SOCAR Proceedings

SOCAR Proceedings

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

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

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

V.Kerimov, R.Mustaev, Vu Nam Hai

Russian State Geological Prospecting University, Moscow, Russia

Origin of hydrocarbons in the Bach Ho field (The Vietnamese shelf)


This article presents the results of a geochemical study of oil on the Vietnam shelf (Cuu Long basin), including those in the crystalline basement. The Bach Ho field oils in the basement have a hydrocarbon distribution that is no different than oil of numerous accumulations in Oligocene and Miocene sedimentary sequences. Similar to the organic origin oils of the world, oils from the Bach Ho field lack regular isoprenanes С12 and С17 and cheilanthanes (tri-cyclic terpanes) С22 and С27. A distinctive feature of these oils is a large amount of cheilanthanes С1929, and large neo-adiantane to adiantane and hopanes to steranes ratios. All these parameters indicate a large bacterial contribution in the generation of these oils. Studies have shown the similarity between oil biomarker parameters and the organic matter of sedimentary rocks, which supports the organic nature of the oils in the basement fields on the Vietnam shelf. It is shown that the hydrocarbon accumulations in the basement complexes of the Cuu Long basin are in a secondary occurrence, and their origin was the organic matter of the sedimentary source rocks.

Keywords:  Bach Ho; biomarkers; origin of hydrocarbons; basement.

This article presents the results of a geochemical study of oil on the Vietnam shelf (Cuu Long basin), including those in the crystalline basement. The Bach Ho field oils in the basement have a hydrocarbon distribution that is no different than oil of numerous accumulations in Oligocene and Miocene sedimentary sequences. Similar to the organic origin oils of the world, oils from the Bach Ho field lack regular isoprenanes С12 and С17 and cheilanthanes (tri-cyclic terpanes) С22 and С27. A distinctive feature of these oils is a large amount of cheilanthanes С1929, and large neo-adiantane to adiantane and hopanes to steranes ratios. All these parameters indicate a large bacterial contribution in the generation of these oils. Studies have shown the similarity between oil biomarker parameters and the organic matter of sedimentary rocks, which supports the organic nature of the oils in the basement fields on the Vietnam shelf. It is shown that the hydrocarbon accumulations in the basement complexes of the Cuu Long basin are in a secondary occurrence, and their origin was the organic matter of the sedimentary source rocks.

Keywords:  Bach Ho; biomarkers; origin of hydrocarbons; basement.

References

  1. Gordadze, G. N. (2015). Uglevodorody v neftyanoj geohimii. Teoriya i praktika. Moscow: Rossijskij gosudarstvennyj universitet nefti i gaza imeni I.M. Gubkina.
  2. Kerimov, V. Y., Gordadze, G. N., Lapidus, A. L., et al. (2018). Physicochemical properties and genesis of the asphaltites of Orenburg oblast. Solid Fuel Chemistry, 52(2), 128–137.
  3. Hai, V. N. Mustaev, R. N., Sericova, U. S., Leonova, E. A. (2016). Exploration of the generating potential of the sedimentary complex in the Kyulong basin based on the basin modelling (Vietnam). In: 18th Science and Applied Research Conference on Oil and Gas Geological Exploration and Development, Geomodel-2016.
  4. Gordadze, G. N., Giruc, M. V., Poshibaeva, A. R., Koshelev, V. N. (2016). Osobennosti obrazovaniya regulyarnyh izoprenanov nefti sostava S10-S20. Neftekhimiya, 56(5), 443–447.
  5. Blumenberg, M., Oppermann, B., Guyoneaud, R., Michaelis, W. (2009). Hopanoid-production by Desulfovibrio bastinii isolated from oilfield formation water. FEMS Microbiology Letters, 293, 73-78.
  6. Flesch, G., Rohmer, M. (1989). Prokaryotic triterpenoids: A novel hopanoid from the ethanol-producing bacterium Zymomonas mobilis. Biochemical Journal, 262, 673-675.
  7. Stroeva, A. R., Giruc, M. V., Koshelev, V. N., Gordadze, G. N. (2014). Modeling of formation of petroleum biomarker hydrocarbons by thermolysis and thermocatalysis of bacterium biomass. Petroleum Chemistry, 54(5), 352–359.
  8. Poshibaeva, A. R., Giruc, M. V., Perevalova, A. A., et al. (2017). Neftyanye uglevodorody-biomarkery v produktah termoliza nerastvorimoj chasti biomassy arhej Thermoplasma sp. Materialy 1-go Rossijskogo mikrobiologicheskogo kongressa.
  9. Matveeva, I. A., Gordadze, G. N. (2001). Pregnanes and cheilantanes as indicators of the geological age of oil: the example of oils from the Timan-Pechora province. Geochemistry,4, 455-460.
  10. Lukin, A. E. (2017). Degazaciya Zemli, naftidogenez i neftegazonosnost'. Zbіrnik naukovih prac' UkrDGRІ, 1–2, 142-164.
  11. Savinyh, Yu. V., Lukin, A. E., Doncov, V. V. (2010). Rol' glubinnyh flyuidov v obrazovanii mestorozhdenij nefti v kollektorah fundamenta. Degazaciya zemli: geotektonika, geodinamika, geoflyuidy; neft' i gaz; uglevodorody i zhizn'. GEOS, 476—478.
  12. Kerimov, V. Yu., Rachinsky, M. Z., Mustaev, R. N., Osipov A. V. (2017). Groundwater dynamics forecasting criteria of oil and gas occurrences in alpine mobile belt basins. Doklady Earth Sciences, 476(1), 1066–1068.
  13. Mustaev, R. N., Hai, W. N., Kerimov, V. Y., Leonova, E. A. (2015). Generation and Conditions Formation of Hydrocarbon Deposits in Kyulong Basin by Simulation Results Hydrocarbon Systems. In: 17th Science and Applied Research Conference on Oil and Gas Geological Exploration and Development, Geomodel- 2015.
  14. Guliev, I. S., Kerimov, V. Yu., Mustaev, R. N. (2016). Fundamental challenges of the location of oil and gas in the South Caspian basin. Doklady Earth Sciences, 471(1), 1109–1112.
  15. Kerimov, V. Y., Rachinsky, M. Z. (2016). Geofluid dynamic concept of hydrocarbon accumulation in natural reservoirs. Doklady Earth Sciences, 471(1), 1123–1125.
  16. Rachinsky, M. Z., Kerimov, V. Y. (2015). Fluid dynamics of oil and gas reservoirs. MA, USA: Scrivener Publishing Wiley.
  17. Guliyev, I. S., Kerimov, V. Y., Osipov, A. V., Mustaev, R. N. (2017). Generation and accumulation of hydrocarbons at great depths under the earth's crust. SOCAR Proceedings, 1, 4-16.
  18. Kukuruza, V. D. (2003). Geoehlektricheskie faktory v processah formirovaniya neftegazonosnosti nedr. Monografiya. Kiev: Karbon-Ltd.
  19. Report. (2004). Geochemical and fluid analyses of well 09-3-soi-2x. Vung Tau: JV «Vietsovpetro» – NIPImorneftegas.
  20. Report. (2004). Geochemical modeling for block 01 and 02 – Сuulong basin. Hanoi: Vietnam Petroleum institute.
  21. Report. (2009). Geology and petroleum resources Vietnam. Hanoi: Vietnam National Oil and Gas Group (Petrovietnam).
  22. Kerimov, V. Yu., Gordadze, G. N., Mustaev, R. N., Bondarev, A. V. (2018). Formation conditions of hydrocarbon systems on the Sakhalin shelf of the sea of okhotsk based on the geochemical studies and modeling. Oriental Journal of Chemistry, 34(2), 934-947.
  23. Kerimov, V. Y., Leonov, M. G., Osipov, A. V., et al. (2019). Hydrocarbons in the basement of the South China Sea (Vietnam) shelf and structural -tectonic model of their formation. Geotectonics, 53(1), 42 -59.
  24. Kerimov, V., Rachinsky, M., Mustaev, R., Serikova, U. (2018). Geothermal conditions of hydrocarbon formation in the South Caspian basin. Iranian Journal of Earth Sciences, 10, 78-89.
  25. Kerimov, V. Y., Mustaev, R. N., Osipov, A. V. (2018). Peculiarities of hydrocarbon generation at great depths in the crust. Doklady Earth Sciences, 483(1), 1413 -1417.
  26. Kerimov, V. Yu., Bondarev, A. V., Mustaev, R. N., Khoshtaria, V. N. (2017). Estimation of geological risks in searching and exploration of hydrocarbon deposits. Oil Industry, 8, 36-41.
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DOI: 10.5510/OGP20210100474

E-mail: r.mustaev@mail.ru


A.M.Salmanov1, E.Sh.Karagozov2, E.H.Ahmadov2

1«OilGasScientificResearchProject» Institute, SOCAR, Baku, Azerbaijan; 2Azneft PU, SOCAR, Baku, Azerbaijan

New classification model based on complication extents of structures


This article is devoted to the compilation of classification model according to the complication characteristics of anticlinal structures present at SCB. Besides the number of tectonic blocks, deposition depth of structure has also been taken into consideration when defining the complication extent of structures. Structures have been classified depending on the sea depth and complication map for the Azerbaijan sector of the Basin has been compiled for the very first time. This map can be utilized as a tool to justify the sequential exploration activities.

Keywords:  structure; complication index; classification; field; oil and gas; productive.

This article is devoted to the compilation of classification model according to the complication characteristics of anticlinal structures present at SCB. Besides the number of tectonic blocks, deposition depth of structure has also been taken into consideration when defining the complication extent of structures. Structures have been classified depending on the sea depth and complication map for the Azerbaijan sector of the Basin has been compiled for the very first time. This map can be utilized as a tool to justify the sequential exploration activities.

Keywords:  structure; complication index; classification; field; oil and gas; productive.

References

  1. Yusufzade, H. B. (1979). Development and exploration of offshore oil and gas fields. Baku: Azerneshr.
  2. Salmanov, A. M., Ahmedov, E. G., Ragimov, F. V. (2019). Geologicheskaya obosnovaniya plastovyh parametrov. Mezhdunarodnaya nauchno-prakticheskaya konferenciya «Novye idei v geologii nefti i gaza», 17-20.
  3. Ahmadov, E. H., Veliyev, R.V. (2019). Methods of minimization of uncertainties and geological risks based on Umid gas-condensate field.
  4. Bagirov, E. B. (1999). South Caspian Fields: onshore and offshore reservoir properties. Natural Resurces Research, 4, 209-313.
  5. Salmanov, A. M., Ahmadov, E. H., Rahimov, F. V. (2019). Geological assessment of reservoir factors of the Umid-Babek area. SOCAR Proceedings, 3, 8-14.
  6. Harbaugh, J. W., Doveton, J., Davis, J. (1977). Probability methods in oil exploration. NY-London_ Toronto: John Wiley & Sons.
  7. Puza, B. D. (2015). Bayesian method for statistical analysis. Acton: ANU eView.
  8. Abramowitz, M., Stegun, I. (2012). Handbook of mathematical functions with formulas, graphs, and mathematical table. New York: Dover Publications.
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DOI: 10.5510/OGP20210100475

E-mail: elvin.ahmadov@socar.az


R. B. Abuev1, G. A. Akhmetzhanova2, K. M. Giesemann3

1Atyrau Branch of KMG Engineering, Atyrau, Kazakhstan; 2Kazakh National Technical University named after K.I. Satpayev (Satbayev University), Almaty, Kazakhstan; 3«JV Kazgermunai» LLP, Kyzylorda, Kazakhstan

Updated stratigraphic correlations due to lithological composition at the M-II-4 horizon, Aksai field


The results of laboratory-based core analysis and log interpretation are presented in the paper to justify separation of various lithological reservoir types of the productive horizon M-II-4 within limits of the Aksai field. The geological section under study is composed of sandstones, gravelstones, conglomerates with carbonate-clayey cement with clay and sandstone interlayers. According to the results of the work, taking into account all geological and geophysical data, aleuritic-sandy, gravelite-conglomerate with carbonate cement and gravelite-conglomerate with carbonate-clay cement with layers of clays and sandstones types of reservoirs are identified. The results obtained were taken into account when reservoir characterization, recommendations were given for further areas of research work.

Keywords: South Torgai oil and gas basin; well logging; porosity & permeability properties; productive formation; gravelites; conglomerates.

The results of laboratory-based core analysis and log interpretation are presented in the paper to justify separation of various lithological reservoir types of the productive horizon M-II-4 within limits of the Aksai field. The geological section under study is composed of sandstones, gravelstones, conglomerates with carbonate-clayey cement with clay and sandstone interlayers. According to the results of the work, taking into account all geological and geophysical data, aleuritic-sandy, gravelite-conglomerate with carbonate cement and gravelite-conglomerate with carbonate-clay cement with layers of clays and sandstones types of reservoirs are identified. The results obtained were taken into account when reservoir characterization, recommendations were given for further areas of research work.

Keywords: South Torgai oil and gas basin; well logging; porosity & permeability properties; productive formation; gravelites; conglomerates.

References

  1. Turkov, O. S., Kuantaev, N. E., Kulumbetova, G. E., Yesenaly, D. D. (2020). Atlas of oil and gas fields of the Republic of Kazakhstan. Almaty.
  2. Paragulgov, H. H., Paragulgov, T. H. (2001). Rifting and oil and gas potential of Kazakhstan. Geology of Kazakhstan, 3-4, 102-122.
  3. Akchulakov, U. A., Bigaraev, A. B., Ablazimov, U. A. (2015). Aryskum transcontinental rift belt and its oil and gas potential. Oil and gas basins of Kazakhstan and prospects for their development, Almaty.
  4. Shahabaev, R. S., Kulzhanov, M. K., Paragulgov, Kh. Kh., et al. (2004). Tectonic development and oil and gas potential of the South Torgai basin. Almaty: SIC «Fylym».
  5. Bigaraev, A. B, Filipyev, G. P. (2009). Features of the geological structure and regularities of the placement of hydrocarbon deposits in the Aryskum trough of the South Torgay depression. Oil and Gas, 2, 50-58.
  6. JSC «NIPIneftegaz». (2016). «Recalculation of oil, gas and condensate reserves of the Aksay and Southern Aksay fields» as of 02.01.2016.
  7. Itenberg, S. S., Dakhkilgov, T. D. (1982). Geophysical studies in wells. Moscow: Nedra.
  8. Itenberg, S. S., Schnurman, G. A. (1984). Interpretation of complex reservoir logging data. Moscow: Nedra.
  9. Proshlyakov, B. K., Kuznetsov, V. G. (1991). Lithology. Moscow: Nedra.
  10. Methodological recommendations for calculating geological reserves of oil and gas by volume method (2003). / ed. Petersilye, V. I. Moscow-Tver: VNIGNI, SPC «Tvergeofizika».
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DOI: 10.5510/OGP20210100476

E-mail: abuyev.r@llpcmg.kz Elvr.az


I. Y. Shireli1, R. S. Ibrahimov2, A. S. Mammadov1

1Industrial Safety Department, SOCAR, Baku, Azerbaijan; 2Azerbaijan State University of Oil and Industry, Baku, Azerbaijan

The analysis of the mechanism of destruction of rocks at offshore drilling rig of chinks by hydromonitor chisels


At drilling of offshore drilling rig chinks by hydromonitor chisels as a result of dynamic interaction of a stream of a liquid with rock in the conditions of a chink face there is its hydromonitor destruction. At the moment of  blow the liquid is compressed in the beginning and only then starts to spread. It is known that, in mining, the occurrence of hydromechanical pressure under the influence of high jet pressure, flowing from the bits of the bit, is inherently pulsating during drilling with the offshore drilling rig. Consequently, in the array where the mountain pressure acts, there is a sign-alternating stress, as a result of which the fatigue of the people.

Keywords: drilling; jetting bit; semi-submersible drilling rigs; borehole; rock failure; hydromechanical pressure; elastic waves.

At drilling of offshore drilling rig chinks by hydromonitor chisels as a result of dynamic interaction of a stream of a liquid with rock in the conditions of a chink face there is its hydromonitor destruction. At the moment of  blow the liquid is compressed in the beginning and only then starts to spread. It is known that, in mining, the occurrence of hydromechanical pressure under the influence of high jet pressure, flowing from the bits of the bit, is inherently pulsating during drilling with the offshore drilling rig. Consequently, in the array where the mountain pressure acts, there is a sign-alternating stress, as a result of which the fatigue of the people.

Keywords: drilling; jetting bit; semi-submersible drilling rigs; borehole; rock failure; hydromechanical pressure; elastic waves.

References

  1. Kozyrev, S. P., SHal'nev, K. K. (1970). Relaksacionnaya gipoteza mekhanizma soudareniya zhidkosti i tverdogo tela. Doklady AN SCSR, 192(3), 126.
  2. Safarov, YA. I. (2000). Povyshenie effektivnosti bureniya neftyanyh i gazovyh skvazhin v oslozhnennyh usloviyah. Baku: SADA.
  3. Se, L. YU. (1973). Rasprostranenie voln v poristoj srede, nasyshchennoj zhidkost'yu. Trudy AOIM. Seriya E, 4.
  4. Katsamanis, F., Raftoculos, D., Teokaris, P. (1977). Opredelenie staticheskogo i dinamicheskogo koefficientov intensivnosti napryazhenij metodom kaustik. Trudy AOIM. Seriya D, 2.
  5. Hurshudov, V. A., Balabeshko, V. V., Semyanikov, V. S. (1983). Vliyanie temperatury i davleniya na plotnost' burovogo rastvora. Neftyanoe hozyajstvo, 7, 9-11.
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DOI: 10.5510/OGP20210100477

E-mail: anar.s.mammadov@socar.az


Ye. Kryzhanivskyi, О. Vytyaz, V. Tyrlych, R. Hrabovskyi, V. Artym

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

Evaluation of the conditions of drill pipes failure during tripping operations


The experimental evaluation of the power criterion for the metal fracture of the reserve and the long operated drill pipes was carried out. The conditions under which, during tripping operations, the failure of explored drill pipes, containing  external or internal transverse annular cracks are possible. An interrelation between the depth of critical external or internal transverse annular cracks in drill pipes with the weight of the drilling string is considered, taking into account the influence of dynamic loads during tripping operations. It is shown that internal transverse annular cracks in lowering operating drilling strings at depths of more than 1400 m are more dangerous than external ones, while at depths up to 1400 m, external cross-sectional circular cracks are more dangerous.

Keywords: critical intensity of stresses; critical size of external or internal transverse annular crack; characteristic depth of external or internal transverse annular crack.

The experimental evaluation of the power criterion for the metal fracture of the reserve and the long operated drill pipes was carried out. The conditions under which, during tripping operations, the failure of explored drill pipes, containing  external or internal transverse annular cracks are possible. An interrelation between the depth of critical external or internal transverse annular cracks in drill pipes with the weight of the drilling string is considered, taking into account the influence of dynamic loads during tripping operations. It is shown that internal transverse annular cracks in lowering operating drilling strings at depths of more than 1400 m are more dangerous than external ones, while at depths up to 1400 m, external cross-sectional circular cracks are more dangerous.

Keywords: critical intensity of stresses; critical size of external or internal transverse annular crack; characteristic depth of external or internal transverse annular crack.

References

  1. Pokhmursky, V. I., Kryzhanivsky, Ye. I., Ivasiv, V. M., et al. (2006). Mechanics of fracture and strength of materials: reference manual /Ed. Panasyuk, V. Vol. 10. Strength and durability of oil and gas equipment. Lviv-Ivano-Frankivsk: Institute of Physics and Mechanics named after. G.V. Karpenko National Academy of Sciences of Ukraine; IFNTUOG.
  2. Artym, V., Yatsyniak, І., Hrytsiv, V. (2012). Analysis of corrosion-fatigue failure of drill string elements. Exploration and Development of Oil and Gas Fields, 2(43), 197-202.
  3. Ivasiv, V., Hrydzhuk, Ya., Yurych, L. (2014). Analysis of the causes of drilling string elements failure. Technological Audit and Production Reserves, 6/4(20), 15-17.
  4. Macdonald, K., Bjune, J. (2007). Failure analysis of drillstrings. Engineering Failure Analysis, 14(8), 1641-1666.
  5. Zamani, S., Hassanzadeh-Tabrizi, S., Sharifi, H. (2016) . Failure analysis of drill pipe: A review. Engineering Failure Analysis, 59, 605-623.
  6. Fangpo, L., Yonggang, L., Xinhu, W., Caihong, L. (2011). Failure analysis of Ј127mm IEU G105 drill pipe wash out. Engineering Failure Analysis, 18, 1867–1872.
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  15. Kerimov, Z., Aliyev, A. (1981). On a task of optimizing tripping in drilling tools into a well. Izvestiya vuzov. «Oil and Gas», 7, 20-23.
  16. Kerimov, Z., Balakishiev, N. (1965). On the determination of the reduced mass of a drilling string. Izvestiya vuzov. «Oil and Gas», 10, 31-34.
  17. Kulizade, K., Saidov, A. (1963). Investigation of the starting mode of drawworks, taking into account the mechanical characteristics of the driving engine. Izvestiya vuzov. «Oil and Gas», 7, 23-28.
  18. Kulizade, K., Saidov, A., Kokov, P. (1965). The influence of the main parameters of the hoisting mechanism on its dynamics. Izvestiya vuzov. «Oil and Gas», 6, 97-100.
  19. Radzhabov, N. (1996). Scientific and practical methods of improving the design and forecasting the life of the main components and mechanisms of drilling and repair facilities. PhD dissertation. Baku.
  20. Tarasevich, V. (1968). Basics of improving the performance of drilling rigs. Moscow: Nedra.
  21. Malko, B. (1999). Dynamic characteristics of operating mechanisms of drilling and oil-field facilities and their optimization. PhD dissertation. Ivano-Frankivsk.
  22. Malko, B. (1996). Acceleration of the travelling block with the drilling string during their lifting. Exploration and Development of Oil and Gas Fields. Series «Oilfield Equipment», 33, 91-96.
  23. Malko, B. (2002). Equation of the drilling string movement during descent into the well. Exploration and Development of Oil and Gas Fields, 2(3), 71-73.
  24. Kharchenko, E. (1991). Dynamic processes of drilling rigs. Lviv: Svit.
  25. Yurtayev, V. (1987). Dynamics of drilling rigs. Moscow: Nedra.
  26. Malko, B., Ivasiv, V., Kozak, F., Ferynuk, M. (1998). Coefficient of dynamics of the drilling rig hoisting system // Exploration and development of oil and gas fields. Series «Drilling Oil and Gas Wells», 2(35), 122-131.
  27. Panasyuk, V., Dmytrakh, I., Toth, L., et al. (2014). A method for the serviceability and fracture hazard for structural elements with crack-like defects. Materials Science, 49(5), 565-576.
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DOI: 10.5510/OGP20210100478

E-mail: o.vytyaz@gmail.com


V. J. Abdullayev

«OilGasScientificResearchProject» Institute, SOCAR, Baku, Azerbaijan

New approach for two-phase flow calcuation of artifical lift


The article develops a method for adjusting design pressure of bellows gas lift valves in deviated gas lift wells based on research and calculations and provides a method for the arrangement of gas lift valves along tubing. As a result of the calculations, the valve opening pressure of the first gas lift valve was taken equal to the initial gas pressure, the valve opening pressure of the following valves was 0.05-0.175 MPa lower than that of the previous gas lift valve, and the pressure difference between the last valve and the second from the last valve was 0.28-0.35 MPa.

Keywords: gaslift valve; vertical and deviated gaslift wells; pressure; pressure gradient; special gas consumption; gas-liquid mixture; tubing; inclination angle.

The article develops a method for adjusting design pressure of bellows gas lift valves in deviated gas lift wells based on research and calculations and provides a method for the arrangement of gas lift valves along tubing. As a result of the calculations, the valve opening pressure of the first gas lift valve was taken equal to the initial gas pressure, the valve opening pressure of the following valves was 0.05-0.175 MPa lower than that of the previous gas lift valve, and the pressure difference between the last valve and the second from the last valve was 0.28-0.35 MPa.

Keywords: gaslift valve; vertical and deviated gaslift wells; pressure; pressure gradient; special gas consumption; gas-liquid mixture; tubing; inclination angle.

References

  1. 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.
  2. Suleimanov, B. A., Latifov, Y. A., Veliyev, E. F. (2019). Softened water application for enhanced oil recovery. SOCAR Proceedings, 1, 19-28.
  3. 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.
  4. 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.
  5. Veliyev, E. F. (2020). Mechanisms of polymer retention in porous media. SOCAR Proceedings, 3, 126-134.
  6. Veliyev, E. F. (2020). Review of modern in-situ fluid diversion technologies. SOCAR Proceedings, 2, 50-66.
  7. Suleimanov, B. A. (1997). Slip effect during filtration of gassed liquid. Colloid Journal, 58(6), 749-753.
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  14. Ivakhnenko, A. G., Zaichenko, Y. P., Dimitrov, V. D. (1976). Decision making on basis of self-organizing. Moscow: Soviet Radio.
  15. Suleimanov, B. A., Ismailov, F. S., Dyshin, O. A., & Veliyev, E. F. (2016, October). Screening evaluation of EOR methods based on fuzzy logic and Bayesian inference mechanisms. SPE-182044-MS. In: SPE Russian Petroleum Technology Conference and Exhibition. Society of Petroleum Engineers.
  16. Abbasov, E. M., Dyshin, O. A., Suleimanov, B. A. (2008). Application of wavelet transforms to the solution of boundary value problems for linear parabolic equations. Computational Mathematics and Mathematical Physics, 48(2), 251–268.
  17. 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.
  18. Joachim, I. A. (1968). Oil and gas production. Moscow: Nedra.
  19. Mamaev, V. A., Odisharia, G. E., Klapchik, O. V., et al. (1978). The flow of gas-liquid mixtures in pipes. Moscow: Nedra.
  20. Prosviryakov, N. N., Shibanov, V. A. (1982). Calculation features of directional wells. Proceedings of «Gipromornetegaz», 10.
  21. Hewitt, G., Hall-Taylor, N. (1974). Annular two-phase flows. Moscow: Mir.
  22. Guidance for analysis and enhancement of operation efficiency of directional producer wells (1988) /Ed. Mirzadzhanzade, A. Kh. Baku.
  23. Mirzadzhanzade, A. Kh., Aliev, N. A., Yusifzade, H. B., et al. (1997). Offshore development fragments. Baku: Elm Publishing House.
  24. Gigiberiya, G. (1956). Hydraulics problems on entrapped air pockets. Transactions of Institute of Energy, Academy of Sciences of Georgia SSR, 10.
  25. Galyamov, A. G. (1966). Experimental investigations of the two-phase flow resistance in a non-horizontal pipeline. Oil Industry, 4, 62-65.
  26. Galyamov, A. G., Shammasov, A. M., Sakharova, L. Kh., et al. (1978). The application of a self-organizing model for the hydraulic calculation of gas-liquid flows in pipes. Izvestiya vuzov. «Oil and Gas», 5, 65-67.
  27. Teletov, S. G. (1958). Problem of fluid dynamics of two-phase mixtures. Bulletin of Moscow University, 2.
  28. Poladov, A. R. (1985). Device for operating of gas lift wells. Patent SU1191561.
  29. Frangel, I. V., Sivokhina, N. B., Bronzov, A. S. (1968). Allowable wellbore deviation. Moscow: Gostoptekhizdat.
  30. Brown, K. E. (1977). The technology of artificial lift methods. Vol. 1. USA: PPS Tulsa.
  31. Mamaev, V. A., Odisharia, G. E., Semenov, N. I., et al. (1969). Hydrodynamics of liquid-gas mixtures in pipes. Moscow: Nedra.
  32. Zaitsev, Y. V., Maksutov, R. A., Chubanov, O. V., et al. (1987). Theory and practice of gas lift. Moscow: Nedra.
  33. Charney, I. A. (1996). The effect of topography and fixed inclusions of liquid or gas to pipeline capacity. Oil Industry, 6, 15-20
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DOI: 10.5510/OGP20210100479

E-mail: vugar.abdullayev@socar.az


E. T. Baspaev

«OPTIMUM» Design Institute LLP, Aktau, Kazakhstan

An advanced wellhead device for shock-wave treatment of the bottomhole zone


A newly designed wellhead device has been developed in order to reduce filtration resistance and restore the reservoir-to-well connectivity for shock-wave impact on the bottomhole formation zone. The device can be used for enhanced recovery of crude oil by reservoir stimulation through the well while well completion and well repairs. In this paper, the problem of increasing the frequency of closing and opening the wellhead device is solved through a reliable design and a constant and continuous lower pressure compressed air supply, which allows it to be used to create pressure and rarefaction shock waves in the well. The use of the developed device allows to put into production low-permeability and isolated zones, improving connectivity and thereby facilitating filtration in the «reservoir-well» system, which boosts enhanced oil recovery and reduces oil cost.

Keywords: enhanced oil recovery; shock wave method; bottomhole formation zone; wellhead device; gate valve; formation permeability.

A newly designed wellhead device has been developed in order to reduce filtration resistance and restore the reservoir-to-well connectivity for shock-wave impact on the bottomhole formation zone. The device can be used for enhanced recovery of crude oil by reservoir stimulation through the well while well completion and well repairs. In this paper, the problem of increasing the frequency of closing and opening the wellhead device is solved through a reliable design and a constant and continuous lower pressure compressed air supply, which allows it to be used to create pressure and rarefaction shock waves in the well. The use of the developed device allows to put into production low-permeability and isolated zones, improving connectivity and thereby facilitating filtration in the «reservoir-well» system, which boosts enhanced oil recovery and reduces oil cost.

Keywords: enhanced oil recovery; shock wave method; bottomhole formation zone; wellhead device; gate valve; formation permeability.

References

  1. Suleimanov, B. A., Ismayilov, F. S., Dyshin, O. A., Veliyev, E. F. (2016). Selection methodology for screening evaluation of EOR methods. Petroleum Science and Technology, 34(10), 961-970.
  2. Suleimanov, B. A., Ismailov, F. S., Dyshin, O. A., Veliyev, E. F. (2016, October). Screening evaluation of EOR methods based on fuzzy logic and Bayesian inference mechanisms. SPE-182044-MS. In: SPE Russian Petroleum Technology Conference and Exhibition. Society of Petroleum Engineers.
  3. Suleimanov, B. A., Latifov, Y. A., Veliyev, E. F., Frampton, H. (2018). Comparative analysis of the EOR mechanisms by using low salinity and low hardness alkaline water. Journal of Petroleum Science and Engineering, 162, 35-43.
  4. Vishnyakov, V., Suleimanov, B., Salmanov, A., Zeynalov, E. (2019). Primer on Enhanced Oil Recovery. Gulf Professional Publishing.
  5. Suleimanov, B. A., Azizov, F., Abbasov, E. M. (1998). Specific features of the gas-liquid mixture filtration. Acta Mechanica, 130(1-2), 121-133.
  6. Suleimanov, B. A. (1995). Filtration of disperse systems in a nonhomogeneous porous medium. Colloid Journal, 57(5), 704-707.
  7. Panakhov, G. M., Suleimanov, B. A. (1995). Specific features of the flow of suspensions and oii disperse systems. Colloid Journal, 57(3), 359-363.
  8. Suleimanov, B. A., Bayramov, M. M., Mamedov, M. R. (2004). On the effect of the skin effect on the flow rate of oil wells. Geology, geophysics and development of oil and gas fields, 8, 68-70.
  9. Shakhverdiev, A. Kh., Panakhov, G. M., Suleшmanov, B. A., et al. (1998). Method for development of oil deposit. RU Patent 2123586.
  10. Kudinov, V. I. (2004). Fundamentals of oil and gas industry. Moscow-Izhevsk: IKI RXD.
  11. Suleimanov, B. A., Veliyev, E. F. (2017). Novel polymeric nanogel as diversion agent for enhanced oil recovery. Petroleum Science and Technology, 35(4), 319-326.
  12. 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.
  13. Veliyev, E. F., Aliyev, A. A., Guliyev, V. V., Naghiyeva, N. V. (2019, October). Water shutoff using crosslinked polymer gels. SPE-198351-MS. In: SPE Annual Caspian Technical Conference. Society of Petroleum Engineers.
  14. Suleimanov, B. A., Veliyev, E. F. (2016, November). Nanogels for deep reservoir conformance control. SPE-182534-MS. In: SPE Annual Caspian Technical Conference & Exhibition. Society of Petroleum Engineers.
  15. Suleimanov, B. A., Ismaylov, F. S., Veliyev, E. F. (2014). On the metal nanoparticles effect on the strength of polymer gels based on carboxymethyl cellulose, applying at oil recovery. Oil Industry, 1, 86-88.
  16. Suleimanov, B.A., Latifov, Y. A., Veliyev, E. F. (2019). Softened water application for enhanced oil recovery. SOCAR Proceedings, 1, 19-29.
  17. Suleimanov, B. A., Latifov, Y. A., Veliyev, E. F., Frampton, H. (2017, November). Low salinity and low hardness alkali water as displacement agent for secondary and tertiary flooding in sandstones. SPE-188998-MS. In: SPE Annual Caspian Technical Conference and Exhibition. Society of Petroleum Engineers.
  18. 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.
  19. Suleimanov, B. A., Veliyev, E. F., Dyshin, O. A. (2015). Effect of nanoparticles on the compressive strength of polymer gels used for enhanced oil recovery (EOR). Petroleum Science and Technology, 33(10), 1133-1140.
  20. Shul'ev, Yu. V., Beketov, S. B., Dimitriadi, Yu. K. (2006). Tekhnologiya volnovogo vozdejstviya na produktivnyj plast s cel'yu intensifikacii pritoka uglevodorodov. Gornyj informacionno-analiticheskij byulleten', 6, 388-394.
  21. Abbasov, E. M., Agaeva, N. A. (2014). Propagation of the constructed of pressure waves in fluid with the account dynamic connection of system the well-formation. SOCAR Proceedings, 1, 77-84.
  22. Burov, K. M. (2012). Skvazhinnaya zadvizhka s pnevmoprivodom. Patent RF № 121887.
  23. Agliullin, M. M., Musabirov, M. H., CHupikova, I. Z. i dr. (2013). Tekhnika i tekhnologiya gidroudarno-volnovogo vozdejstviya na priskvazhinnuyu zonu plasta v processe remonta skvazhin v OAO «Tatneft'». Elektronnyj nauchnyj zhurnal «Neftegazovoe delo», 1. http://www.ogbus.ru
  24. Petrichenko, M. R., SHipulin, A. V., Nemova, D. V., Cejtin, D. N. (2013). Predel'naya zadacha dlya neustanovivshegosya dvizheniya flyuida v vertikal'noj skvazhine. Stroitel'stvo unikal'nyh zdanij i sooruzhenij, 10(15).
  25. Gor'kov, A. N. (2006). Shibernaya zadvizhka. Patent RF № 55915.
  26. Shipulin, A. V. (2008). Skvazhinnaya zadvizhka s pnevmoprivodom. Patent RF № 74680.
  27. Ismailov, F. S., Suleimanov, B. A., Ibadov, G. G., et al. (2019). Wellhead device for shock-wave impact on the bottom-hole zone of the formation. Eurasian Patent 032854.
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DOI: 10.5510/OGP20210100480

E-mail: baspaev1989@gmail.com


O. R. Kondrat1, S. M. Rudyi2, M. I. Rudyi2

1Ivano-Frankivsk National Technical University of Oil and Gas IFNTUOG, Ivano-Frankivsk, Ukraine; 2Research and Development Institute of PJSC «Ukrnafta», Ivano-Frankivsk, Ukraine

Petroleum sulfonates of the karpatol trademark as the most effective surfactants for acting on the formation of producing wells


Experimental studies and pilot test results of developed stimulation technologies with petroleum sulfonate indicate economic benefits of the use of Karpatol  achieved due to significant reduction in interfacial tension surfactant-hydrocarbon (oil, condensate, petrol); increase of residual oil displacement factor, destruction of water-oil emulsions, partial permeability build-up of contaminated rock samples, advanced permeability of surfactants in nonuniform permeable and hydrophobic strata, influence on the rheology of viscous oils,  improvement of wells development after stimulation, high technological efficiency of stimulation technologies using Karpatol, increase of  production index after treatment.

Keywords: oil; petroleum sulfonates; surface-active agent; interracial tension; displacement factor; hydrophobic reservoir; well deliverability.

Experimental studies and pilot test results of developed stimulation technologies with petroleum sulfonate indicate economic benefits of the use of Karpatol  achieved due to significant reduction in interfacial tension surfactant-hydrocarbon (oil, condensate, petrol); increase of residual oil displacement factor, destruction of water-oil emulsions, partial permeability build-up of contaminated rock samples, advanced permeability of surfactants in nonuniform permeable and hydrophobic strata, influence on the rheology of viscous oils,  improvement of wells development after stimulation, high technological efficiency of stimulation technologies using Karpatol, increase of  production index after treatment.

Keywords: oil; petroleum sulfonates; surface-active agent; interracial tension; displacement factor; hydrophobic reservoir; well deliverability.

References

  1. Vikoristannya poverhnevo-aktivnih rechovin na rodovishchah VAT «Ukrnafta» (2009) /za zagal. red. Mihajlyuka, V. D., Rudogo, M.,І.]. Galich: Galic'ka drukarnya Plyus.
  2. Mihajlyuk, V. D., Rudij, M. І., Rudij, S. M. (2010). Mіzhfaznij natyag yak funkcіya poverhnevoї aktivnostі poverhnevo-aktivnih rechovin. Naftova і gazova promislovіst', 5, 26-28.
  3. Gorodnov, V. P., Feshchuk, O. V., Mihajlyuk, V. D. i dr. (1990). Sostav dlya obrabotki prizabojnoj zony plasta. A.S. CCCP № 1571224.
  4. Kondrat, O. R. (2000). Eksperimental'nі doslіdzhennya vitіsnennya skondensovanih vuglevodnіv z gazokondensatnih rodovishch rozchinami PAR. Naftova і gazova promislovіst', 1, 34-38.
  5. Lіskevich, Є. І., Rudij, M. І., Mihajlyuk, V. D. (2008). Adsorbcіya poverhnevo-aktivnih rechovin yak chinnik efektivnostі їh zastosuvannya v procesah naftovidobutku. Naftova і gazova promislovіst', 1, 42-44.
  6. Kasyanchuk, V. G., Pilipec, I. A. (1984). Rezul'taty iskusstvennogo vozdejstviya na prizabojnuyu zonu produktivnyh plastov v NGDU «Dolinaneftegaz». Neftepromyslovoe delo, 7, 12-13.
  7. Rudij, M. І., Rudij, S. M. (2009). Tekhnologії dії na privibіjnu zonu plasta vidobuvnih sverdlovin іz vikoristannyam poverhnevo-aktivnih rechovin. Naftova і gazova promislovіst', 1, 45-48.
  8. SOU 11.1-00135390-023-2006. (2006). Sverdlovini na naftu і gaz. Obrobka sverdlovin z vikoristannyam rozchinіv poverhnevo-aktivnih rechovin і їh kompozicіj. Іvano-Frankіvs'k.
  9. Rudij, M. І. (2010). Novі tekhnologії kislotnoї dії na privibіjnu zonu plasta. Galich: Galic'ka drukarnya Plyus.
  10. SOU 11.1-00135390-197-2012. (2012). Viznachennya tekhnologіchnoї docіl'nostі obrobki privibіjnoї zoni. Kiev: PAT «Ukrnafta».
  11. Sisenbayeva, M.R. (2015). Changes in formation oil viscosity in phase change area and effect of SAA «Karpatol-UM2K-Nurol» on bubble-point pressure. SOCAR Proceedings, 3, 21-26.
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DOI: 10.5510/OGP20210100481

E-mail: alexkondratr@gmail.com


A. M. Svalov

Institute of Oil and Gas Problems (OGRI), Russian Academy of Sciences, Moscow

Effect of compact inclusion on the natural frequencies of vibrations of a pipe string in a well


The influence of small-size inclusion of pipes in a well column on the natural frequency of its longitudinal vibrations is investigated. Using the asymptotic expansion in a small parameter, an analytical relation is obtained that describes the change in the period of the column oscillations in the form of some additional small term to the period of the homogeneous column oscillations. Numerical calculations show that the obtained analytical relations almost accurately describe the oscillation period of a column with a massive compact inclusion, while its difference from the oscillation period of a homogeneous column is within ~20%. The results obtained can be useful for preventing resonant phenomena in the drill string when drilling wells, as well as for optimal use of the longitudinal vibrations of the tubing string to influence the bottom-hole zones of producing wells.

Keywords: natural frequency of vibrations; pipe column; small-size inclusion.

The influence of small-size inclusion of pipes in a well column on the natural frequency of its longitudinal vibrations is investigated. Using the asymptotic expansion in a small parameter, an analytical relation is obtained that describes the change in the period of the column oscillations in the form of some additional small term to the period of the homogeneous column oscillations. Numerical calculations show that the obtained analytical relations almost accurately describe the oscillation period of a column with a massive compact inclusion, while its difference from the oscillation period of a homogeneous column is within ~20%. The results obtained can be useful for preventing resonant phenomena in the drill string when drilling wells, as well as for optimal use of the longitudinal vibrations of the tubing string to influence the bottom-hole zones of producing wells.

Keywords: natural frequency of vibrations; pipe column; small-size inclusion.

References

  1. Svalov, A. M. (2008). Device for wave action on productive stratum. RU Patent 2337238.
  2. Svalov, A. M., Mishchenko, I. T., Ibatullin, R. R., et al. (2014). Downhole device for generation and transfer of flexure oscillations to productive stratum. RU Patent 2520674
  3. Landau, L. D., Lifshitz, E. M. (1987). Theory of elasticity. Moscow: Nauka.
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DOI: 10.5510/OGP20210100482

E-mail: svalov@ipng.ru


D. A. Mirzoev

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

Principal features of the continental shelf oil and gas resources development


According to forecast estimates, the depletion of continental oil and gas fields of the Russian Federation is 30 - 50%, and the fields of the continental shelf are less than 1%. Therefore, the main volumes of growth of reserves, oil and gas production in the fuel and energy complex system should be planned at the expense of resources and reserves of the continental shelf. The article considers the principal features of development of oil and gas fields of the continental shelf and criteria determining types of offshore oil and gas fisheries.

Keywords: oil and gas fields development; continental shelf; offshore field development facilities; design; construction and operation of offshore oil and gas field.

DOI: 10.5510/OGP20210100483

E-mail: D_Mirzoev@vniigaz.gazprom.ru


N. A. Valiyev1, M. А. Jamalbayov2, Kh. M. Ibrahimov2, I. R. Hasanov2

1SOCAR Head Office, Baku, Azerbaijan; 2SOCAR «OilGasScientificResearchProject» Institute, Baku, Azerbaijan

On the prospects for the use of CO2 to enhance oil recovery in the fields of Azerbaijan


Studied modern scientific research and world practice of the use of carbon dioxide СО2 in order to intensify production and increase oil recovery. On its basis, taking into account the existing potential opportunities, the possibilities of using СО2 at most of the fields of Azerbaijan were studied, which were classified in terms of the use of СО2 technologies. Taking into account the presence of CO2 sources in Azerbaijan and its unique physicochemical features, great prospects for its application have been established in intensifying production and increasing oil recovery in the fields of Azerbaijan. 

Keywords: carbon dioxide; production intensification; increased oil recovery; supercritical state.

Studied modern scientific research and world practice of the use of carbon dioxide СО2 in order to intensify production and increase oil recovery. On its basis, taking into account the existing potential opportunities, the possibilities of using СО2 at most of the fields of Azerbaijan were studied, which were classified in terms of the use of СО2 technologies. Taking into account the presence of CO2 sources in Azerbaijan and its unique physicochemical features, great prospects for its application have been established in intensifying production and increasing oil recovery in the fields of Azerbaijan. 

Keywords: carbon dioxide; production intensification; increased oil recovery; supercritical state.

References

  1. Suleimanov, B. A., Ismailov, F. S., Dyshin, O. A., Veliyev, E. F. (2016, October). Screening evaluation of EOR methods based on fuzzy logic and bayesian inference mechanisms. SPE182044-MS. In SPE Russian Petroleum Technology Conference and Exhibition. Society of Petroleum Engineers.
  2. Veliyev, E. F. (2020). Review of modern in-situ fluid diversion technologies. SOCAR Proceedings, 2, 50-66.
  3. 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.
  4. Suleimanov, B. A., Dyshin, O. A., Veliyev, E. F. (2016, October). Compressive strength of polymer nanogels used for enhanced oil recovery EOR. SPE-181960-MS. In SPE Russian Petroleum Technology Conference and Exhibition. Society of Petroleum Engineers.
  5. Suleimanov, B. A., Veliyev, E. F. (2016). The effect of particle size distribution and the nano-sized additives on the quality of annulus isolation in well cementing. SOCAR Proceedings, 4, 4-10.
  6. Suleimanov, B. A., Veliyev, E. F., Dyshin, O. A. (2015). Effect of nanoparticles on the compressive strength of polymer gels used for enhanced oil recovery (EOR). Petroleum Science and Technology, 33(10), 1133-1140.
  7. Suleimanov, B. A., Ismaylov, F. S., Veliyev, E. F. (2014). On the metal nanoparticles effect on the strength of polymer gels based on carboxymethyl cellulose, applying at oil recovery. Oil Industry, (1), 86-88.
  8. Suleimanov, B. A., Latifov, Y. A., Veliyev, E. F. (2019). Softened water application for enhanced oil recovery. SOCAR Proceedings, 1, 19-28.
  9. 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.
  10. 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.
  11. 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.
  12. Veliyev, E. F. (2020). Mechanisms of polymer retention in porous media. SOCAR Proceedings, 3, 126-134.
  13. Балинт, В., Бан, А., Долешал, Ш. (1977). Применение углекислого газа в добыче нефти. Москва: Недра.
  14. Martin, D. F., Taber, J. J. (1992). Carbon dioxide flooding. SPE-23564-PA. Journal of Petroleum Technology, 44(04), 396–400.
  15. Gimatudinov, Sh. K. (1971). Physics of oil and gas reservoir. Moscow: Nedra.
  16. Sabirzyanov, A. N., Gumerov, F. M., Gabitov, F. R. (2003). Sub- i sverhkriticheskie flyuidy v processah neftei bitumodobychi. Materialy 12 Evropejskogo simpoziuma «Povyshenie nefteotdachi plastov». Kazan.
  17. Khromykh, L. N., Litvin, A. T., Nikitin, A. V. (2018). Application of carbon dioxide in enhanced oil recovery. The Eurasian Scientific Journal, 5(10).
  18. Pokrepin, B. V. (2008). Development of oil and gas fields. Volgograd: InFolio.
  19. Sohrabi, M., Riazi, M., Jamiolahmady, M., Brown, Ch. (2009, December). Enhanced oil recovery and CO2 storage by carbonated water injection. In: International Petroleum Technology Conference, Doha, Qatar.
  20. Sohrabi, M., Jamiolahmady, M., Al Quraini, A. (2007, June). Heavy oil recovery by liquid CO2/water injection. In: EUROPEC/EAGE Conference and Exhibition, London, U.K.
  21. Farzaneh, S. A., Seyyedsar, S. M., Sohrabi, M. (2016, September). Enhanced heavy oil recovery by liquid CO2 injection under different injection strategies. SPE-181635-MS. In: SPE Annual Technical Conference and Exhibition, Dubai, UAE.
  22. Oldenburg, C. M., Benson, S. M. (2002, February). CO2 injection for enhanced gas production and carbon sequestration. SPE-74367-MS. In: SPE International Petroleum Conference and Exhibition in Mexico, Villahermosa, Mexico.
  23. Izgec, O., Demiral, B., Bertin, H. J., Akin, S. (2005, March-April). CO2 injection in carbonates. SPE-93773-MS. In: SPE Western Regional Meeting, Irvine, California.
  24. Kalra, S., Wu, X. (2014, April). CO2 injection for enhanced gas recovery. SPE-169578-MS. In: SPE Western North American and Rocky Mountain Joint Meeting, Denver, Colorado.
  25. Gumerov, F. M. (2010). Perspektivy primeneniya dioksida ugleroda dlya uvelicheniya nefteotdachi plastov. V sbornike nauchnyh statej «Aktual'nye voprosy issledovanij plastovyh sistem mestorozhdenij uglevodorodov». Chast' II. Moskva: «Gazprom VNIIGAZ».
  26. Lemenovsky, D. A., Bagratashvili, V. N. (1999). Supercritical fluids. new chemical reactions and technologies. Soros Education Journal, 10, 36-41.
  27. Dadashev, M. N., Kuharenko, A. A., Vinokurov, V. A. (2004). Perspektivy ispol'zovaniya sverhkriticheskoj tekhnologii v razlichnyh otraslyah promyshlennosti. Materialy I mezhdunarodnoj nauchno-prakticheskoj konferencii «Sverhkriticheskie flyuidnye tekhnologii: innovacionnyj potencial Rossii». Rostov-na-Donu.
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DOI: 10.5510/OGP20210100484

E-mail: mehemmed.camalbeyov@socar.az


K. I. Matiev, A. M. Samedov, F. M. Akhmedov

«OilGasScientificResearchProject» Institute, SOCAR, Baku, Azerbayjan

Development of pour point depressants for crude oil and study of their properties


A pour point depressant additive has been developed to reduce the pour point of paraffinic oils. The depressant contains a (non-ionic) surfactant, a depressant component and a solvent. The depressor properties of the developed compositions have been studied. It has been established that while adding the compositions to the oil mixture, at a concentration of 0.02% wt. the pour point decreases from +31 oC to -3 - +7 оС, and at a concentration of 0.04% wt. up to -5- + 4 оС. Under the effect of the developed compositions the oil viscosity at + 35 оС decreases from 46.3 mPa·s to 22.1-27.7 mPa·s, and at + 40 °C - from 38.2 mPa·s to 16.6-21.6 mPa·s. Viscosity reduction performance at the indicated temperatures are 40.2-51.6% and 43.5-56.5%, respectively. Compositions 8, 14 and 17 exhibit higher depressor properties.

Keywords: depressant; depressor properties; surfactant; reagent; pour point; viscosity; performance level.

A pour point depressant additive has been developed to reduce the pour point of paraffinic oils. The depressant contains a (non-ionic) surfactant, a depressant component and a solvent. The depressor properties of the developed compositions have been studied. It has been established that while adding the compositions to the oil mixture, at a concentration of 0.02% wt. the pour point decreases from +31 oC to -3 - +7 оС, and at a concentration of 0.04% wt. up to -5- + 4 оС. Under the effect of the developed compositions the oil viscosity at + 35 оС decreases from 46.3 mPa·s to 22.1-27.7 mPa·s, and at + 40 °C - from 38.2 mPa·s to 16.6-21.6 mPa·s. Viscosity reduction performance at the indicated temperatures are 40.2-51.6% and 43.5-56.5%, respectively. Compositions 8, 14 and 17 exhibit higher depressor properties.

Keywords: depressant; depressor properties; surfactant; reagent; pour point; viscosity; performance level.

References

  1. Shakhverdiev, A. Kh., Panakhov, G. M., Suleimanov, B. A., Abbasov, E. M. (2009). Method for development of oil deposit. RU Patent 2125154.
  2. Suleimanov, B. A. (1997). Slip Effect during filtration of gassed liquid. Colloid Journal, 59(6), 749-751.
  3. Suleimanov, B. A. (1995). Filtration of disperse systems in a nonhomogeneous porous medium. Colloid Journal, 57(5), 704-707.
  4. Suleimanov, B. A., Bayramov, М. М., Mamedov, М. R. (2004). On skin-effect influence on the flow rate of oil wells. Geology, Geophysics and Development of Oil and Gas Fields, (8), 68-70.
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  7. Espolov, I. T., Ayapbergenov, E.O., Serkebayeva, B.S. (2016). Features of rheological properties of high-viscosity oil at transportation on the pipeline. Transport and Storage of Oil Products and Hydrocarbons, 3, 35-39.
  8. Volkova, G. I., Loskutova, YU. V., Prozorova, I. V., Berezina, E. M. (2015). Podgotovka i transport problemnyh neftej (nauchno prakticheskie aspekty). Tomsk: Izdatel'skij dom TGU.
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  10. Matiyev, K. I., Agazade, A. D., Alsafarova, M. E., Akhmedov, F. M. (2018). Pour-point depressant for pigh our-point paraffinic oils. SOCAR Proceedings, 3, 32-37.
  11. Soliman, E. A., Elkatory, M. R., Hashem, A. I., Ibahim, H. S. (2018). Synthesis and performance of maleic anhydride copolymers with alkyl linoleate or tetra-esters as pour point depressants for waxy crude oil. Fuel, 211, 535-547.
  12. Lemos, B. C., Gilles, V., Goncalves, G. R., et al. (2018). Synthesis, structure-activity relationship and evaluation of new nonpolymic chemical additives based on naphthoquinone derivatives as was precipitation inhibitors and pour point depressants to petroleum. Fuel, 220, 200-209.
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  14. Zhuravlev, A. V., Pavlenina, V. I., Puhova, E. Iu. (2019). Study of the effect of рour рoint depressant additives on petroleum low-temperature properties and on the asphalten-resin-paraffin deposit formation process. PNRPU Bulletin. Chemical Technology and Biotechnology, 2, 104-111.
  15. Strijkov, I. V. (2007). Dynamics of aspd formation during the pumping of high wax content oil treated with different pour point depressants. Problems of gathering, treatment and transportation of oil and oil products, 2, 70-75.
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DOI: 10.5510/OGP20210100485

E-mail: kazim.metiyev@socar.az


R. A. Gasumov1, E. R. Gasumov2

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

Researches of technological mode of operation of gas wells with a single-lift elevator at a critical speed of upper flow


The article discusses the modes of movement of gas-liquid flows in relation to the operating conditions of waterlogged gas wells at a late stage of field development. Algorithms have been developed for calculating gas well operation modes based on experimental work under conditions that reproduce the actual operating conditions of flooded wells of Cenomanian gas deposits. The concept of calculating the technological mode of operation of gas wells with a single-row elevator according to the critical velocity of the upward flow is considered based on the study of the equilibrium conditions of two oppositely directed forces: the gravity of water drops directed downward and the lifting force moving water drops with a gas flow directed upward. A calculation was made according to the method of the averaged physical parameters of formation water and natural gas in the conditions of flooded Cenomanian gas wells in Western Siberia. The results of a study of the dependence of the critical flow rate of Cenomanian wells on bottomhole pressure and diameter of elevator pipes are presented.

Keywords: field development; well; exploitation; Cenomanian deposits; water-logged gas wells; technological mode; critical speed; upward flow; lift pipes; natural gas; flow rate; produced water; bottomhole pressure.

The article discusses the modes of movement of gas-liquid flows in relation to the operating conditions of waterlogged gas wells at a late stage of field development. Algorithms have been developed for calculating gas well operation modes based on experimental work under conditions that reproduce the actual operating conditions of flooded wells of Cenomanian gas deposits. The concept of calculating the technological mode of operation of gas wells with a single-row elevator according to the critical velocity of the upward flow is considered based on the study of the equilibrium conditions of two oppositely directed forces: the gravity of water drops directed downward and the lifting force moving water drops with a gas flow directed upward. A calculation was made according to the method of the averaged physical parameters of formation water and natural gas in the conditions of flooded Cenomanian gas wells in Western Siberia. The results of a study of the dependence of the critical flow rate of Cenomanian wells on bottomhole pressure and diameter of elevator pipes are presented.

Keywords: field development; well; exploitation; Cenomanian deposits; water-logged gas wells; technological mode; critical speed; upward flow; lift pipes; natural gas; flow rate; produced water; bottomhole pressure.

References

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  6. Gasumov, R. A., SHihalieva, I. S., Iskanderova, I. I. (2017). Matematicheskaya model' dlya rascheta poter' davleniya pri dvizhenii suhogo gaza v vertikal'nyh trubah. Sbornik nauchnyh trudov «Tyumen'NIIgiprogaz».
  7. Gasumov, R. A., Shikhaliyeva, I. S., Iskanderova, I. I. (2016) Investigation of pressure loss during the of gas-liquid flow in vertical pipes. Science. Innovations. Technologies, 4, 139-152.
  8. Mamaev, V. A., Odishariya, G. E., Klapchuk, O. V., et al. (1978). Motion of gas-liquid mixtures in tubes. Moscow: Nedra.
  9. Nikolaev, O. V. (2012). Regulirovanie raboty gazovyh skvazhin na zavershayushchej stadii razrabotki zalezhej po rezul'tatam eksperimental'nyh issledovanij gazozhidkostnyh potokov v vertikal'nyh trubah. Dissertaciya na soiskanie uchenoj stepeni kandidata tekhnicheskih nauk. Moskva.
  10. Tolpaev, V. A., Korchagin, P. V., Gogoleva, S. A. (2013). Approximation dependence of gas supercompressibility factor on pressure and temperature. Automation, Telemechanization and Communication in Oil Industry, 12, 35-38.
  11. Gasumov, R. A., Tolpaev, V. A., Ahmedov, K. S., et al. (2019). Approximation mathematical models of gas well operational properties and their application to flow rate forecasting. Oilfield Engineering, 5, 53‑59.
  12. Gasumov, R. A., Tolpaev, V. A., Akhmedov, K. S., Kravtsov, A. M. (2018). Nonlinear dynamic wave models of gas-liquid flows in technical systems. Automation, Telemechanization and Communication in Oil Industry, 8, 42‑47.
  13. Tolpaev, V. A., Gasumov, R. A., Akhmedov, K. S., Gogoleva, S. A. (2016). Approximation models of gas inflow to wells and calculation of predictive flow rates. Automation, Telemechanization and Communication in Oil Industry, 9, 25-37.
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DOI: 10.5510/OGP20210100486

E-mail: r.gasumov@yandex.ru


E. F. Veliyev, A. A. Aliyev, T. E. Mammadbayli

«OilGasScientificResearchProject» Institute, SOCAR, Baku, Azerbaijan

Machine learning application to predict the efficiency of water coning prevention techniques implementation


The increase in number of the mature fields is accompanied by an increase in the water cut of the produced fluids. One of the most common causes of this phenomenon is the process of water coning, that is, the breakthrough of the bottom water to the wellbore, in which water flows form a figure similar to a cone. The paper proposes a ranking mechanism based on machine learning methods that allow to significantly reduce the resource intensity of existing prediction models. In order to preserve the simplicity of presentation, the proposed mechanism is considered on the example of one technology - DWL. Obtained results show about 10% smaller deviation values when using the least squares support vector machine in comparison with the ANN. Both developed models demonstrated acceptable results for practical application.

Keywords: water coning; artificial neural network; least square support vector machine; particle swarm optimization method; prediction.

The increase in number of the mature fields is accompanied by an increase in the water cut of the produced fluids. One of the most common causes of this phenomenon is the process of water coning, that is, the breakthrough of the bottom water to the wellbore, in which water flows form a figure similar to a cone. The paper proposes a ranking mechanism based on machine learning methods that allow to significantly reduce the resource intensity of existing prediction models. In order to preserve the simplicity of presentation, the proposed mechanism is considered on the example of one technology - DWL. Obtained results show about 10% smaller deviation values when using the least squares support vector machine in comparison with the ANN. Both developed models demonstrated acceptable results for practical application.

Keywords: water coning; artificial neural network; least square support vector machine; particle swarm optimization method; prediction.

References

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  5. Suleimanov, B. A., Veliyev, E. F., Azizagha, A. A. (2020). Colloidal dispersion nanogels for in-situ fluid diversion. Journal of Petroleum Science and Engineering, 193, 107411.
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  8. Suleimanov, B. A., Dyshin, O. A., Veliyev, E. F. (2016, October). Compressive strength of polymer nanogels used for enhanced oil recovery EOR. SPE-181960-MS. In: SPE Russian Petroleum Technology Conference and Exhibition. Society of Petroleum Engineers.
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  23. Liang, J. T., Lee, R. L., Seright, R. S. (1993). Gel placement in production wells. SPE Production & Facilities, 8(04), 276-284.
  24. Siddiqi, S. S., Wojtanowicz, A. K. (2002, January). A study of water coning control in oil wells by injected or natural flow barriers using scaled physical model and numerical simulator. SPE-77415- MS. In: SPE Annual Technical Conference and Exhibition. Society of Petroleum Engineers.
  25. Zhang, P., Wen, X. H., Ge, L., et al. (2008, January). Existence of flow barriers improves horizontal well production in bottom water reservoirs. SPE-115348-MS. In: SPE annual technical conference and exhibition. Society of Petroleum Engineers.
  26. Chaperon, I. (1986, January). Theoretical study of coning toward horizontal and vertical wells in anisotropic formations: subcritical and critical rates. SPE-15377-MS. In: SPE annual technical conference and exhibition. Society of Petroleum Engineers.
  27. Yue, P., Jia, B., Sheng, J., Lei, T., Tang, C. (2019). A coupling model of water breakthrough time for a multilateral horizontal well in a bottom water-drive reservoir. Journal of Petroleum Science and Engineering, 177, 317-330.
  28. Okon, A. N., Appah, D. (2018). Water coning prediction: an evaluation of horizontal well correlations. Engineering and Applied Sciences, 3(1), 21-28.
  29. Oloro, J. O., Adewole, S. E. (2020). Performance and behavior of a horizontal well in reservoir subject to double-edged water drive. Nigerian Journal of Technology, 39(2), 417-423.
  30. Siemek, J., Stopa, J. (2002). A simplified semi-analytical model for water-coning control in oil wells with dual completions system. Journal of Energy Resources Technology, 124(4), 246-252.
  31. Ould-Amer, Y., Chikh, S., Naji, H. (2004). Attenuation of water coning using dual completion technology. Journal of Petroleum Science and Engineering, 45(1-2), 109-122.
  32. Alblooshi, Y. A., Wojtanowicz, A. K. (2018, May). Dynamic water control in naturally fractured bottom water-drive reservoirs via downhole water sink well deployment: first experimental study. SEG-2018-35. In: Research and Development Petroleum Conference and Exhibition 2018 (Vol. 2018, No. 1, pp. 128-131). European Association of Geoscientists & Engineers.
  33. Pratama, I. S., Adiwena, M. D. (2018). Integrated study of down-hole water sink technology to water coning development in thin layers.
  34. Jin, L., Wojtanowicz, A. K. (2010). Performance analysis of wells with downhole water loop installation for water coning control. Journal of Canadian petroleum technology, 49(06), 38-45.
  35. Jin, L., Wojtanowicz, A. K. (2011, January). Minimum produced water from oil wells with water-coning control and water-loop installations. SPE-143715-MS. In: SPE Americas E&P Health, Safety, Security, and Environmental Conference. Society of Petroleum Engineers.
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  38. Suleimanov, B. A., Ismailov, F. S., Dyshin, O. A., Veliyev, E. F. (2016, October). Screening evaluation of EOR methods based on fuzzy logic and Bayesian inference mechanisms. SPE-182044- MS. In: SPE Russian Petroleum Technology Conference and Exhibition. Society of Petroleum Engineers.
  39. Suleimanov, B. A., Ismayilov, F. S., Dyshin, O. A., Veliyev, E. F. (2016). Selection methodology for screening evaluation of EOR methods. Petroleum Science and Technology, 34(10), 961-970.
  40. Rafiq, M. Y., Bugmann, G., Easterbrook, D. J. (2001). Neural network design for engineering applications. Computers & Structures, 79(17), 1541-1552.
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  44. Vong, C. M., Wong, P. K., Li, Y. P. (2006). Prediction of automotive engine power and torque using least squares support vector machines and Bayesian inference. Engineering Applications of Artificial Intelligence, 19(3), 277-287.
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DOI: 10.5510/OGP20210100487

E-mail: elchinf.veliyev@socar.az


B.M.Mukhtanov

Atyrau Branch of KMG Engineering, Atyrau, Kazakhstan

Application of thermal methods in the Republic of Kazakhstan. Current projects and prospects


This article presents the results of assessment and prospectivity of high-viscosity oil reserves difficult to recover development technology application by means of thermal formation treatment based on analysis of Kenkiyak, Kumsai and Mortuk fields development.

Keywords: reservoir; high-viscosity oil; enhanced oil recovery; oil production; thermal recovery methods.

This article presents the results of assessment and prospectivity of high-viscosity oil reserves difficult to recover development technology application by means of thermal formation treatment based on analysis of Kenkiyak, Kumsai and Mortuk fields development.

Keywords: reservoir; high-viscosity oil; enhanced oil recovery; oil production; thermal recovery methods.

References

  1. Babasheva, M. N., Nurbaev, S. T., Murzagalieva, ZH. S. (2012). Utochnennyj proekt razrabotki nadsolevyh zalezhej mestorozhdeniya Kenkiyak. Tom 1. Atyrau: TOO NII «Kaspijmunajgaz».
  2. Babasheva, M. N., Nurbaev, S. T., Ramazan, A. U. (2013). «Analiz razrabotki mestorozhdeniya Kumsaj». Atyrau: TOO NII «Kaspijmunajgaz».
  3. Babasheva, M. N., Kairbekov, S. B., Ramazan, A. U. (2014). Analiz razrabotki opytnyh uchastkov mestorozhdeniya prirodnyh bitumov Mortuk. Atyrau: TOO NII «Kaspijmunajgaz».
  4. Babasheva, M. N., Kairbekov, S. B., Koshtaeva, SH. K. (2013). Proekt opytno-promyshlennyh rabot po ispytaniyu tekhnologij termicheskogo vozdejstviya na zalezhi vysokovyazkoj nefti melovyh gorizontov uchastka Moldabek Vostochnyj mestorozhdeniya Kenbaj». Atyrau: TOO NII «Kaspijmunajgaz».
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DOI: 10.5510/OGP20210100488

E-mail: mukhtanov.B@llpcmg.kz


Kh.M.Gamzaev

Azerbaijan State Oil and Industry University, Baku, Azerbaijan

A method of determining leaks transported liquid from the pipeline


The problem of detecting leaks of oil and petroleum products from the pipeline is considered. For the mathematical description of the problem we use one-dimensional mathematical model of unsteady flow of a viscous incompressible fluid in pipeline, which includes the equation of motion and equation of continuity of fluid flow. In this case, the liquid leak is represented as a point drain described by the Delta function, and the continuity equation is compiled taking into account the point drain. The pressure and volume flow of the liquid in the initial and final sections of the pipeline are considered set. Taking into account the features of point runoff,  the task is split into two tasks with matching conditions. Analytical solutions to the obtained problems are determined and explicit formulas are derived for determining the volume flow rate of the liquid for leakage and the coordinates of the leak location in the pipeline.

Keywords: method of leak detection; location of leaks in pipelines; the fluid flow in the leakage; Inverse problem.

The problem of detecting leaks of oil and petroleum products from the pipeline is considered. For the mathematical description of the problem we use one-dimensional mathematical model of unsteady flow of a viscous incompressible fluid in pipeline, which includes the equation of motion and equation of continuity of fluid flow. In this case, the liquid leak is represented as a point drain described by the Delta function, and the continuity equation is compiled taking into account the point drain. The pressure and volume flow of the liquid in the initial and final sections of the pipeline are considered set. Taking into account the features of point runoff,  the task is split into two tasks with matching conditions. Analytical solutions to the obtained problems are determined and explicit formulas are derived for determining the volume flow rate of the liquid for leakage and the coordinates of the leak location in the pipeline.

Keywords: method of leak detection; location of leaks in pipelines; the fluid flow in the leakage; Inverse problem.

References

  1. Gol'yanov, A. A. (2002). Analiz metodov obnaruzheniya utechek na nefteprovodah. Transport i hranenie nefteproduktov, 10–11, 5–14.
  2. Shestakov, R. A. (2019). Razrabotka metodiki parametricheskoj diagnostiki tekhnologicheskih uchastkov magistral'nyh nefteprovodov. Dissertaciya na soiskanie uchenoj stepeni kandidata tekhnicheskih nauk. Moskva: RGU im. I.M.Gubkina.
  3. Fiedler, J. (2016). An overview of pipeline leak detection technologies. https://asgmt.com/wp-content/ uploads/2016/02/004.pdf
  4. Zhao, Y., Zhuang, X., Min, S. (2010). A new method of leak location for the natural gas pipeline based on wavelet analysis. Energy, 35( 9), 3814-3820.
  5. Uttam, R. (2017). Leak detection in pipe networks using hybrid ANN method. Water Conservation Science and Engineering, 2, 145–152.
  6. Marllene, D. (2010). A model based approach for pipeline monitoring and leak locating. In: 15th IEEE Mediterranean Electrotechnical Conference, Melecon.
  7. Voevodin, A. F., Nikiforovskaya, V. S. (2009). Chislennyj metod opredeleniya mesta utechki zhidkosti ili gaza v truboprovode. Sibirskij zhurnal industrial'noj matematiki, 12(1), 25–30.
  8. Aida-zade, K. R., Ashrafova, E. R. (2017). Numerical leak detection in a pipeline network of complex structure with unsteady flow. Computational Mathematics and Mathematical Physics, 57(12), 1919–1934.
  9. Gamzaev, H. M. (2008). Metod obnaruzheniya utechek nefti i nefteproduktov v truboprovodah. Avtomatizaciya, telemekhanizaciya i svyaz' v neftyanoj promyshlennosti, 2, 24-25.
  10. Lurie, M. V., Zverev, F. S. (2012). Method of zonal location to detect oil leaks. Science & Technologies: Oil and Oil Products Pipeline Transportation, 1, 48-51.
  11. Bondar, D. V., Zholobov, V. V., Varybok, D. I., Nadezhkin, O. S. (2018). About the testing of the leak detecting algorithms based on the sensitivity function. The electronic scientific journal «Oil and Gas Business», 4, 194-233.
  12. Samarskii, A. A., Vabishchevich, P. N. (2009). Numerical methods for solving inverse problems of mathematical physics. Moscow: LKI.
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DOI: 10.5510/OGP20210100489

E-mail: xan.h@rambler.ru