M. (2003). Development of oil accumulations in carbonate reservoirs of the Znamensky oilfield. Oil Industry, 3, 51-53.
  43. Amineva, G. R., Dvorkin, A. V., Burikova, T. V., et al. (2018). Microporous rocks features and identification on the base of core and well logging data. Oil Industry, 6, 58-61.
Read more Read less

DOI: 10.5510/OGP20220400788

E-mail: vv@of.ugntu.ru


E. R. Agishev1, G. S. Dubinsky2, V. V. Mukhametshin2, R. N. Bakhtizin2, V. E. Andreev2,3, L. S. Kuleshova4, T. R. Vafin4

1JV «Vietsovpetro», Vung Tau, Vietnam; 2USPTU, Ufa, Russia; 3Institute of Strategic Research of the Republic of Bashkortostan , Ufa, Russia; 4Institute of Oil and Gas, USPTU (branch in the city of Oktyabrsky), Russia

Prediction of hydraulic fracturing fracture parameters based on the study of reservoir rock geomechanics


The article is devoted to the search for ways to reduce the risks of water inflow during hydraulic fracturing and its more reliable design in order to increase technological efficiency. The methodology and approach to forecasting the parameters of hydraulic fracturing fractures based on the study of geomechanics of reservoir rocks are presented. Analytical, laboratory and field studies were carried out. The design adjustment was tested when planning hydraulic fracturing, the possibility of using such an algorithm of actions and its success were shown. Recommendations are given on the correct design of hydraulic fracturing and improving the quality of work, which reduces the risk of flooding of the productive reservoir.

Keywords: hydraulic fracturing; geomechanical properties of the formation; increase in production; reduction of waterflooding.

The article is devoted to the search for ways to reduce the risks of water inflow during hydraulic fracturing and its more reliable design in order to increase technological efficiency. The methodology and approach to forecasting the parameters of hydraulic fracturing fractures based on the study of geomechanics of reservoir rocks are presented. Analytical, laboratory and field studies were carried out. The design adjustment was tested when planning hydraulic fracturing, the possibility of using such an algorithm of actions and its success were shown. Recommendations are given on the correct design of hydraulic fracturing and improving the quality of work, which reduces the risk of flooding of the productive reservoir.

Keywords: hydraulic fracturing; geomechanical properties of the formation; increase in production; reduction of waterflooding.

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. (2014). Oil recovery: past, present, future (production optimization, maximization of oil recovery). Kazan: FEN.
  3. 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.
  4. 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.
  5. Kontorovich, A. E., Livshits, V.R. (2017). Oil resources of small and minute deposits of the Volga-Ural NGP, as a basis for the development of small and medium-sized oil production business. Materials of the All-Russian Scientific Conference dedicated to the 30th anniversary of the IPNG RAS «The fundamental basis of innovative technologies of the oil and gas industry». Moscow: LLC «Analyst».
  6. 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..
  7. 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.
  8. Veliyev, E. F. (2021). Polymer dispersed system for in-situ fluid diversion. Prospecting and Development of Oil and Gas Fields, 1(78), 61–72.
  9. Rozman, M. S., Smolyak, S. A., Zakirov, E. S., et al. (2020). About the feasibility study of TrIZ mining: how not to step on the old rake. Neftegaz.RU, 2(98), 62–70.
  10. Vygon, G. V. (2019). Inventory of stocks: from state expertise to national audit. Oil and Gas Vertical, 18(462), 19-24.
  11. Mukhametshin, V. V., Bakhtizin, R. N., Kuleshova, L. S., et al. (2021). Screening and assessing the conditions for effective oil recovery enhancing techniques application for hard to recover high-water cut reserves. SOCAR Proceedings, SI2, 48-56.
  12. Zakirov, S. N., Indrupskii, I. M., Smoliak, S. A., et al. (2015). To the problem of economic assessment of recoverable hydrocarbon volumes. Subsoil Using - XXI century, 4(54), 112-121.
  13. Mukhametshin, V. V. (2020). Oil production facilities management improving using the analogy method. SOCAR Proceedings, 4, 42-50.
  14. Orlov, S. (2020). New oil. Siberian Oil, 175, 8-13.
  15. 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.
  16. Alekseev, A. (2020). New oil. Siberian Oil, 175, 20-27.
  17. 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.
  18. Mukhametshin, V. V. (2021). Improving the efficiency of managing the development of the West Siberian oil and gas province fields on the basis of differentiation and grouping. Russian Geology and Geophysics, 62(12), 1373–1384.
  19. Veliyev, E. F. (2020). Review of modern in-situ fluid diversion technologies. SOCAR Proceedings, 2, 50-66.
  20. 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.
  21. Tikhonov, S. (2019).TRiZ and taxes. Incentives and obstacles to the development of hard-to-recover reserves. Oil and Gas Vertical, 6, 10-17.
  22. Grishchenko, V. A., Gareev, R. R., Tsiklis, I. M., et al. (2021). Expanding the amount of preferential royalty facilities with hard-to-recover oil reserves. SOCAR Proceedings, SI2, 8-18.
  23. Grishchenko, V. A., Asylgareev, I. N., Bakhtizin, R. N., et al. (2021). Methodological approach to the resource base efficiency monitoring in oil fields development. SOCAR Proceedings, SI2, 229-237.
  24. 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.
  25. 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.
  26. Khisamiev, T. R., Bashirov, I. R., Mukhametshin, V. Sh., et al. (2021). Results of the development system optimization and increasing the efficiency of carbonate reserves extraction of the Turney stage of the Chetyrmansky deposit. SOCAR Proceedings, SI2, 131-142.
  27. Grishchenko, V. A., Tsiklis, I. M., Mukhametshin, V. Sh., Yakupov, R. F. (2021). Methodological approaches to increasing the flooding system efficiency at the later stage of reservoir development. SOCAR Proceedings, SI2, 161-171.
  28. Veliyev, E. F. (2020). Mechanisms of polymer retention in porous media. SOCAR Procеedings, 3, 126-134.
  29. Grishchenko, V. A., Pozdnyakova, T. V., Mukhamadiyev, B. M., et al. (2021). Improving the carbonate reservoirs development efficiency on the example of the Tournaisian stage deposits. SOCAR Proceedings, SI2, 238-247.
  30. 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.
  31. 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.
  32. 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.
  33. Rzayeva, S. J. (2019). New microbiological method of oil recovery increase containing highly mineralized water. SOCAR Procеedings, 2, 38-44.
  34. Stabinskas, A. P., Sultanov, Sh. Kh., Mukhametshin, V. Sh., et al. (2021). Evolution of hydraulic fracturing fluid: from guar systems to synthetic gelling polymers. SOCAR Proceedings, SI2, 172-181.
  35. 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.
  36. 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.
  37. 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.
  38. Fattakhov, I. G., Kuleshova, L. S., Bakhtizin, R. N., et al. (2021). Complexing the hydraulic fracturing simulation results when hybrid acid-propant treatment performing and with the simultaneous hydraulic fracture initiation in separated intervals. SOCAR Proceedings, SI2, 103-111.
  39. Grishchenko, V. A., Rabaev, R. U., Asylgareev, I. N., et al. (2021). Methodological approach to optimal geological and technological characteristics determining when planning hydraulic fracturing at multilayer facilities. SOCAR Proceedings, SI2, 182-191.
  40. 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.
  41. Fadeev, A. B. (1982). Strength and deformability of rocks. Moscow: Nedra.
  42. GOST 12248-2010. (2011). Soils. Methods of laboratory determination of strength and deformability characteristics. Moscow: Standartinform.
  43. Egorov, A. A. (2021). Domestic flagship product «Rosneft» - «RN-GRID» simulator simulation of hydraulic facing (HF). Automation and IT in the Oil and Gas Industry, 2(44), 12–27.
  44. Magadova, L. A., Silin, M. A., Malkin, D. N., et al. (2014). Fracturing technologies diminishing the risks of well watering. Сoiled Tubing Times, 3(049), 38–46.
  45. Konoplev, Yu. V. (2006). Geophysical methods of control over the development of oil and gas fields. Krasnodar: Kuban State University.
Read more Read less

DOI: 10.5510/OGP20220400789

E-mail: vsh@of.ugntu.ru


E. Kh. Iskenderov, A. N. Bagirov, Sh. A. Bagirov, P. Sh. Ismayilova

Azerbaijan State Oil and Industry University, Baku, Azerbaijan

Development of new technological processes based on supersonic flow of natural gas


The article is devoted to the study of supersonic movement of natural gas in a pipeline and the possibility of developing new technological processes for cooling, drying and separating liquid hydrocarbons. Technological processes and a set of equipment created using the supersonic movement of natural gas are studied, their advantages and disadvantages are analyzed. It is known that a change in the process of gas injection into UGS facilities in a wide range of pressure during the season creates opportunities for more efficient use of compressor equipment. The thermobaric parameters of gas cooling due to supersonic motion in various designs have been calculated, and the existence of ample opportunities for creating new technological processes has been proved. Recommendations have been developed on the throughput capacity of gas installations to ensure the regulation of cooling systems created for underground gas storage facilities. It was noted that the cooling and gas separation systems created on the basis of thermobaric parameters and principles of regulation will be useful not only for underground gas storages, but also for other sub-sectors of the gas industry.

Keywords: natural gas; supersonic movement; laval nozzle; underground gas storage; gas cooling; separation; compressor.

The article is devoted to the study of supersonic movement of natural gas in a pipeline and the possibility of developing new technological processes for cooling, drying and separating liquid hydrocarbons. Technological processes and a set of equipment created using the supersonic movement of natural gas are studied, their advantages and disadvantages are analyzed. It is known that a change in the process of gas injection into UGS facilities in a wide range of pressure during the season creates opportunities for more efficient use of compressor equipment. The thermobaric parameters of gas cooling due to supersonic motion in various designs have been calculated, and the existence of ample opportunities for creating new technological processes has been proved. Recommendations have been developed on the throughput capacity of gas installations to ensure the regulation of cooling systems created for underground gas storage facilities. It was noted that the cooling and gas separation systems created on the basis of thermobaric parameters and principles of regulation will be useful not only for underground gas storages, but also for other sub-sectors of the gas industry.

Keywords: natural gas; supersonic movement; laval nozzle; underground gas storage; gas cooling; separation; compressor.

References

  1. Suleimanov, B. A. (1995). Filtration of disperse systems in a nonhomogeneous porous medium. Colloid Journal, 57(5), 704-707.
  2. Suleimanov, B. A. (1996). Experimental study of the formation of fractal structures in displacement of immiscible fluids using a Hele-Shaw cell. Journal of Engineering Physics and Thermophysics, 69(2), 182-187.
  3. Suleimanov, B. A. (1996). Effect of a surface-active substance on nonequilibrium phenomena in filtration of gas-liquid systems in the subcritical region. Journal of Engineering Physics and Thermophysics, 69(4), 427-431.
  4. Suleimanov, B. A. (1997). Slip effect during filtration of gassed liquid. Colloid Journal, 59(6), 749-753.
  5. Suleimanov, B. A. (1999). The slip effect during filtration of gassed non-Newtonian liquids. Colloid Journal, 61(6), 786-790.
  6. Suleimanov, B. A. (2004). On the effect of interaction between dispersed phase particles on the rheology of fractally heterogeneous disperse systems. Colloid Journal, 66(2), 249-252.
  7. Suleimanov, B. A. (2011). Mechanism of slip effect in gassed liquid flow. Colloid Journal, 73(6), 846-855.
  8. Bagirov, L. A., Imaev, S. Z. (2015, October). Experience of 3S-technology application for natural gas processing at gas facilities in Russia and China. SPE-176649-MS. In: SPE Russian Petroleum Technology Conference. Society of Petroleum Engineers.
  9. Alfyorov, V., Bagirov, L., Dmitriyev, L., et al. (2005). Supersonic nozzle efficiently sepsrstes natural gas components. Oil & Gas Journal, 23 May, 53-58.
  10. Imaev, S. Z., Safyannikov, M. I. (2016). Regulation of supersonic separators. Oil and Gas Territory, 9, 98-104.
Read more Read less

DOI: 10.5510/OGP20220400790

E-mail: pervaneismayilova0715@gmail.com


K. A. Bashmur1, V. S. Tynchenko1,2,3, R. B. Sergienko4, V. V. Kukartsev1,3, S. O. Kurashkin1,2,3, V.V. Tynchenko3,1

1Siberian Federal University, Krasnoyarsk, Russia; 2Bauman Moscow State Technical University, Russia; 3Reshetnev Siberian State University of Science and Technology, Krasnoyarsk, Russia; 4Gini Gmbh, Munich, Germany

Technologies assuring the service properties of friction pairs with cellular microrelief surfaces


Article focuses on the improvement of the technologies used to improve the durability of friction pair components. The authors use the piston compressor to study cellular microrelief surfaces of cylindrical components. The cells are shaped as elliptic paraboloid with uneven positive parameters. The use of cellular microrelief surfaces is highly preferred as they reduce the attrition wear of the friction pairs through assuring the hydrodynamic load capacity of the lubrication layer with the shape of the microrelief. The research goals included the parametric analysis of the lubrication layer behavior in the gap between the microrelief cells. To do this, the authors developed an analytical model based on the theory of hydrodynamic lubrication and constructed a CFD model using the ANSYS Fluent software. To contain the transfer equations, the authors used the turbulence model SST k–ω. Both models showed that the maximum hydrodynamic load capacity coincided with the 75%-length of the major axis of the elliptic cell, which also corresponds to 0.128 mm in cell depth. The maximum lifting hydrodynamic pressure on one microrelief cell amounted to 3 kPa. Based on the results of the parametric analysis, the authors claim that the cellular microrelief can be efficiently used to assure the service properties of friction pairs in process units.

Keywords: friction pair; cylinder sleeve; piston ring; cellular microrelief; hydrodynamic model; mathematical model; ANSYS Fluent; two-dimensional parametric analysis.

Article focuses on the improvement of the technologies used to improve the durability of friction pair components. The authors use the piston compressor to study cellular microrelief surfaces of cylindrical components. The cells are shaped as elliptic paraboloid with uneven positive parameters. The use of cellular microrelief surfaces is highly preferred as they reduce the attrition wear of the friction pairs through assuring the hydrodynamic load capacity of the lubrication layer with the shape of the microrelief. The research goals included the parametric analysis of the lubrication layer behavior in the gap between the microrelief cells. To do this, the authors developed an analytical model based on the theory of hydrodynamic lubrication and constructed a CFD model using the ANSYS Fluent software. To contain the transfer equations, the authors used the turbulence model SST k–ω. Both models showed that the maximum hydrodynamic load capacity coincided with the 75%-length of the major axis of the elliptic cell, which also corresponds to 0.128 mm in cell depth. The maximum lifting hydrodynamic pressure on one microrelief cell amounted to 3 kPa. Based on the results of the parametric analysis, the authors claim that the cellular microrelief can be efficiently used to assure the service properties of friction pairs in process units.

Keywords: friction pair; cylinder sleeve; piston ring; cellular microrelief; hydrodynamic model; mathematical model; ANSYS Fluent; two-dimensional parametric analysis.

References

  1. Wojciechowski, L., Kubiak, K. J., Mathia, T. G. (2016). Roughness and wettability of surfaces in boundary lubricated scuffing wear. Tribology International, 93(B), 593-601.
  2. Miao, C., Guo, Z., Yuan, C. (2022). Tribological behavior of co-textured cylinder liner-piston ring during running-in. Friction, 10, 878-890.
  3. Kumar, S., Kumar, M. (2022). Tribological and mechanical performance of coatings on piston to avoid failure — a review. Journal of Failure Analysis and Prevention, 22, 1346-1369.
  4. Dokshanin, S. G., Tynchenko, V. S., Bukhtoyarov, V. V., et al. (2019). Investigation of the tribological properties of ultrafine diamond-graphite powder as an additive to greases. IOP Conference Series: Materials Science and Engineering, 560, 012192.
  5. Bukhtoyarov, V., Zyryanov, D., Tynchenko, V., et al. (2020). Research of data analysis techniques for vibration monitoring of technological equipment. In: Software Engineering Perspectives in Intelligent Systems. CoMeSySo 2020. Advances in Intelligent Systems and Computing, 1294, 598-605.
  6. Shneyder, Yu. G. (1982). Operational properties of parts with regular microrelief. Saint Petersburg: Mashinostroyeniye.
  7. Gafarov, A. M. Shikhseidov, A. Sh. (1999). Metal processing by vibration rolling. Baku: Elm.
  8. Shchedrina, A. V., Bekaeva, A. A., Tomskaya, N. V. (2021). Improving rotary cutting. Russian Engineering Research, 41(11), 1065-1066.
  9. 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.
  10. Gainiev, R. R., Barykin, A. Y., Takhaviev, R. K., Nuretdinov, D. I. (2020). Improvement of repair impact efficiency during technical operation of diesel engines. International Journal of Engineering Research and Technology, 13(11), 3601-3604.
  11. Zhao, W., Wang, L., Xue, Q. (2010). Influence of micro/nano-textures and chemical modification on the nanotribological property of Au surface. Colloids and Surfaces A: Physicochemical and Engineering Aspects, 366(1-3), 191-196.
  12. Liu, C., Lu, Y.-J., Zhang, Y.-F., et al. (2017). Numerical study on the lubrication performance of compression ring-cylinder liner system with spherical dimples. PLoS ONE, 12(7), e0181574.
  13. Zhang, Y., Zeng, L., Wu, Z., et al. (2019). Synergy of surface textures on a hydraulic cylinder piston. Micro & Nano Letters, 14(4), 424-429.
  14. Petrovsky, D. E., Petrovsky, E. A. (2017). Rotary tool modules for processing parts of technological machines. Stary Oskol: TNT.
  15. Zakharov, S. M. (2010). Hydrodynamic lubrication: state and prospects. Friction and Wear, 31(1), 78-92.
  16. Dotsenko, A. I., Buyanovsky, I. A. (2014). Fundamentals of tribology. Moscow: INFRA-M.
  17. Putintsev, S. V. (2011). Mechanical losses in reciprocating engines: special design, calculation and testing chapters. Moscow: Bauman Moscow State Technical University.
  18. Paley, M. A., Romanov, A. B., Braginsky, V. A. (2001). Tolerances and landings: Part 1. Saint Petersburg: Politehnika.
  19. ANSYS Fluent Theory Guide. https://www.afs.enea.it/project/neptunius/docs/fluent/html/th/node67.htm
Read more Read less

DOI: 10.5510/OGP20220400791

E-mail: bashmur@bk.ru


G. G. Ismailov, Y. Z. Alakparov, R. A. Ismailov

Azerbaijan State Oil and Industry University, Baku, Azerbaijan

About rationale for the selection of the cooling capacity of the turbodetander unit in the process of gas preparation


In gas condensate fields, low-temperature separation process is mainly used for primary processing of gas. Cooling of well products in gas preparation systems is achieved by throttling them. As the reservoir pressure decrease, the amount of energy obtained decreases. This worsens the conditions for the preparation of gases. Therefore, raises a need to use additional energy sources. Analysis of the operating modes of gas treatment plants has shown that the energy obtained during the expansion of gas can be used rationally. Calculations have shown that the gas temperature at the outlet of turbodetander units during adiabatic expansion provides the required dew point for water and hydrocarbons.

Keywords: gas; condensate; turbodetander; gas expansion; polytrophic; adiabatic; cold productivity; dew point.

In gas condensate fields, low-temperature separation process is mainly used for primary processing of gas. Cooling of well products in gas preparation systems is achieved by throttling them. As the reservoir pressure decrease, the amount of energy obtained decreases. This worsens the conditions for the preparation of gases. Therefore, raises a need to use additional energy sources. Analysis of the operating modes of gas treatment plants has shown that the energy obtained during the expansion of gas can be used rationally. Calculations have shown that the gas temperature at the outlet of turbodetander units during adiabatic expansion provides the required dew point for water and hydrocarbons.

Keywords: gas; condensate; turbodetander; gas expansion; polytrophic; adiabatic; cold productivity; dew point.

References

  1. Yazik, A.V. (1986). Systems and means for cooling of natural gas. Moscow: Nedra.
  2. Gritsenko, A. I., Aleksandrov, I. A., Galanin, I. A. (1981). Physical methods of gas processing and use. Moscow: Nedra.
  3. Siebert, G. K., Zaporozhets, E. P., Siebert, A. G. et al. (2015). Technological processes and methods for calculating equipment for hydrocarbon gas treatment plants. Moscow: National University of Oil and Gas «Gubkin University».
  4. Melnikov, V. B., Makarova, N. P., Fedorova, E. B. (2012). Collection and preparation of gas and gas condensate. Low temperature processes. Moscow: National University of Oil and Gas «Gubkin University».
Read more Read less

DOI: 10.5510/OGP20220400792

E-mail: asi_zum@mail.ru


L. M. Gaisina1, I. L. Litvinenko2, L. R. Magomaeva3, M. M.Muradov4

1USPTU, Ufa, Russia; 2MSUHE, Moscow, Russia; 3Grozny State Oil Technical University named after Academician M.D. Millionshchikov, Grozny, Russia; 4Sumgait State University, Sumgait, Azerbaijan

Innovation and investment aspect energy transition to renewable energy sources


The article comprehensively considers the economic aspects of the process of transition of the global economy to the use of renewable energy sources. An assessment was made of the potential investment and physical needs of energy based on renewable sources, and a study was made of the potential of the global economy to meet these needs. An analysis was made of the previously implemented actions of the governments of the countries of the world and business in the direction of the formation of an energy sector based on the use of renewable energy sources. Obstacles to the transition of the global economy to renewable energy sources of an economic and resource nature have been identified. The analysis of the experience of the countries of the world in overcoming the relevant obstacles and the formation of conditions by states to reduce the barriers for the entry of a global investor into the energy sector based on renewable resources was carried out. The most significant results from the point of view of the formation of energy based on renewable sources were studied and an assessment was made of their use for the formation of energy based on renewable sources in other countries of the world. Considerable attention is paid to the experience of the EU as an interstate integration group, the most integrated in the process of formation of energy based on renewable sources. Based on the results of the analysis of innovative and investment aspects of the energy transition to renewable energy sources, energy development trends until 2050 were formulated and a system of recommendations was developed for the implementation of the energy transition in the countries of the world.

Keywords: energy; renewable energy sources; innovations; investments; state regulation; modernization.

The article comprehensively considers the economic aspects of the process of transition of the global economy to the use of renewable energy sources. An assessment was made of the potential investment and physical needs of energy based on renewable sources, and a study was made of the potential of the global economy to meet these needs. An analysis was made of the previously implemented actions of the governments of the countries of the world and business in the direction of the formation of an energy sector based on the use of renewable energy sources. Obstacles to the transition of the global economy to renewable energy sources of an economic and resource nature have been identified. The analysis of the experience of the countries of the world in overcoming the relevant obstacles and the formation of conditions by states to reduce the barriers for the entry of a global investor into the energy sector based on renewable resources was carried out. The most significant results from the point of view of the formation of energy based on renewable sources were studied and an assessment was made of their use for the formation of energy based on renewable sources in other countries of the world. Considerable attention is paid to the experience of the EU as an interstate integration group, the most integrated in the process of formation of energy based on renewable sources. Based on the results of the analysis of innovative and investment aspects of the energy transition to renewable energy sources, energy development trends until 2050 were formulated and a system of recommendations was developed for the implementation of the energy transition in the countries of the world.

Keywords: energy; renewable energy sources; innovations; investments; state regulation; modernization.

References

  1. Litvinenko, I., Gaisina, L., Shakirova, E., et al. (2021). The innovative component of ubiquitous digitalization: scales and prospects. AD ALTA: Journal of Interdisciplinary Research, 11(2), S21, 225-230.
  2. (2021). Renewables 2021. Analysis and forecast to 2026. International Energy Agency.
  3. Revel-Muroz, P. A., Bakhtizin, R. N., Karimov, R. M., Mastobaev, B. N. (2017). Joint usage of thermal and chemical stimulation technique for transportation of high viscosity and congealing oils. SOCAR Proceedings, 2, 49-55.
  4. Litvinenko, I. L., Gaisina, L. M., Semenova, L., et al. (2021). Transformation of institutions of socio-economic development in the conditions of a long-term viral pandemic. AD ALTA: Journal of Interdisciplinary Research, 11(2), C21, 220-224.
  5. (2021). Statistical overview of world energy – 2021. London: BP.
  6. Litvinenko, I. L., Shouty, M. G., Kazanbieva, A. Kh., et al. (). (2021). Specifics of investing in human capital in the modern Russian Federation. AD ALTA: Journal of Interdisciplinary Research, 11(2), C20, 14-19.
  7. IRENA. (2018). Global energy transformation. A roadmap to 2050. Abu Dhabi: International Renewable Energy Agency.
  8. Bakhtizin, R. N., Vereshchagin, A. S., Furman, A. B. (2003). The battle for oil / Russia in the global struggle for «black gold» (the end of XIX - mid XX centuries). Ufa.
  9. Litvinenko, I. L., Smirnova, I. A., Nightingale, N. N., et al. (2021). Digitisation and innovatice economic space. AD ALTA: Journal of Interdisciplinary Research, 11(2), C20, 20-24.
  10. Konoplyanik, A. (2022). Energy transition and green energy: the struggle for climate and for a new redistribution of the world - and a proposal for a balanced solution between Russia and the EU. Journal of World Energy Law and Business, 15(1), 59-73.
  11. Wang, X., Lo, K. (2021). Just transition: A conceptual review. Energy Research & Social Science, 82, 102291.
  12. Karasmanaki, E. (2021). Energy transition and willingness to pay for renewable energy sources: the case of environmental students. IOP Conferences Series: Earth and Environmental Science, 899, 012048.
  13. (2021). Global Energy Perspective 2021. January 2021. McKinsey & Company.
  14. Pagliaro, M. (2020). Renewable energy in Russia: A critical perspective. Energy Science & Engineering, 9(7), 950-957.
  15. (2021). Leveraging energy action for advancing the sustainable development goals. In: Policy briefs in support of the high-level political forum. United Nations.
  16. Timokhin, D., Bugayenko, M., Putilov, A. (2020). The use of IT technologies in the implementation of the methodology of the «economic cross» in the project «Breakthrough» of Rosatom. Procedia Computer Science, 169, 445-451.
  17. Gorokhova, A. E., Gaisina, L. M., Gareev, E. S., et al. (2018). Application of coaching methods at agricultural and industrial enterprises to improve the quality of young specialists’ adaptation. Quality - Access to Success, 19(164), 103-108.
  18. Sekerin, V. D., Gaisina, L. M., Shutov, N. V., et al. (2018). Improving the quality of competence-oriented training of personnel at industrial enterprises. Quality - Access to Success, 19(165), 68-72.
  19. Gaisina, L. M., Shayakhmetova, R. R., Mingazetdinova, R. F., et al. (2021). Social responsibility during the Covid-19 pandemic (The Republic of Bashkortostan). Laplage Em Revista, 7(3A), 226-234.
  20. Bakhtizin, R., Evtushenko, E., Burenina, I., et al. (2016). Methodical approach to design of system of the logistic centers and wholesale warehouses at the regional level. Journal of Advanced Research in Law and Economics, 1(15), 16 – 25.
Read more Read less

DOI: 10.5510/OGP20220400793

E-mail: glmug@mail.ru


E. B. Zeynalov1, Y. M. Naghiyev1, A. B. Huseynov1, M. I. Nadiri1, A. D. Guliyev2, N. I. Salmanova3, M. H. Abbasov1, F. B. Nazarov3, R. R. Apayeva1

1Nagiyev ICICh., ANAS, Baku, Azerbaijan; 2IPP named after acad. Y. Mammadaliyev, ANAS, Baku, Azerbaijan; 3ASUOI, Baku, Azerbaijan

Aerobic-peroxide oxidation of naphthalene in the presence of transition metal on a nanocarbon carrier


The paper describes the results of aerobic-peroxide catalytic oxidation of naphthalene in the presence of iron-containing multi-walled carbon nanotubes Fe@MWCNT. The active nanocarbon substrate containing α-iron atoms and carbides realizes by the Fenton reaction active formation of active particles and intensive oxidation of the hydrocarbon under rather mild conditions. It was found that at the temperature range 333 - 353K, in the presence of hydrogen peroxide (30% aqueous solution) and Fe@MWCNT (Fe ≈3.7 wt. %), under intense air current, the reaction proceeds without destroying the cyclic structure of the molecule with predominant formation of phthalic anhydride and naphthol. Identification of the functional groups of the main target products was performed by the infrared (IR) spectroscopy. The results obtained can be proposed for further development of such studies and bringing them into compliance with the standards of the industrial process.

Keywords: aerobic oxidation of hydrocarbons; oxidation of naphthalene; hydrogen peroxide; multi-walled carbon nanotubes; nanocarbon catalysis; Fenton system, oxygencontaining aromatic compounds.

The paper describes the results of aerobic-peroxide catalytic oxidation of naphthalene in the presence of iron-containing multi-walled carbon nanotubes Fe@MWCNT. The active nanocarbon substrate containing α-iron atoms and carbides realizes by the Fenton reaction active formation of active particles and intensive oxidation of the hydrocarbon under rather mild conditions. It was found that at the temperature range 333 - 353K, in the presence of hydrogen peroxide (30% aqueous solution) and Fe@MWCNT (Fe ≈3.7 wt. %), under intense air current, the reaction proceeds without destroying the cyclic structure of the molecule with predominant formation of phthalic anhydride and naphthol. Identification of the functional groups of the main target products was performed by the infrared (IR) spectroscopy. The results obtained can be proposed for further development of such studies and bringing them into compliance with the standards of the industrial process.

Keywords: aerobic oxidation of hydrocarbons; oxidation of naphthalene; hydrogen peroxide; multi-walled carbon nanotubes; nanocarbon catalysis; Fenton system, oxygencontaining aromatic compounds.

References

  1. Stahl, S. , Alsters, P. L. (Eds.). (2016). Liquid phase aerobic oxidation catalysis: industrial applications and academic perspectives. John Wiley & Sons.
  2. Suresh, A. K., Sharma, M. M., Sridhar, T. (2000). Engineering aspects of industrial liquid-phase air oxidation of hydrocarbons. Industrial & Engineering Chemistry Research, 39(11), 3958-3997.
  3. Mills, P. L., Chaudhari, R. V. (1999). Reaction engineering of emerging oxidation processes. Catalysis Today, 48(1-4), 17-29
  4. Sheldon, R. A., Dakka, J. (1994). Heterogeneous catalytic oxidations in the manufacture of fine chemicals. Catalysis Today, 19(2), 215-245.
  5. Litvintsev, I. Yu. (2004). Oxidation processes in industrial organic chemistry. Soros Educational Journal, 8(1), 24-31.
  6. Nagiev, T. M. (2007). Coherent synchronized oxidation reactions by hydrogen peroxide. Monograph. Amsterdam: Elsevier.
  7. Zeynalov, B., Nagiyev, T. M. (2015). Enzymatic catalysis of hydrocarbons oxidation “in vitro” (review). Chemistry & Chemical Technology, 9(2), 157-164.
  8. Alimardanov, Kh. M., Velieva, F. M., Garibov, N. I., Musaeva, E. S. (2020). Kinetic regularities of liquid-phase oxidation of styrene with hydrogen peroxide in the presence of polyoxotungstate. Journal of Applied Chemistry, 93(5), 722-734.
  9. Zeynalov, E. B. (2016). Carbon nano-dimensional catalysts for oxidation of hydrocarbons by hydrogen peroxide (a review). Azerbaijan Chemical Journal, 3, 175-183.
  10. Zeynalov, E., Nagiyev, T., Friedrich, J., Magerramova, M. (2018). Carbonaceous nanostructures in hydrocarbons and polymeric aerobic oxidation mediums / In: Fullerenes, graphenes and nanotubes: A pharmaceutical approach. (Ed.) A. M. Grumezescu. Elsevier –William Andrew Publishing House, Ch. 16, 631-681.
  11. Zeynalov, E. B., Huseynov, E. R. (2018). Nanocatalisis. Emphases. Azerbaijan Chemical Journal, 2, 40-43.
  12. Zeynalov, E. B., Allen, N. S., Salmanova, N. I., Vishnyakov, V. M. (2019). Carbon nanotubes catalysis in liquid-phase aerobic oxidation of hydrocarbons: Influence of nanotube impurities. Journal of Physics and Chemistry of Solids, 127(4), 245-251.
  13. Kim, S. C. (2002). The catalytic oxidation of aromatic hydrocarbons over supported metal oxide. Journal of Hazardous Materials, 91(1-3), 285-299.
  14. Raja, R., Ratnasamy, P. (1997). Selective oxidation of aromatic hydrocarbons over copper complexes encapsulated in molecular sieves / In: Studies in surface science and catalysis. Elsevier, Vol. 105, 1037-1044.
  15. Gao, J., Tong, X., Li, X., et al. (2007). The efficient liquid‐phase oxidation of aromatic hydrocarbons by molecular oxygen in the presence of MnCO3. Journal of Chemical Technology & Biotechnology: International Research in Process, Environmental & Clean Technology, 82(7), 620-625.
  16. Shie, J. L., Chang, C. Y., Chen, J. H., et al. (2005). Catalytic oxidation of naphthalene using a Pt/Al2O3 Applied Catalysis B: Environmental, 58(3-4), 289-297.
  17. Bampenrat, A., Meeyoo, V., Kitiyanan, B., et al. (2008). Catalytic oxidation of naphthalene over CeO2–ZrO2 mixed oxide catalysts. Catalysis Communications, 9(14), 2349-2352.
  18. Garcia, T., Solsona, B., Taylor, S. H. (2006). Naphthalene total oxidation over metal oxide catalysts. Applied Catalysis B: Environmental, 66(1-2), 92-99.
  19. Clarke, T. J., Kondrat, S. A., Taylor, S. H. (2015). Total oxidation of naphthalene using copper manganese oxide catalysts. Catalysis Today, 258, 610-615.
  20. Aranda, A., Agouram, S., López, J. M., et al. (2012). Oxygen defects: The key parameter controlling the activity and selectivity of mesoporous copper-doped ceria for the total oxidation of naphthalene. Applied Catalysis B: Environmental, 127, 77-88.
  21. Sellick, D. R., Aranda, A., García, T., et al. (2013). Influence of the preparation method on the activity of ceria zirconia mixed oxides for naphthalene total oxidation. Applied Catalysis B: Environmental, 132, 98-106.
  22. Westerman, D. W. B., Foster, N. R., Wainwright, M. S. (1982). The role of alkali metal sulphates in the oxidation of naphthalene to phthalic anhydride. Applied Catalysis, 3(2), 151-160.
  23. Shi, F., Tse, M. K., Beller, M. (2007). A novel and convenient process for the selective oxidation of naphthalenes with hydrogen peroxide. Advanced Synthesis & Catalysis, 349(3), 303-308.
  24. Giurg, M., Syper, L., Młochowski, J. (2004). Hydrogen peroxide oxidation of naphthalene derivatives catalyzed by poly (bis-1, 2-diphenylene) diselenide. Polish Journal of Chemistry, 78(2), 231-248.
  25. Shi, F., Tse, M. K., Beller, M. (2007). Selective oxidation of naphthalene derivatives with ruthenium catalysts using hydrogen peroxide as terminal oxidant. Journal of Molecular Catalysis A: Chemical, 270(1-2), 68-75.
  26. Iwasa, S., Fakhruddin, A., Widagdo, H. S., Nishiyama, H. (2005). A rapid and efficient synthesis of quinone derivatives: Ru (II)‐or Ir (I)‐catalyzed hydrogen peroxide oxidation of phenols and methoxyarenes. Advanced Synthesis & Catalysis, 347(4), 517-520.
  27. Wienhoefer, G., Schroeder, K., Moeller, K., et al. (2010). A novel process for selective ruthenium‐catalyzed oxidation of naphthalenes and phenols. Advanced Synthesis & Catalysis, 352(10), 1615-1620.
  28. Khavasi, H. R., Safari, N. (2005). Effects of metal and porphyrin structure on the yield and chemoselectivity of naphthalene oxidation: a comparative study for manganese and iron. Journal of Porphyrins and Phthalocyanines, 9(02), 75-81.
  29. Yan, T., Hong, M., Niu, L., et al. (2012). Manganese (II) naphthenate as effective catalyst for the clean oxidation of 2-methylnaphthalene by hydrogen peroxide. Research on Chemical Intermediates, 38(8), 1839-1846.
  30. Zeynalov, E. B., Huseynov, A. B., Huseynov, E. R., et al. (2021). Impact of as-prepared and purified multi-walled carbon nanotubes on the liquid-phase aerobic oxidation of hydrocarbons. Chemistry & Chemical Technology, 15(4), 479-485.
  31. Abdullayeva, S. H., Musayeva, N. N., Frigeri, C., et al. (2015). Characterization of high quality carbon nanotubes synthesized via Aerosol –CVD. Journal of Advances in Physics, 11(3), 3229−3240.
  32. Emanuel, N. M., Denisov, E. T., Maizus, Z. K. (1967). Liquid phase oxidation of hydrocarbons. New York: Plenum Press.
  33. Zeynalov, B. K. (1964). Oxidation of paraffinic distillate and ways of the oxidation products practical Baku: Azerneshr.
  34. Zeynalov, E., Friedrich, J., Meyer-Plath, A., et al. (2013). Plasma-chemically brominated single-walled carbon nanotubes as novel catalysts for oil hydrocarbons aerobic oxidation. Applied Catalysis A, 454, 115–118.
  35. Zeynalov, B., Allen, N. S., Salmanova, N. I., Vishnyakov, V. M. (2019). Carbon nanotubes catalysis in liquid-phase aerobic oxidation of hydrocarbons: Influence of nanotube impurities. Journal of Physics and Chemistry of Solids, 127(4), 245-251.
  36. Zeynalov, E. B., Huseynov, A. B., Huseynov, E. R., et al. (2021). Impact of as-prepared and purified multi-walled carbon nanotubes on the liquid-phase aerobic oxidation of hydrocarbons. Chemistry & Chemical Technology, 15(4), 479-485.
  37. Duesterberg, C. K., Cooper, W. J., Waite, T. D. (2005). Fenton-mediated oxidation in the presence and absence of oxygen. Environmental Science & Technology, 39(13), 5052-5058.
Read more Read less

DOI: 10.5510/OGP20220400794

E-mail: zeynalov_2000@yahoo.com