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.

U. J. Aliyeva

«OilGasScientificResearchProject» Institute, SOCAR, Baku, Azerbaijan

Some features of prospecting work in the oil and gas region of Ganja


Extensive exploratory investigations and borehole surveys have confirmed the high prospect of oil and gas potential of the Upper Cretaceous-Maikop deposits in numerous structures in the Ganja oil and gas region. The structures identified in the OGR have a complex structure and are also complicated by multidirectional fractures. Although the regularity of field formation has been clarified, an individual approach to prospecting and exploration operations at each block is necessary. It is necessary to direct prospecting and exploration operations to obtain direct geophysical parameters representing oil and gas potential in other blocks, taking into account the results of recent comprehensive geophysical surveys at the Gazanbulag-Chaily and Naftalan-Godakboz fields. Taking into account the available geophysical data and using appropriate geophysical complexes for predicting of oil and gas potential in anticlinal and non-anticlinal structures, determination of their boundaries and depths, elements of traps and stratigraphic affiliation is an effective way for further exploration of oil and gas.

Keywords: seismic survey; refracted wave; gravity-magnetic survey; seismic and gravimetric anomaly; trap; oil and gas field; upper Cretaceous-Maikop.

Extensive exploratory investigations and borehole surveys have confirmed the high prospect of oil and gas potential of the Upper Cretaceous-Maikop deposits in numerous structures in the Ganja oil and gas region. The structures identified in the OGR have a complex structure and are also complicated by multidirectional fractures. Although the regularity of field formation has been clarified, an individual approach to prospecting and exploration operations at each block is necessary. It is necessary to direct prospecting and exploration operations to obtain direct geophysical parameters representing oil and gas potential in other blocks, taking into account the results of recent comprehensive geophysical surveys at the Gazanbulag-Chaily and Naftalan-Godakboz fields. Taking into account the available geophysical data and using appropriate geophysical complexes for predicting of oil and gas potential in anticlinal and non-anticlinal structures, determination of their boundaries and depths, elements of traps and stratigraphic affiliation is an effective way for further exploration of oil and gas.

Keywords: seismic survey; refracted wave; gravity-magnetic survey; seismic and gravimetric anomaly; trap; oil and gas field; upper Cretaceous-Maikop.

References

  1. Huseynov, B., Salmanov, A., Maharramov, B. (2019). Oil and gas geological zoning onshore Azerbaijan. Baku: Mars Print.
  2. Abbasov, A. B., Karimov, F. M., Ibrahimli, M. S. (2007). Study of the history of the geological development of the Ganja oil and gas region according to the regularity of the distribution of sediments in the area and geochronology stratification. Azerbaijan Oil Industry, 6, 31-33.
  3. Niyazov, T. X., Garayev, B. M. (2015). Revised geological model on the surface of the Cretaceous deposits of the Yevlakh-Aghjabadi depression using seismic data. Azerbaijan Oil Industry, 1, 6-10.
  4. Ganbarov, Y. H. (2009). About seismic exploration of the internal geological structure of the Mesozoic deposits in the Yevlakh-Aghjabadi depression. Azerbaijan Oil Industry, 12, 3-6.
  5. Ganbarov, Y. H., Abbasov, A. B., Karimov, F. M. (2009). Recently discovered prospects North Chayli and North Ziyadkhan in the Yevlakh- Aghjabadi depression. Geophysical Innovations in Azerbaijan, 1-2.
  6. Ganbarov, Y. H., Novruzov, A. G., Gadirov, V. G., et al. (2010). The results of integrated seismic and gravimetric works in the areas of Gazanbulag-Borsunlu-Ziyadkhan. Azerbaijan Oil Industry, 2, 3-7.
  7. Novruzov, A. G., Mammadova, U. J., Jamalova, Kh. Sh., Popova, N.,V. (2016). On the effectiveness of geophysical surveys at the Naftalan-Godakboz area. Azerbaijan Oil Industry, 12, 12-17.
  8. Garayev, B. M., Niyazov, T. Kh. (2013). On the internal geological structure of the Mesozoic deposits in the Naftalan-North Naftalan-Godakboz area. Azerbaijan Oil Industry, 9, 9-13.
  9. Novruzov, A. G., Gadirov, V. Q., Rashidov, A. M., et al. (2007). Method for direct search for oil and gas fields. Patent AZ I 2000181.
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DOI: 10.5510/OGP20210300523

E-mail: ulvmammadova@gmail.com


V. Sh. Gurbanov1, S. V. Galkin2, N. R. Narimanov3, L. A. Sultanov3, G. G. Abbasova3

1Institute of Oil and Gas of the ANAS, Baku, Azerbaijan; 2Perm National Research Polytechnic University, Perm, Russia; 3Azerbaijan State Oil and Industry University, Baku, Azerbaijan

Petrophysical characteristics of the Meso-Cenozoic sediments of the Southeastern subsidence of the Greater Caucasus in connection with their oil and gas potential


In order to assess the prospects for oil and gas potential, the reservoir properties of Mezozoy-Kaynazoic sediments, formed in various geological conditions of the structures of Yalama, Khudat and Siazan monocline, have been studied. The results of the analysis are summarized in tables reflecting the physical and reservoir properties of various types of rocks. On the basis of petrophysical analysis for reservoirs of various lithological types, regularities have been established in changes in density, carbonate content, porosity and permeability of rocks, as well as in the propagation velocity of ultrasonic waves. It was found that changes in reservoir properties of rocks over the area are mainly associated with lithogenesis conditions, with heterogeneity of the lithological composition of sedimentary complexes, with the depth of occurrence of rocks, as well as with the peculiarity of the development of local uplifts. When predicting oil and gas content in deep-seated strata of the territory under consideration, along with exploration and geophysical methods, it is also recommended to use the results of changes in the filtration-volume characteristics of rocks, as well as the nature of the change in the propagation velocity of seismic waves with depth.

Keywords: lithological facies; density; porosity; permeability; carbonate content; seismic P-wave velocity.

In order to assess the prospects for oil and gas potential, the reservoir properties of Mezozoy-Kaynazoic sediments, formed in various geological conditions of the structures of Yalama, Khudat and Siazan monocline, have been studied. The results of the analysis are summarized in tables reflecting the physical and reservoir properties of various types of rocks. On the basis of petrophysical analysis for reservoirs of various lithological types, regularities have been established in changes in density, carbonate content, porosity and permeability of rocks, as well as in the propagation velocity of ultrasonic waves. It was found that changes in reservoir properties of rocks over the area are mainly associated with lithogenesis conditions, with heterogeneity of the lithological composition of sedimentary complexes, with the depth of occurrence of rocks, as well as with the peculiarity of the development of local uplifts. When predicting oil and gas content in deep-seated strata of the territory under consideration, along with exploration and geophysical methods, it is also recommended to use the results of changes in the filtration-volume characteristics of rocks, as well as the nature of the change in the propagation velocity of seismic waves with depth.

Keywords: lithological facies; density; porosity; permeability; carbonate content; seismic P-wave velocity.

References

  1. Yusifzadeh, X. B. (2013). Use of modern technology in exploration and production of oil and gas reservoirs of Azerbaijan. Azerbaijan Oil Industry, 7-8, 3-13.
  2. Kerimov, K. M, Rahmanov, R. R., Xeyirov, M. B. (2001). Oil and gas contest of South Caspian Mega Basin. Baku: «Adiloglu» publishing.
  3. Hain, V. E. (1958). Tektonika neftegazonosnyh oblastej YUgo-Vostochnoe pogruzhenie Bol'shogo Kavkaza. Moskva: Gostoptekhizdat.
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  6. Alizade, A. A., Akhmedov, Q. A., Akhmedov, A. M., et al. (1966). Geology of oil and gas deposits of Azerbaijan. Moscow: Nedra.
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  8. Sokolov, B. A. (1980). Evolyuciya i neftegazonosnost' osadochnyh bassejnov. Moskva: Nauka.
  9. Uspenskaya, N. YU., Tauson, N. N. (1972). Neftegazonosnye provincii i oblasti zarubezhnyh stran. Moskva: Nedra.
  10. Ali-Zadeh, A. A., Salayev, S. Q., Aliyev, A. I. (1985). Scientific evaluation of perceptivity of oil and gas in Azerbaijan, South Caspian and direction of search-exploration operation. Baku: Elm.
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  15. (2010). Creating the catalog of the collector characteristics of Mezo-Cenozoic deposits of oil and perspective oil-gas structures of Azerbaijan. Report of SRI of Geophysics 105-2009. Baku: Fond of Administration of Geophysics and Geology.
  16. Babayev, M. S., Sultanov, L. A., Qanbarova, Sh. A., Aliyeva, T. A. (2014). About the result of petrophysical exploration of deposits of productive series of oil gas field of Baku archipelago. News of Higher Technical Institutions of Azerbaijan, 2, 7-12.
  17. Qurbanov, V. S., Sultanov, L. A., Abbasova, Q. Q. (2014). Lithological-petrophysical and collector contents of Mesozoic deposits of Precaspian-Quba oil and gas zone. Geophysics News of Azerbaijan, 3, 10-13.
  18. Sultanov, L. A., Nadjaf-Guliyeva, V. M., Abbasova, G. G. (2013, November). About predictable the distribution velocity of longitudinal waves and density of sedimentary rocks of Pre-Caspian-Guba area and between the rivers Kura and Gabirri. Proceedings of Gubkin XX. Moscow.
  19. Gurbanov, V. Sh., Babaev, M. S., Sultanov, L. A., Rustamov, R. E. (2012). The shot geologicalgeophysical characteristics of section of Earth crust of Saatli district of ultra deep well №1. The Azerbaijan Geologics, 16, 31-37.
  20. (1985). Physical properties of the mineral system of the Earth’s interior. International monograph Project 3 CAPG. Praha.
  21. Lebedev, T. S. (1980). Model studies of physical properties of mineral matter in high pressure – temperature experiments. Physics of the Earth and Planetary Interiors, 25, 292-303.
  22. Rakhmanov, R. R. (1985). Predictable of formation and placing zones of oil and gas accumulation in Mesozoic sediments of Azerbaijan. Baku: Elm.
  23. Kojevnikov, D. A. (2001). Petrophysical invariance of granular collectors. Geophysics, 4, 31-37.
  24. Rachinsky, M. Z., Chilingar, G. (2007). Raw-material base of the South-Caspian basin: results of explorations conducted in 1995-2005. Geologial aspects of petroleum possibilities. Quantitative estimation. Azerbaijan Oil Industry,1, 32-48.
  25. Mehtiyev, U. Sh., Xeyirov, M. B. (2007). Lito-petrographical and collector characteristics of Kala and Podkirmaky layer of Absheron oil and gas zone of Azerbaijan. Baku.
  26. Raxmanav, R. R., Sultanov, L. A., Najaf-Kuliyeva, V. M., Qanbarova, Sh. A. (2013, February). Assessment of prospective of oil and gas bearing of PL of under Pliocene of shallow zone of Absheron peninsula and of Baku archipelago on complex materials of geological-geophysical researches. Proceedings of International Scientific-practical seminar «Rassokhin reading». Ukhta: USTU.
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DOI: 10.5510/OGP20210300524

E-mail: vagifqurbanov@mail.ru


R. M. Huseynov

«OilGasScientificResearchProject» Institute, SOCAR, Baku, Azerbaijan

Conditions for the formation and accumulation of hydrocarbons in oligocene-miocene sediments of Western Absheron


Oligocene-Miocene deposits, after the main oil-gas suit of Azerbaijan – the Productive Suit, are one of the most studied objects. This complex is classified as mature rocks and, according to the stratigraphic scale, is associated with Maykop, Chokrak, and diatom deposits. Therefore, studies of the conversion of organic substances to hydrocarbons under favourable sedimentation and thermobaric conditions are of great importance. In addition, the determination of hydrocarbon generation zones, the presence of appropriate paleotectonic and paleostructural conditions for their further migration and accumulation in traps are also important tasks requiring clarification. For this purpose, maps of the Maykop and Mid- and Upper Miocene sediments were constructed, models reflecting their paleostructural position by the end of the century of the productive stratum, and predicted paleotemperatures are indicated on the diagrams. As a result, it was found that the reducing-alkaline environment existing during sedimentation in the Maykop and Chokrak period was favourable for the conversion of organic substances into hydrocarbon.

Keywords: Western Absheron; oligocene-miocene sediments; source rock; organic matter; oil window; vitrinite; geochemical condition; source of generation; migration; traps; paleostructure.

Oligocene-Miocene deposits, after the main oil-gas suit of Azerbaijan – the Productive Suit, are one of the most studied objects. This complex is classified as mature rocks and, according to the stratigraphic scale, is associated with Maykop, Chokrak, and diatom deposits. Therefore, studies of the conversion of organic substances to hydrocarbons under favourable sedimentation and thermobaric conditions are of great importance. In addition, the determination of hydrocarbon generation zones, the presence of appropriate paleotectonic and paleostructural conditions for their further migration and accumulation in traps are also important tasks requiring clarification. For this purpose, maps of the Maykop and Mid- and Upper Miocene sediments were constructed, models reflecting their paleostructural position by the end of the century of the productive stratum, and predicted paleotemperatures are indicated on the diagrams. As a result, it was found that the reducing-alkaline environment existing during sedimentation in the Maykop and Chokrak period was favourable for the conversion of organic substances into hydrocarbon.

Keywords: Western Absheron; oligocene-miocene sediments; source rock; organic matter; oil window; vitrinite; geochemical condition; source of generation; migration; traps; paleostructure.

References

  1. Zhabrev, D. V., Mekhtiev, Sh. F. (1959). K bituminologii tretichnogo kompleksa YUgo-Vostoka Azerbajdzhana. Moskva: AN SSSR.
  2. Mekhtiev, Sh. F. (1956). Voprosy proiskhozhdeniya nefti i formirovaniya neftyanyh zalezhej Azerbajdzhana. Baku: AN Azerb. SSR.
  3. Mekhtiev, Sh. F., Digurova, T. M., Potapova, V. I. (1958). Organicheskie komponenty osadochnyh porod Azerbajdzhana. Baku: AN Azerb. SSR.
  4. Mekhtiev, Sh. F. (1969). Problemy genezisa nefti i formirovaniya neftegazovyh zalezhej. Baku: AN Azerb. SSR.
  5. Mekhtiev, Sh. F. (1985). Processy formirovaniya i preobrazovaniya sostava nefti i gaza prirode. Baku: Elm.
  6. Ali-Zade, A. A., Ahmedov, G. A., Aliev, G.-M. A. i dr. (1975). Ocenka nefteproizvodyashchih svojstv mezokajnozojskih otlozhenij Azerbajdzhana. Baku: Elm.
  7. Tagiyev, M. F. (2009). Organicheskoe veshchestvo v paleogen-neogenovyh otlozheniyah YUKV: sravnitel'naya geohimicheskaya harakteristika na osnove piroliza porod s estestvennyh obnazhenij, gryazevyh vulkanov i skvazhin. Geolog Azerbajdzhana, 13, 98-30.
  8. Feyzullaev, A. A., Tagiyev, M. F., Ismajlova, G. G. (2000). Uglevodorodnyj potencial majkopskih otlozhenij Sрamahy-Gobustanskogo rajona. Geolog Azerbajdzhana, 5, 110-119.
  9. Feyzullayev, A. A., Tagiyev, M. F. (2008). Formation of oil-gas deposits in Productive series of the South-Caspian basin: new approaches and results. Azerbaijan Oil Industry, 3, 7-18.
  10. Feyzullayev, A. A., Guliyev, I. S., Tagiyev, M. F. (2001). Source potential of the Mesozoic-Cenozoic rock sin the South Caspian Basin and their role in forming the oil accumulations in the Lower Pliocene reservoirs. Petroleum Geoscience, 7(4), 409-417.
  11. Miles, J. A. (1991). Illustrated glossary of petroleum geochemistry. Oxford: Clarendon Press.
  12. Lerche, I., Alizadeh, Ak. A., Guliyev, I. S., et al. (1997). South Caspian basin: stratigraphy, geochemistry and risk analysis. Baku: Nafta-Press.
  13. Aliyev, Ad. A., Abbasov, O. R., Ibadzade, A. J., Mammadova, A. N. (2018). Genesis and organic geochemical characteristics of oil shale in Eastern Azerbaijan. SOCAR Proceedings, 3, 4–15.
  14. Korchagina, E. P., Guliev, I. S., Zejnalova, K. S. (1988). Neftegazomaterinskij potencial glubokopogruzhennyh mezozojsko-kajnozojskih otlozhenij Yuzhno-Kaspijskoj vpadiny. Problemy neftegazonosnosti Kavkaza. Moskva: Nauka.
  15. Vassoevich, N. B. (1986). Geochemistry of organic matter and origin of oil. Moscow: Nauka.
  16. Bazhenova, O. K., Burlin, Yu. K., Sokolov, B. A., Khain, V. E. (2012). Geology and geochemistry of oil and gas. Moscow: Moscow University Press.
  17. Salmanov, A. M., Magerramov, B. I., Guseynov, R. M. (2011). Estimation of oil and gas prospects of Western Absheron Oligocene-Miocene sediments based on paleogeology analysis. Azerbaijan Oil Industry, 3, 3-11
  18. Salmanov, A. M., Maharramov, B. I., Huseynov, R. M., Agazade, B. Q. (2016). Struktur-tektonik tehlil esasinda Qerbi Absheronun oliqosen-miosen chokuntulerinin neft-qazliliq perspektivliklerinin qiymetlendirilmesi. Azerbaycanda geofizika yenilikleri, 1-2, 23-27.
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DOI: 10.5510/OGP20210300525

E-mail: rovshan.huseynov@socar.az


S. Z. Ismayilov1, V. J. Abdullayev2, E. Sh. Garagozov3, I. A. Qasımov1, Z. Z. Ismayilov1

1«SOCAR – AQS» JV, Baku, Azerbaijan; 2«OilGasScientificResearchProject» Institute, SOCAR, Baku, Azerbaijan; 3«Azneft» PO, SOCAR, Baku, Azerbaijan

Application of drilling of multilateral well on the basis of new technology and model in south Caspian basin


The article discusses the issue of drilling multilateral horizontal wells and provides a brief history of its development. Data were provided on the selection of the location of the multilateral horizontal well, drilling the main wellbore and determining the depth for running the сasing strings. This paper also analyzes the selection of lateral wellbore penetration depth, the importance of drilling multilateral horizontal wells and their application for the first time in the shelf water of South Caspian Basin, at the Western Absheron field, Well 19.

Keywords: multilateral wells; drilling of horizontal wells; petrophysical models; drilling of main and lateral wellbores.

The article discusses the issue of drilling multilateral horizontal wells and provides a brief history of its development. Data were provided on the selection of the location of the multilateral horizontal well, drilling the main wellbore and determining the depth for running the сasing strings. This paper also analyzes the selection of lateral wellbore penetration depth, the importance of drilling multilateral horizontal wells and their application for the first time in the shelf water of South Caspian Basin, at the Western Absheron field, Well 19.

Keywords: multilateral wells; drilling of horizontal wells; petrophysical models; drilling of main and lateral wellbores.

References

  1. Fraija, J., Ohmer, H., Pulick, T., et al. (2002). New aspects of multilateral well construction. Oilfields Review, 14(3), 52-69.
  2. Ehlig-Economides, C.A., Mowat, G. R., Corbett, C. (1996, April). Techniques for multibranch well trajectory design in the context of a three-dimensional reservoir model. SPE-35505-MS. In: SPE European 3-D Reservoir Modeling Conference.
  3. Sugiyama, H., Tochikawa, T., Peden, J.M., Nicoll, G. (1997, April). The optimal application of multilateral/multi-branch completions. SPE-38033-MS. In: SPE Asia Pacific Oil and Gas Conference.
  4. Schlumberger Information Solutions. 23 January 2008.
  5. Technology Advancement for Multi-Laterals (TAML). https://neftegaz.ru/tech-library/burenie/142482- klassifikatsiya-taml/
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DOI: 10.5510/OGP20210300526

E-mail: vugar.abdullayev@socar.az


B. A. Suleimanov1, S. J. Rzayeva1, U. T. Akhmedova2

1«OilGasScientificResearchProject» Institute, SOCAR, Baku, Azerbaijan; 2SOCAR Downstream Management LLC, Baku, Azerbaijan

Self-gasified biosystems for enhanced oil recovery


Microbial enhanced oil recovery is considered to be one of the most promising methods of stimulating formation, contributing to a higher level of oil production from long-term fields. The injection of bioreagents into a reservoir results in the creation of oil-displacing agents along with significant amount of gases, mainly carbon dioxide. In early, the authors failed to study the preparation of self-gasified biosystems and the implementation of the subcritical region (SR) under reservoir conditions. Gasified systems in the subcritical phase have better oil-displacing properties than non-gasified systems. Because, in a heterogeneous porous medium, the filtration profile of gasified liquids in the SR should be more uniform than for a degassed liquid. Based on experimental studies, the superior efficiency of oil displacement by gasified biosystems compared with degassed ones has been demonstrated. The possibility of efficient use of gasified hybrid biopolymer systems has been shown.

Keywords: self-gasified; biosystem; microbial; subcritical region; slippage effect; enhanced oil recovery.

Microbial enhanced oil recovery is considered to be one of the most promising methods of stimulating formation, contributing to a higher level of oil production from long-term fields. The injection of bioreagents into a reservoir results in the creation of oil-displacing agents along with significant amount of gases, mainly carbon dioxide. In early, the authors failed to study the preparation of self-gasified biosystems and the implementation of the subcritical region (SR) under reservoir conditions. Gasified systems in the subcritical phase have better oil-displacing properties than non-gasified systems. Because, in a heterogeneous porous medium, the filtration profile of gasified liquids in the SR should be more uniform than for a degassed liquid. Based on experimental studies, the superior efficiency of oil displacement by gasified biosystems compared with degassed ones has been demonstrated. The possibility of efficient use of gasified hybrid biopolymer systems has been shown.

Keywords: self-gasified; biosystem; microbial; subcritical region; slippage effect; enhanced oil recovery.

References

  1. Bagirov, O. T., Ismailova, S. D., Ismailov, A. D. (2002). Stimulation of oil production at the expense of relaxation properties of bio-reagents. Azerbaijan Oil Industry, 10, 14-18.
  2. Suleimanov, B. A. (2006). Specific features of heterogeneous system filtration. Moscow-Izhewsk: ICR.
  3. Melikov, G. Kh., Azizov, M. G. (1988). Experimental study of the relaxation effect properties of gasliquid systems on filtration in nonhomogeneous porous media. Izvestiya VUZ SSSR. Neft i Gaz, 10, 35–38.
  4. Vahitov, G. G., Mirzadzhanzade, A. H., Ryzhik, V. M. i dr. (1977). Osobennosti vytesneniya vodoj neftej s vyazkouprugimi svojstvami. Neftyanoe hozyajstvo, 4, 38–41.
  5. Ametov, I. M., Khavkin, A. Ya., Buchenkov, L. N., et al. (1997). New opportunities for enhanced oil recovery. Oil Industry, 1, 30–32.
  6. Suleimanov, B. A. (2012). The mechanism of slip in the flow of gassed non-Newtonian liquids. Colloid Journal, 74(6), 726–730.
  7. Namiot, Yu. A. (1991). Solubility of gases in water. Moscow: Nedra.
  8. Mirzadzhanzade, A. Kh., Ametov, I. M., Bogopol'skij, A. O. (1998). Method for development of oil deposit. SU Patent 1822219.
  9. Shakhverdiev, A. Kh., Panakhov, G. M., Suleimanov, B. A., et al. (1998). Method for treating bottomhole zone of oil bed. RU Patent 2114291.
  10. Shakhverdiev, A. Kh., Panakhov, G. M., Suleimanov, B. A., et al. (1998). Method for treating bottom-hole zone of oil bed. RU Patent 2114292.
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DOI: 10.5510/OGP20210300527

E-mail: baghir.suleymanov@socar.az


A. A. Abbasov1, E. M. Abbasov2, Sh. Z. Ismayilov3, A. A. Suleymanov3

1SOCAR, Baku, Azerbaijan; 2Institute of Mathematics and Mechanics, Baku, Azerbaijan; 3Azerbaijan State Oil and Industry University, Baku, Azerbaijan

Waterflooding efficiency estimation using capacitance-resistance model with non-linear productivity index


A modified Capacitive Resistive Model (CRM), with a non-linear Productivity Index (PI), has been suggested to evaluate efficiency of waterflooding in heterogeneous reservoirs. CRM model is based on continuity equation between production and injection, and has several additional advantages. The technique does not require sophisticated geological and hydrodynamics numerical simulation modeling, which would require expensive computing time and based on actual hydrodynamic data. The model adequately describes depletion process and can be used for production forecasting and waterflooding mechanism. Capacitance-resistance model with non-linear productivity index has been tested against numerical model as well as actual production data. Additionally, non-linear productivity index based CRM model was compared against the CRM model with linear productivity index function. The calculations algorithm does not require building static geological models and running dynamic simulations, nor it demands extensive computational resources and time, thanks to using production and injection history only, therefore it can be deployed easily.

Keywords: waterflooding; capacitance-resistance model; non-linear productivity index; efficiency; monitoring; forecast.

A modified Capacitive Resistive Model (CRM), with a non-linear Productivity Index (PI), has been suggested to evaluate efficiency of waterflooding in heterogeneous reservoirs. CRM model is based on continuity equation between production and injection, and has several additional advantages. The technique does not require sophisticated geological and hydrodynamics numerical simulation modeling, which would require expensive computing time and based on actual hydrodynamic data. The model adequately describes depletion process and can be used for production forecasting and waterflooding mechanism. Capacitance-resistance model with non-linear productivity index has been tested against numerical model as well as actual production data. Additionally, non-linear productivity index based CRM model was compared against the CRM model with linear productivity index function. The calculations algorithm does not require building static geological models and running dynamic simulations, nor it demands extensive computational resources and time, thanks to using production and injection history only, therefore it can be deployed easily.

Keywords: waterflooding; capacitance-resistance model; non-linear productivity index; efficiency; monitoring; forecast.

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. SPE-182044-MS. In: SPE Russian Petroleum Technology Conference and Exhibition. Society of Petroleum Engineers.
  2. Vishnyakov, V., Suleimanov, B., Salmanov, A., & Zeynalov, E. (2019). Primer on enhanced oil recovery. Gulf Professional Publishing.
  3. Veliyev, E. F. (2020). Review of modern in-situ fluid diversion technologies. SOCAR Proceedings, 2, 50-66.
  4. Suleimanov, B. A., Latifov, Y. A., Veliyev, E. F. (2019). Softened water application for enhanced oil recovery. SOCAR Proceedings, 1, 19-28.
  5. 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
  6. Veliyev, E. F. (2020). Mechanisms of polymer retention in porous media. SOCAR Proceedings, 3, 126-134. 52
  7. 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.
  8. 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.
  9. 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.
  10. Suleimanov, B. A., Ismaylov, F. S., Veliyev, E. F. (2014). On the metal nanoparticles effect on the strength of polymer gels based on carboxymethylcellulose, applying at oil recovery. Oil Industry, 1, 86-88.
  11. Veliyev, E. F. (2021). Polymer dispersed system for in-situ fluid diversion. Prospecting and Development of Oil and Gas Fields, 1(78), 61-72.
  12. 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.
  13. Veliyev, E. F., Aliyev, A. A., Mammadbayli, T. E. ().Machine learning application to predict the efficiency of water coning prevention. SOCAR Proceedings, 1, 104-113.
  14. 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.
  15. Shakhverdiev, A. Kh., Panakhov, G. M., Suleimanov, B. A., et al. Method for development of oil deposit. RU Patent 2125154.
  16. Suleimanov, B.A. (1997). Slip effect during filtration of gassed liquid. Colloid Journal, 59(6), 749-753.
  17. Suleimanov, B.A. (1995). Filtration of disperse systems in a nonhomogeneous porous medium. Colloid Journal, 57(5), 704-707.
  18. Mirzajanzadeh, A. K., Khasanov, M. M., Bahtizin, R. N. (1999). Etudes on complex system modeling of oil and gas production. Non-linearity, unsteadiness, heterogeneity. Ufa: Gilem.
  19. Ahmed, T. H. (2001). Reservoir engineering handbook. Elsevier, Gulf Professional Publishing.
  20. Mirzajanzadeh, A. K., Aliyev, N. A., Yusifzade, H. B., et al. (1997). Fragments of the offshore oil and gas fields development. Baku: Elm.
  21. Al-Harrasi, A., Rathore, Y. S., Kumar, J., et al. (2011, September). Field development and waterflood management in complex clastic field in Oman - case study. SPE-145663-MS. In: SPE Asia Pacific Oil and Gas Conference and Exhibition. Society of Petroleum Engineers.
  22. Kumar, A. (1977). Strength of water drive or fluid injection from transient well test data. Journal of Petroleum & Technology, 29(11), 1497-1508.
  23. Hearn, C. L. (1983). Method analyzes injection well pressure and rate data. Oil & Gas Journal, 117-120.
  24. Chan, K. S. (1995, October). Water control diagnostic plots. SPE-30775-MS. In: SPE Annual Technical Conference and Exhibition. Society of Petroleum Engineers.
  25. Yortsos, Y. C., Choi, Y., Yang, Z., et al. (1999). Analysis and interpretation of water/oil ratio in waterfloods. SPE Journal, 4, 413-424.
  26. Lyons, W. C., Plisga, G. J. (2005). Standard handbook of petroleum & natural gas engineering. Elsevier, Gulf Professional Publishing.
  27. Albertoni, A., Lake, L. W. (2002, April). Inferring interwell connectivity from well-rate fluctuations in waterfloods. SPE-75225-MS. In: SPE/DOE Symposium on Improved Oil Recovery, Tulsa, Oklahoma. Society of Petroleum Engineers.
  28. Yousef, A. (2005). Investigating statistical techniques to infer interwell connectivity from production and injection rate fluctuations. phd dissertation. University of Texas, Austin, Texas.
  29. Yousef, A. A., Gentil, P. H., Jensen, J. L., et al. (2006). A capacitance model to infer interwell connectivity from production and injection rate fluctuations. SPE Reservoir Evaluation & Engineering, 9(6), 630-646.
  30. Kim, J. S., Lake, L. W., Edgar, T. F. (2012, May-June). Integrated capacitance-resistance model for characterizing waterflooded reservoirs. In: 2012 IFAC Workshop on Automatic Control in Offshore Oil and Gas Production. Norwegian University of Science and Technology, Trondheim, Norway.
  31. Laochamroonvorapongse, R. (2013). Advances in the development and application of a capacitance-resistance model. PhD dissertation. University of Texas, Austin, Texas.
  32. Aulisa, E., Ibragimov, A., Walton, J. R. (2009). A new method for evaluating the productivity index of nonlinear flows. SPE Journal, 14(4), 693-706.
  33. Aulisa, E., Ibragimov, A., Valko, P., Walton, J. R. (2009). Mathematical framework of the well productivity index for fast Forchheimer (non-Darcy) flows in porous media. Mathematical Models and Methods in Applied Sciences, 19(08), 1241-1275.
  34. Arnold, W. F., Laub, A. J. (1984). Generalized eigenproblem algorithms and software for algebraic riccati equations. Proceedings IEEE, 72(12), 1746-1754.
  35. Navidi, W. C. (2011). Statistics for engineers and scientists. New-York: McGraw-Hill.
  36. Sayarpour, M. (2008). Development and application of capacitance-resistive models for water/CO2 flood. PhD dissertation. University of Texas, Austin, Texas.
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DOI: 10.5510/OGP20210300528

E-mail: petrotech@asoiu.az


I. N. Ponomareva, D. A. Martyushev

Perm National Research Polytechnic University, Perm, Russian Federation

Evaluation the volume of distribution of the injected water and the interaction between injection and production wells probabilistic and statistical methods


The article describes the application of probabilistic-statistical methods for solving the urgent problem associated with determining the direction of movement of filtration flows. Today, the oil industry enterprises for these purposes use methods of hydrolistening and indicator research. These methods can most accurately assess the direction of movement of the filtration flows, but due to the high cost and duration of these studies in the Perm Krai fields are not often carried out. In this paper, we propose to study the interaction between production and injection wells by correlating the accumulated characteristics of their work. An analysis of the dynamics of the correlation coefficient between the accumulated values of water injection and liquid production performed in this way made it possible to establish qualitative indicators of the waterflooding system within the considered element of the development system. The obtained qualitative indicators of the waterflooding system demonstrate a high reliability of practical application, which is confirmed by the materials of tracer studies, as applied to the carbonate deposits of the Gagarinskoye field.

Keywords: tracer studies; oil production; water injection; filtration flows; correlation coefficient; angular coefficient; carbonate reservoir.

The article describes the application of probabilistic-statistical methods for solving the urgent problem associated with determining the direction of movement of filtration flows. Today, the oil industry enterprises for these purposes use methods of hydrolistening and indicator research. These methods can most accurately assess the direction of movement of the filtration flows, but due to the high cost and duration of these studies in the Perm Krai fields are not often carried out. In this paper, we propose to study the interaction between production and injection wells by correlating the accumulated characteristics of their work. An analysis of the dynamics of the correlation coefficient between the accumulated values of water injection and liquid production performed in this way made it possible to establish qualitative indicators of the waterflooding system within the considered element of the development system. The obtained qualitative indicators of the waterflooding system demonstrate a high reliability of practical application, which is confirmed by the materials of tracer studies, as applied to the carbonate deposits of the Gagarinskoye field.

Keywords: tracer studies; oil production; water injection; filtration flows; correlation coefficient; angular coefficient; carbonate reservoir.

References

  1. Stenkin, A. V., Kotenev, Yu. A., Sultanov, Sh. Kh., Umetbaev, V. G. (2019). Methodological rationale for increasing the production of oil reserves in fields complicated by tectonic disturbances. Bulletin of the TPU, Geo Assets Engineering, 330 (1), 214-223.
  2. Alrashdi, Z., Sayyafzadeh, M. (2019). Evalution strategy algorithm in well placement, trajectory, control and joint optimization. Journal of Petroleum Science and Engineering, 177, 1042-1058.
  3. Mukhametshin, V. V. (2018). Justification of trends in increasing the level of oil production in the Lower Cretaceous deposits of Western Siberia based on the identification of objects. Bulletin of the TPU, Geo Assets Engineering, 329 (5), 117-124.
  4. Sayfutdinov, M. A., Khakimzyanov, I. N., Petrov, V. N., et al. (2018). Studies on the presence of a hydrodynamic connection between the terrigenous Bobrikovsky and carbonate Tournaisian objects based on the geological and technological model of the field site. Georesursy, 20 (1), 2-8.
  5. Mukhametshin, V. V., Kuleshova L. S. (2019). Justification of low-productive oil deposits flooding systems in the conditions of limited information amount. SOCAR Proceedings, 2, 16-22.
  6. Jirjees, A. Y., Abdulaziz, M. (2019). Influences of uncertainty in well log petrophysics and fluid properties on well test interpretation: An application in West Al Qurna Oil Field, South Iraq. Egyptian Journal of Petroleum, 28(4), 383–392.
  7. Belhouchet, H. E., Benzagouta, M. S., Dobbi, A., et al. (2021). A new empirical model for enhancing well log permeability prediction, using nonlinear regression method: Case study from Hassi-Berkine oil field reservoir – Algeria. Journal of King Saud University - Engineering Sciences, 33(2), 136-145.
  8. Xie, W., Wang, X., Li, C., Zhou, Y. (2019). Quantitative well placement optimisation of five-spot patterns in an anisotropic oil reservoir. International Journal of Oil, Gas and Coal Technology, 21(3), 333-356.
  9. Li, Y.-F., Sun, W., Liu, X.-W., et al. (2018). Study of the relationship between fractures and highly productive shale gas zones, Longmaxi Formation, Jiaoshiba area in Eastern Sichuan. Petroleum Science, 15(3), 498-509.
  10. Ponomareva, I. N., Martyushev, D. A., Cherny, K. A. (2021). Research of interaction between expressive and producing wells based on construction of multilevel models. Bulletin of the TPU, Geo Assets Engineering, 332(2), 116–126.
  11. Song, M. (2020). Reservoir formation conditions and key technologies for exploration and development in Shengtuo oilfield in Bohai Bay Basin. Petroleum Research, 5(4), 289–303.
  12. Huang, C., Liu, G., Shi, K., et al. (2020). Hydrocarbon migration in fracture-cave systems of carbonate reservoirs under tectonic stresses: A mechanism study. Petroleum Research, 5(2), 124–130.
  13. Kassab, M. A., Abbas, A., Ghanima, A. (2020). Petrophysical evaluation of clastic Upper Safa Member using well logging and core data in the Obaiyed field in the Western Desert of Egypt. Egyptian Journal of Petroleum, 29(2), 141-153.
  14. Martyushev, D. A., Yurikov, A. (2021). Evaluation of opening of fractures in the Logovskoye carbonate reservoir, Perm Krai, Russia. Petroleum Research, 6(2), 137-143.
  15. Abbas, A. H., WanSulaiman, W. R., ZaidiJaafar, M., et al. (2020). Numerical study for continuous surfactant flooding considering adsorption in heterogeneous reservoir. Journal of King Saud University - Engineering Sciences, 32(1), 91-99.
  16. Fattah, K. A., Lashin, A. (2018). Improved oil formation volume factor (Bo) correlation for volatile oil reservoirs: An integrated non-linear regression and genetic programming approach. Journal of King Saud University - Engineering Sciences, 30(4), 398-404.
  17. ElGibaly, A., Osman, M. A. (2019). Perforation friction modeling in limited entry fracturing using artificial neural network. Egyptian Journal of Petroleum. 28(3), 297-305.
  18. Martyushev, D. A., Ponomareva, I. N., Galkin, V. I. (2021). Estimation of the reliability of determination of filtering parameters of productive formations using multi-dimensional regression analysis. SOCAR Proceedings, Special Issue 1, 50-59.
  19. Silva, T. M. D., Bela, R. V., Pesco, S., Barreto Jr., A. (2021). ES-MDA applied to estimate skin zone properties from injectivity tests data in multilayer reservoirs. Computers & Geosciences, 146, 104635.
  20. Grachev, S. I., Korotenko, V. A., Kushakova, N. P. (2020). Study on influence of two-phase filtration transformation on formation of zones of undeveloped oil reserves. Journal of Mining Institute, 241, 68-82.
  21. Hu, W., Wei, Y., Bao, J. (2018). Development of the theory and technology for low permeability reservoirs in China. Petroleum Exploration and Development, 45(4), 685-697
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DOI: 10.5510/OGP20210300529

E-mail: martyushevd@inbox.ru


S. D. Maherramova

Institute of Oil and Gas of ANAS, Baku, Azerbaijan

Improvement of efficiency of the process of extraction of condensate on gas-condensate deposits with various development modes


On the basis of mathematical modeling, the possibilities of increasing the condensate recovery coefficient at gas-condensate deposits under different development regimes are investigated. It has been established that the final condensate recovery coefficient significantly increases compared to the depletion development regime by maintaining reservoir pressure using nitrogen, also carbon dioxide, and their results are comparable to the corresponding dry gas injection results.

Keywords: permeability; porosity; pressure; condensate recovery factor; nitrogen injection.

On the basis of mathematical modeling, the possibilities of increasing the condensate recovery coefficient at gas-condensate deposits under different development regimes are investigated. It has been established that the final condensate recovery coefficient significantly increases compared to the depletion development regime by maintaining reservoir pressure using nitrogen, also carbon dioxide, and their results are comparable to the corresponding dry gas injection results.

Keywords: permeability; porosity; pressure; condensate recovery factor; nitrogen injection.

References

  1. Zakirov, S. N. (1998). Razrabotka gazovyh, gazokondensatnyh i neftegazo-kondensatnyh mestorozhdenij. Moskva: Struna.
  2. Gurevich, G. R. (1985). Sposoby povysheniya kondensatootdachi plastov. Ezhegodnik «Itogi nauki i tekhniki». Seriya «Razrabotka neftyanyh i gazovyh mestorozhdenij». T. 16. Moskva: VINITI.
  3. Abbasov, Z. YA. (1993). Metody rascheta staticheskogo dinamicheskogo zabojnogo davleniya v gazovyh i gazokondensatnyh skvazhinah. Baku: Elm.
  4. Brusilovsky A. I. (2002) Phase transformations in the development of oil and gas fields. Moscow: Grail.
  5. Feyzullayev, Kh. A., Kuliyev, E. A. (2017). Modeling of water influence on a gas-condensate layer. Automation, Telemechanization and Communication in Oil Industry, 8, 31-37.
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DOI: 10.5510/OGP20210300530

E-mail: xasay.feyzullayev@socar.az


E.T.Baspaev

«OPTIMUM» Design Institute LLP, Aktau, Kazakhstan

Efficiency improvement for removal of liquid from gas wells bottom zone


One of the effective technologies for removing liquid accumulated at the bottom of gas wells and restoring the free movement of gas is the introduction of solid surfaceactive substances (surfactants) in a spherical or cylindrical form (chemical candle) to the bottomhole, contributing to the aeration of the foam mud at the bottom of the well and its rise to daylight surface. Foam formation reduces hydrostatic pressure on the formation, enhancing well productivity. The paper addresses the results of studies on a new composition of a solid surfactant for removing liquid from the bottom of gas wells. Proceeding from the studies carried out, it can be concluded that the considered composition has a high surface activity, wetting and multifunctional protective ability. A method is proposed for delivering a solid surfactant (chemical candles) to the bottom of a directional well.

Keywords: gas wells; liquid removal; solid surfactant; chemical candles; aeration of the foam mud; directional well.

One of the effective technologies for removing liquid accumulated at the bottom of gas wells and restoring the free movement of gas is the introduction of solid surfaceactive substances (surfactants) in a spherical or cylindrical form (chemical candle) to the bottomhole, contributing to the aeration of the foam mud at the bottom of the well and its rise to daylight surface. Foam formation reduces hydrostatic pressure on the formation, enhancing well productivity. The paper addresses the results of studies on a new composition of a solid surfactant for removing liquid from the bottom of gas wells. Proceeding from the studies carried out, it can be concluded that the considered composition has a high surface activity, wetting and multifunctional protective ability. A method is proposed for delivering a solid surfactant (chemical candles) to the bottom of a directional well.

Keywords: gas wells; liquid removal; solid surfactant; chemical candles; aeration of the foam mud; directional well.

References

  1. Suleimanov, B.A. (1997). Slip effect during filtration of gassed liquid. Colloid Journal, 59(6), 749-753.
  2. Suleimanov, B.A. (1995). Filtration of disperse systems in a nonhomogeneous porous medium. Colloid Journal, 57(5), 704-707.
  3. Shakhverdiev, A. Kh., Panakhov, G. M., Suleimanov, B. A., et al. Method for development of oil deposit. RU Patent 2125154.
  4. Suleimanov, B. A., Azizov, H. F. (1995). Specific features of the flow of a gassed liquid in a porous body. Colloid Journal, 57(6), 818-823.
  5. Suleimanov, B. A., Azizov, F., Abbasov, E. M. (1998). Specific features of the gas-liquid mixture filtration. Acta mechanica, 130(1), 121-133.
  6. Vishnyakov, V., Suleimanov, B., Salmanov, A., Zeynalov, E. (2019). Primer on enhanced oil recovery. Gulf Professional Publishing.
  7. 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
  8. Veliyev, E. F. (2020). Review of modern in-situ fluid diversion technologies. SOCAR Proceedings, 2, 50-66.
  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. Veliyev, E. F. (2020). Mechanisms of polymer retention in porous media. SOCAR Proceedings, 3, 126-134.
  11. 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.
  12. 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.
  13. Kolovertnov, G. Yu., Krasnov, A. N., Kuznetsov, Yu. S., et al. (2015). Automation of the process of liquid removal from gas wells and lines. Oil and Gas Territory, 9, 70-76.
  14. Panikarovskii, E.V., Panikarovskii, V. V., Vaganov, Y. V. (2019). Improving efficiency of application foam sheets to remove liquid from gas wells. Oil and Gas Studies, 3, 54-63.
  15. fon Pionski, K., Sejdel, SH., Veuto, D. K., Veuto, D. (2003). Ustrojstvo dlya avtomaticheskogo vvoda bruskov myla obespechivaet uvelichenie dobychi gaza. Neft' mira, 1, 45-46.
  16. Maximize production by continuously dropping soap sticks throughout the day and night. https://jandjsolutionsllc.com/products/automatic-soap-stick-launcher/
  17. Kondrat, R. M., Bileckij, M. M. (1980). Sovershenstvovanie metodov ekspluatacii obvodnivshihsya gazovyh skvazhin. Razrabotka i ekspluataciya gazovyh i gazokondensatnyh mestorozhdenij, 9, 56.
  18. Soap Sticks. https://jandjsolutionsllc. com/products/soap-sticks/
  19. Soft Soap Sticks. http://fisher-stevens. com/index.html
  20. Soapsticks. https://foamtechinc. com/products/soapsticks/
  21. Zakirov, N. N., Krotov, P. S., Yushkov, A. Yu. et al. (2007). Bottom hole constructional choice in senoman horizontal wells. Bureniye i Neft, 5, 30-31.
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DOI: 10.5510/OGP20210300531

E-mail: baspaev1989@gmail.com


E. F. Veliyev

«OilGasScientificResearchProject» Institute, SOCAR, Baku, Azerbaijan

Application of amphiphilic block-polymer system for emulsion flooding


The paper presents the developed composition of an amphiphilic block polymer that forms a stable emulsion system. The presented block polymer composition also possesses reversible-thermal gel-forming properties, which allows to consider it as an effective working agent on deep fluid diversion purposes. Amphiphilic polymer systems traditionally used in the oil industry are not very stable in high-salinity environments. For this purpose, a block polymer formulation was developed which eliminates this disadvantage. This work presents the results of the research on the effect of the block polymer on the surface tension values in saline environments. The main results of the presented work are as follows: emulsion stability increases with concentration increase of block polymer used as emulsifier; determination of the critical concentration of aggregation above which a transition from macro to micro emulsions occurs; and increase of oil recovery by 37 % with injection of 0.25 pore volume emulsion slug.

Keywords: oil recovery factor; emulsion flooding; block-polymer; critical aggregation concentration.

The paper presents the developed composition of an amphiphilic block polymer that forms a stable emulsion system. The presented block polymer composition also possesses reversible-thermal gel-forming properties, which allows to consider it as an effective working agent on deep fluid diversion purposes. Amphiphilic polymer systems traditionally used in the oil industry are not very stable in high-salinity environments. For this purpose, a block polymer formulation was developed which eliminates this disadvantage. This work presents the results of the research on the effect of the block polymer on the surface tension values in saline environments. The main results of the presented work are as follows: emulsion stability increases with concentration increase of block polymer used as emulsifier; determination of the critical concentration of aggregation above which a transition from macro to micro emulsions occurs; and increase of oil recovery by 37 % with injection of 0.25 pore volume emulsion slug.

Keywords: oil recovery factor; emulsion flooding; block-polymer; critical aggregation concentration.

References

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  6. Vishnyakov, V., Suleimanov, B., Salmanov, A., Zeynalov, E. (2019). Primer on enhanced oil recovery. Gulf Professional Publishing.
  7. Suleimanov, B. A., Ismaylov, F. S., Veliyev, E. F. (2014). On the metal nanoparticles effect on the strength of polymer gels based on carboxymethylcellulose, applying at oil recovery. Oil Industry, 1, 86-88.
  8. 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.
  9. Suleimanov, B. A., Latifov, Y. A., Veliyev, E. F. (2019). Softened water application for enhanced oil recovery. SOCAR Proceedings, 1, 19-28.
  10. Veliyev, E. F. (2020). Review of modern in-situ fluid diversion technologies. SOCAR Proceedings, 2, 50-66.
  11. Kamal, M. S., Adewunmi, A. A., Sultan, A. S., et al. (2017). Recent advances in nanoparticles enhanced oil recovery: rheology, interfacial tension, oil recovery, and wettability alteration. Journal of Nanomaterials, 2017.
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  13. Joonaki, E., Ghanaatian, S. J. P. S. (2014). The application of nanofluids for enhanced oil recovery: effects on interfacial tension and coreflooding process. Petroleum Science and Technology, 32(21), 2599-2607.
  14. Saha, R., Uppaluri, R. V., Tiwari, P. (2018). Effects of interfacial tension, oil layer break time, emulsification and wettability alteration on oil recovery for carbonate reservoirs. Colloids and Surfaces A: Physicochemical and Engineering Aspects, 559, 92-103.
  15. 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.
  16. Veliyev, E. F. (2020). Mechanisms of polymer retention in porous media. SOCAR Proceedings, 3, 126-134.
  17. 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.
  18. 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.
  19. Veliyev, E. F. (2021). Polymer dispersed system for in-situ fluid diversion. Prospecting and Development of Oil and Gas Fields, 1(78), 61-72.
  20. 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.
  21. Veliyev, E. F., Aliyev, A. A., Mammadbayli, T. E. (2021).Machine learning application to predict the efficiency of water coning prevention. SOCAR Proceedings, 1, 104-113.
  22. Suleimanov, B. A., Dyshin, O. A., Veliyev, E. F. (2016, October). Compressive strength of polymer nanogels used for enhanced oil recovery EOR. In: SPE Russian Petroleum Technology Conference and Exhibition. Society of Petroleum Engineers.
  23. Naghiyeva, N. V. (2020). Colloidal dispersion gels for align the injectivity profile of injection wells. SOCAR Proceedings, 2, 67-77.
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  25. Bryan, J. L., Kantzas, A. (2007, November). Enhanced heavy-oil recovery by alkali-surfactant flooding. SPE-110738-MS. In: SPE Annual Technical Conference and Exhibition. Society of Petroleum Engineers.
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  27. Larson, R. G. (1978). Analysis of the physical mechanisms in surfactant flooding. SPE Journal, 18(01), 42-58.
  28. Liu, S., Zhang, D., Yan, W., et al. (2008). Favorable attributes of alkaline-surfactant-polymer flooding. SPE Journal, 13(01), 5-16.
  29. Chang, H. L., Zhang, Z. Q., Wang, Q. M., et al. (2006). Advances in polymer flooding and alkaline/ surfactant/polymer processes as developed and applied in the People's Republic of China. SPE Journal of Petroleum Technology, 58(02), 84-89.
  30. Vargo, J., Turner, J., Bob, V., et al. (2000). Alkaline-surfactant-polymer flooding of the Cambridge Minnelusa field. SPE Reservoir Evaluation & Engineering, 3(06), 552-558.
  31. Li, G. Z., Mu, J. H., Li, Y., Yuan, S. L. (2000). An experimental study on alkaline/surfactant/polymer flooding systems using nature mixed carboxylate. Colloids and Surfaces A: Physicochemical and Engineering Aspects, 173(1-3), 219-229.
  32. Kon, W., Pitts, M. J., Surkalo, H. (2002, October). Mature waterfloods renew oil production by alkalinesurfactant-polymer flooding. SPE-78711-MS. In: SPE Eastern Regional Meeting. Society of Petroleum Engineers.
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  36. Guo, H., Li, Y., Wang, F., Gu, Y. (2018). Comparison of strong-alkali and weak-alkali ASP-flooding field tests in Daqing oil field. SPE Production & Operations, 33(02), 353-362.
  37. Denney, D. (2013). Progress and effects of ASP flooding. SPE Journal of Petroleum Technology, 65(01), 77-81.
  38. Guillen, V. R., Carvalho, M. S., Alvarado, V. (2012). Pore scale and macroscopic displacement mechanisms in emulsion flooding. Transport in Porous Media, 94(1), 197-206.
  39. Demikhova, I. I., Likhanova, N. V., Perez, J. R. H., et al. (2016). Emulsion flooding for enhanced oil recovery: Filtration model and numerical simulation. Journal of Petroleum Science and Engineering, 143, 235-244.
  40. Kumar, R., Dao, E., Mohanty, K. K. (2010, April). Emulsion flooding of heavy oil. SPE-129914-MS. In: SPE Improved Oil Recovery Symposium. Society of Petroleum Engineers.
  41. Ning, J., Wei, B., Mao, R., et al. (2018). Pore-level observations of an alkali-induced mild O/W emulsion flooding for economic enhanced oil recovery. Energy & Fuels, 32(10), 10595-10604.
  42. Pei, H., Shu, Z., Zhang, G., et al. (2018). Experimental study of nanoparticle and surfactant stabilized emulsion flooding to enhance heavy oil recovery. Journal of Petroleum Science and Engineering, 163, 476-483.
  43. Carvalho, M. S., Alvarado, V. (2014). Oil recovery modeling of macro-emulsion flooding at low capillary number. Journal of Petroleum Science and Engineering, 119, 112-122.
  44. Pei, H., Zhang, G., Ge, J., et al. (2017). Study of polymer-enhanced emulsion flooding to improve viscous oil recovery in waterflooded heavy oil reservoirs. Colloids and Surfaces A: Physicochemical and Engineering Aspects, 529, 409-416.
  45. Alizadeh, S., Suleymani, M. (2020). A mechanistic study of emulsion flooding for mobility control in the presence of fatty acids: effect of chain length. Fuel, 276, 118011.
  46. Wei, B., Ning, J., Shang, J., Pu, W. (2018, March). An experimental validation of a smart emulsion flooding for economic chemical EOR. SPE-190352-MS. In: SPE EOR Conference at Oil and Gas West Asia. Society of Petroleum Engineers.
  47. Zhou, Y., Yin, D., Chen, W., et al. (2019). A comprehensive review of emulsion and its field application for enhanced oil recovery. Energy Science & Engineering, 7(4), 1046-1058.
  48. Sharma, T., Suresh Kumar, G., Sangwai, J. S. (2014). Enhanced oil recovery using oil-in-water (o/w) emulsion stabilized by nanoparticle, surfactant and polymer in the presence of NaCl. Geosystem Engineering, 17(3), 195-205.
  49. Pei, H. H., Zhang, G. C., Ge, J. J., et al. (2015, June). Investigation of nanoparticle and surfactant stabilized emulsion to enhance oil recovery in waterflooded heavy oil reservoirs. SPE-174488-MS. In: SPE Canada heavy oil technical conference. Society of Petroleum Engineers.
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DOI: 10.5510/OGP20210300532

E-mail: elchinf.veliyev@socar.az


K. I. Matiyev1, A. M. Samedov1, F. M. Akhmedov2

1«OilGasScientificResearchProject» Institute, SOCAR, Baku, Azerbaijan; 2SOCAR Midstream Operations Limited, Baku, Azerbaijan

Reduction of acidity and corrosive activity of an oilstock


A new composition has been developed to reduce the acid number and corrosive activity of oilstock, which includes hydroxides of group 1A elements, substances with demulsifying properties, as well as surfactants that create additional auxiliary properties. The activity of the developed compositions to reduce acidity and corrosion activity was studied on various types of oils taken from the Dubendi site.

Keywords: naphthenic acids; acid number; corrosive activity; surfactant; oilstock.

A new composition has been developed to reduce the acid number and corrosive activity of oilstock, which includes hydroxides of group 1A elements, substances with demulsifying properties, as well as surfactants that create additional auxiliary properties. The activity of the developed compositions to reduce acidity and corrosion activity was studied on various types of oils taken from the Dubendi site.

Keywords: naphthenic acids; acid number; corrosive activity; surfactant; oilstock.

References

  1. Turnbull, A., Slavcheva, E., Shone, B. (1998). Factors controlling naphthenic acid corrosion. Corrosion, 54 (11), 922-930.
  2. Oliveira, E. C., Filho, P. J. S., Piatnicki, C. M. S., Caramão, E. B. (2006). Analysis of tertbutyldimethylsilyl derivatives in heavy gas oil from brazilian naphthenic acids by gas chromatography coupled to mass spectrometry with electron impact ionization. Journal of Chromatography A, 1105(1–2), 95-105.
  3. Philip R. Petersen, P. R., Robbins, F. P., Winston, W. G. (1990). Naphthenic acid corrosion inhibitors. US Patent 5182013.
  4. Edmondson, J. G. (1985). Method of inhibiting propionic acid corrosion in distillation units. US Patent 4647366.
  5. Verachtert, T. A. (2001). Trace acid removal in the pretreatment of petroleum distillate. US Patent 4199440.
  6. Sartori, G., Sehvidzh, D. U., Gorbehti, M. L., et al. (1996). Method of reducing acidity and corrosion activity of crude oil stock. RU Patent 2167909.
  7. Suleimanov, B. A., Metiyev, K. I., Samedov, A. M., Akhmedov, F. M. (2021). Sposob umen'sheniya kislotnosti i korrozionnoj aktivnosti neftyanogo syr'ya. Zayavka na poluchenie Evrazijskogo patenta na izobretenie № 2021/020(AZ).
  8. Najivana, P., Vaziri, A. (2015). Optimizatijn of demulsifer formulation for separation of water from crudе oil emulsions. Brazilian Journal of Chemical Engineering, 32, 107-118.
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DOI: 10.5510/OGP20210300533

E-mail: kazim.metiyev@socar.az


V. A. Suleymanov1, N. A. Buznikov2

1Gubkin Russian State University of Oil and Gas (National Research University), Moscow, Russia; 2«Gazprom VNIIGAZ» LLC, Razvilka, Moscow Region, Russia

Effects of the transported fluid composition and the pipeline route profile


The modes of the transport of gas with low condensate content in an extentional subsea pipeline with a hilly terrain profile of the route are studied. Flow assurance in a pipeline is provided if the gas flow rate exceeds a certain threshold value called the turndown rate. It is shown that for a pipeline with a complex route profile, the transport of a two-phase hydrocarbon fluid (gas and condensate) is preferable to provide the flow assurance, since the presence of even a small amount of the water and hydrate inhibitor in the fluid leads to significant increase of the turndown rate. It is found that to expand the range of the safe pipeline operation, the use of methanol as a hydrate inhibitor is preferable over glycols. The performed hydraulic calculations show that the alignment of the pipeline route under construction may result in a decrease in the turndown rate for the transport of two-phase fluid and multiphase fluid containing a water solution of methanol.

Keywords: subsea pipeline; natural gas; gas condensate; hydrate inhibitor; multiphase fluid; liquid holdup; turndown rate.

The modes of the transport of gas with low condensate content in an extentional subsea pipeline with a hilly terrain profile of the route are studied. Flow assurance in a pipeline is provided if the gas flow rate exceeds a certain threshold value called the turndown rate. It is shown that for a pipeline with a complex route profile, the transport of a two-phase hydrocarbon fluid (gas and condensate) is preferable to provide the flow assurance, since the presence of even a small amount of the water and hydrate inhibitor in the fluid leads to significant increase of the turndown rate. It is found that to expand the range of the safe pipeline operation, the use of methanol as a hydrate inhibitor is preferable over glycols. The performed hydraulic calculations show that the alignment of the pipeline route under construction may result in a decrease in the turndown rate for the transport of two-phase fluid and multiphase fluid containing a water solution of methanol.

Keywords: subsea pipeline; natural gas; gas condensate; hydrate inhibitor; multiphase fluid; liquid holdup; turndown rate.

References

  1. Bai, Y., Bai, Q. (2005). Subsea pipelines and risers. Amsterdam: Elsevier.
  2. Suleymanov, V. A. (2011). Pipeline transportation of the FPU-type marine platform products. Gazovaya promyshlennost', 10, 90–94.
  3. Barrau, B. (2000). Profile indicator helps predict pipeline holdup, slugging. Oil & Gas Journal, 98(8), 58–62.
  4. Soave, G. (1972). Equilibrium constants from a modified Redlich–Kwong equation of state. Chemical Engineering Science, 27(6), 1197–1203.
  5. Péneloux, A., Rauzy, E., Fréze, R. (1982). A consistent correlation for Redlich–Kwong–Soave volumes. Fluid Phase Equilibria, 8(1), 7–23.
  6. Bendiksen, K. H., Malnes, D., Moe, R., Nuland, S. (1991). The dynamic two-fluid model OLGA: Theory and applications. SPE Production & Engineering, 6(2), 171–180.
  7. Taitel, Y., Barnea, D., Brill, J. P. (1995). Stratified three phase flow in pipes. International Journal of Multiphase Flow, 21(1), 53–60.
  8. Khor, S. H., Mendes-Tatsis, M. A., Hewitt, G. F. (1997). One-dimensional modeling of phase holdups in three-phase stratified flow. International Journal of Multiphase Flow, 23 (5), 885–897.
  9. Buznikov, N. A., Suleymanov, V. A. (2014). Aqueous hydrate inhibitor accumulation and removal profiles under offshore pipeline initial filling. Gazovaya promyshlennost', 8, 34–37
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DOI: 10.5510/OGP20210300534

E-mail: suleymanov.v@gubkin.ru


A. A. Gasimov1, G. B. Hajiyev2

1SOCAR, Baku, Azerbaijan; 2Azerbaijan State University of Economics, Baku, Azerbaijan

On management evaluation of oil-gas industry enteprises in modern economic condition


The article shows the history of the oil industry in our country and its current situation. Since the establishment of the State Oil Company of the Republic of Azerbaijan (SOCAR) to date, a number of successes have been achieved, especially since the launch of a new oil strategy in our country. Thus, during the years of independence new oil and gas fields were discovered, modern technologies were mastered, new agreements were signed with international oil companies, qualified human resources were developed and other achievements were made. International financial reporting and risk management in oil and gas industry enterprises were assessed. The application of the advanced work and projects mentioned in the article has shown that SOCAR has also strengthened its position in the international financial market and benefited from new banking products. As a result, oil and gas industry enterprises with international financial reporting have a favorable investment climate, which allows for efficient management of competitive production.

Keywords: oil-gas industry; enterprise; development; management; finance; report; riscs.

The article shows the history of the oil industry in our country and its current situation. Since the establishment of the State Oil Company of the Republic of Azerbaijan (SOCAR) to date, a number of successes have been achieved, especially since the launch of a new oil strategy in our country. Thus, during the years of independence new oil and gas fields were discovered, modern technologies were mastered, new agreements were signed with international oil companies, qualified human resources were developed and other achievements were made. International financial reporting and risk management in oil and gas industry enterprises were assessed. The application of the advanced work and projects mentioned in the article has shown that SOCAR has also strengthened its position in the international financial market and benefited from new banking products. As a result, oil and gas industry enterprises with international financial reporting have a favorable investment climate, which allows for efficient management of competitive production.

Keywords: oil-gas industry; enterprise; development; management; finance; report; riscs.

References

  1. Aliyev, I. G. (2003). Caspian oil of Azerbaijan. Moscow: Izvestia.
  2. Abdullaev, R., Gasimov, S. (2017). Practical guide to improving the operating activities efficiency of an oil and gas enterprise. Moscow: Nedra.
  3. Aliyev, N. A. (1994). The history of oil in Azerbaijan. Azerbaijan International, USA, 2, 22-23.
  4. SOCAR (2019). SOCAR Annual report – 2018. Sustainability report. Baku: SOCAR.
  5. Tagıyev, C. O. (2003). Azerbaijan oil and oil pipelines-endof XX century-beginning of XXI. Disseration of PhD. Baku.
  6. Annual report (2019). Annual report of Transparency Commission in Production Industry of Azerbaijan Republic. Baku.
  7. www.e-qanun.az
  8. www.president.az
  9. Jamal, M., Al-Mufarej, M., Al-Mutawa, M., et al. (2013, October). Effective well management in Sabriyah intelligent digital oilfield. SPE-167273-MS. In: SPE Kuwait Oil and Gas Show and Conference held in Mishref, Kuwait.
  10. Davidenko, L. M., Miller, A. Е. (2016). Technological integration of the industrial enterprises of old industrial regions. In: North-East Asia Academic Forum (Publication of scientific articles). China: Harbin University of Commerce, 1(11), 94 – 97.
  11. Davidenko, L. M., Miller, A. E., Miller, N. V. (2015). Formation of integrated industrial companies under current conditions. Asian Social Science, 11(19), 70-81.
  12. Karnauhov, A. A. (2014). Formirovanie effektivnogo mekhanizma realizacii investicionnyh proektov v neftegazovom stroitel'stve: Discertaciya na soiskanie uchenoj stepeni kandidata ekonomicheskih nauk. Moskva.
  13. Transparency report (2019). Summary report of Transparency Commission in Production Industry in Azerbaijan Republic. Baku, 2019, p. 34
  14. SOCAR (2019). SOCAR Annual report – 2018. Baku: SOCAR.
  15. SOCAR (2019). SOCAR Annual report – 2018.Financal statement. Baku: SOCAR.
  16. www.socar.az
  17. http://socar.az/socar/assets/documents/az/socar-financialreports/Maliyye.hesabat.2018.pdf
  18. Abdullaev, R., Gasimov, S. (2017). The history of SOCAR transformation. Baku.
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DOI: 10.5510/OGP20210300535

E-mail: anver.qasimov@socar.az