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.

Alaa S. Al-Rikaby1,2, Mohammed S. Al-Jawad1, Osama S. Doohe3

1College of Engineering, University of Baghdad, Baghdad, Iraq; 2College of Engineering, Al-Ayen Iraqi University, Thi-Qar, Iraq; 3Oil Exploration Company, Iraqi Ministry of Oil, Baghdad, Iraq

Construction of a comprehensive static model based on the probability of reef and fault for carbonate reservoirs


Static model construction is the crucial first stage to constructing a dynamic model for any reservoir, and it is here that the significance of this work becomes evident. The primary objective of this paper was to identify the distribution of petrophysical properties throughout the carbonate reservoir and the initial oil-in-place calculation to assess the viability of working on reservoir modeling and the detection and resolution of reservoir problems, the most important of which is the difference in bubble pressure values within the same formation by verifying the presence of a fault or reef that led to that problem. The static model will be built based on two possibilities, reef and fault, to verify the correct possibility by historical matching with no difference in the distribution of petrophysical properties and the calculation of oil in place in both cases. The significance of developing this field lies in the issue of bubble point discrepancy in carbonate formation by verifying the presence of faults or not because it may be a significant cause of that discrepancy. Several studies were conducted in this formation, where the initial oil in place was calculated according to the available data, among which oil-water contact was one of the most uncertain parameters for stock tank oil initially in place calculation. As a result of drilling more we lls and using modern well logging, a deeper OWC level was adopt ed than in previous studies, which led to a significant increase in the oil used initially, mainly on the eastern side of this formation.

Keywords: carbonate reservoir; static model; seismic interpretation; fault; reef; oil initially in place.

Date submitted: 21.01.2025     Date accepted: 14.04.2025

Static model construction is the crucial first stage to constructing a dynamic model for any reservoir, and it is here that the significance of this work becomes evident. The primary objective of this paper was to identify the distribution of petrophysical properties throughout the carbonate reservoir and the initial oil-in-place calculation to assess the viability of working on reservoir modeling and the detection and resolution of reservoir problems, the most important of which is the difference in bubble pressure values within the same formation by verifying the presence of a fault or reef that led to that problem. The static model will be built based on two possibilities, reef and fault, to verify the correct possibility by historical matching with no difference in the distribution of petrophysical properties and the calculation of oil in place in both cases. The significance of developing this field lies in the issue of bubble point discrepancy in carbonate formation by verifying the presence of faults or not because it may be a significant cause of that discrepancy. Several studies were conducted in this formation, where the initial oil in place was calculated according to the available data, among which oil-water contact was one of the most uncertain parameters for stock tank oil initially in place calculation. As a result of drilling more we lls and using modern well logging, a deeper OWC level was adopt ed than in previous studies, which led to a significant increase in the oil used initially, mainly on the eastern side of this formation.

Keywords: carbonate reservoir; static model; seismic interpretation; fault; reef; oil initially in place.

Date submitted: 21.01.2025     Date accepted: 14.04.2025

References

  1. Baker, H. A., Al-Rikaby, A. S, Salih, I. S. (2019). evaluation of formation capacity and skin phenomena of Mishrif reservoir - Garraf oil field. IOP Conference Series: Materials Science and Engineering, 579, 012039.
  2. Baker, H. A., Al-Rikaby, A. S., (2017). Reservoir characterizations and reservoir performance of Mishrif formation in Amara oil field. Journal of Engineering - University of Baghdad, 23(12), 33-50.
  3. Abbas, L. K., Mahdi, T. A., (2020). Reservoir modeling of Mishrif formation in Majnoon oil field, Southern Iraq. Iraqi Geological Journal, 53, 89-101.
  4. Witter, J. B., Siler, D. L., Faulds, J. E., et al. (2016). 3D geophysical inversion modeling of gravity data to test the 3D geologic model of the Bradys geothermal area, Nevada, USA. Geothermal Energy, 4, 14.
  5. Al-Rikaby, A. S, Al-Jawad, M. S. (2024). Unlocking the mysteries of the Mishrif formation: seismic data reinterpretation and structural analysis for reservoir performance optimization in the Garraf oil field, Southern Iraq. Iraqi Geological Journal, 57(1B), 111–121.
  6. Abdulredah, S. K., Al-Jawad, M. S. (2024). Building 3D geological model using non-uniform gridding for Mishrif reservoir in Garraf oilfield. Petroleum Science and Technology, 42(7), 809-827.
  7. Aziz, Q. A, Hussein, H. A. (2021). Mechanical rock properties estimation for carbonate reservoir using laboratory measurement: A case study from Jerib, Khasib and Mishrif formations in Fauqi oil field. The Iraqi Geological Journal, 54(1E), 88-102.
  8. Hashim, N. S., Zakaria, A. F., Ishak, N. A., et al. (2017). An innovative approach towards improving the relationship between flow zone indicators with lithofacies: A case study in carbonate oil field, Middle East. SPE-186005-MS. In: The SPE Reservoir Characterisation and Simulation Conference and Exhibition, Abu Dhabi, UAE.
  9. Al-Rikaby, A. S., Al-Jawad, M. S. (2024). Identification of reservoir flow zone & permeability estimation: review paper. Egyptian Journal of Petroleum, 33(1), 1-21.
  10. Al-Jawad, M. S, Kareem, K. A. (2016). Geological model of Khasib reservoir-central area/East Baghdad field. Iraqi Journal of Chemical and Petroleum Engineering, 17(3), 1-10.
  11. Al-Mimar, H. S, Awadh, S. M., Al-Yaseri, A. A., et al. (2018). Sedimentary units-layering system and depositional model of the carbonate Mishrif reservoir in Rumaila oilfield, Southern Iraq. Modeling Earth Systems and Environment, 4, 1449-1465.
  12. Al-Jawad, M. S., Al-Rikaby, A. S. (2024). Decoding Complexities: seismic, geological, and dynamic modeling of fault and reef influence on bubble point variations. Geotechnical and Geological Engineering, 42(8), 6979-6995.
  13. Sheriff, R. E., Geldart, L. P. (1995). Exploration of seismology. Cambridge University Press. Petronas, c. I. H. (2021). Garraf final development plan (FDP), unpublished study.
  14. Petronas, c. I. H. (2017). Garraf final development plan (FDP), unpublished study.
  15. Al-Rikaby, A. S., Al-Jawad, M. S. (2024). Investigating the bubble point pressure discrepancy by history matching for Mishrif reservoir, Southern Iraqi oil field. Iraqi Geological Journal, 57(1C), 92–100.
  16. Al-Rikaby, A. S., Al-Jawad, M. S. (2025). A novel method to recognise faults and reefs from history matching of gas production- case study: Mishrif reservoir, Southern Iraq. Iraqi Journal of Science, 66(1).
  17. Burgess, P. M., Winefield, P., Minzoni, M., et al. (2013). Methods for identification of isolated carbonate buildups from seismic reflection data Identification of isolated carbonate buildups from seismic reflection data. AAPG Bulletin, 97(7), 1071-1098.
  18. Xiao, Z., Wei, Z., Tang, Z., et al. (2022). Integrated geologic modeling of fault-block reservoir: a case study of Ss oil field. Geofluids. In: Special Issue: New advances in the sustainability of unconventional oil and gas resources.
  19. Al-Rikaby, A. S., Alameedy, U. S., Alali, N., et al. (2024). An approach to deciphering the properties and performance of heterogeneous carbonate rocks in the Amara oilfield utilizing 3d reservoir modeling. SOCAR Proceedings, 4, 51-58.
  20. Worthington, P. F. (2010). Net pay: what is it? What does it do? How do we quantify it? How do we use it? SPE-123561-PA. SPE Reservoir Evaluation & Engineering, 13(05), 812–822.
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DOI: 10.5510/OGP20250201059

E-mail: alaa.awad2108p@coeng.uobaghdad.edu.iq


Rayan Abdul-Haq Ahmed

College of Science, University of Mosul, Mosul, Iraq

Reservoir characterization of the Oligocene units and Jeribe formation in Khabaz oilfield


The study investigates the petrophysical properties and reservoir characteristics of the Oligocene units and Jeribe formation of the Khabaz Oilfield, northern Iraq, focusing on well A1, for the depths between 2234.97 and 2460 meters. The Jeribe formation is of Early Miocene, has been identified as a significant hydrocarbon reservoir. The interplay between dolomite and limestone influence permeability and porosity. Unlike limestone reservoirs, whose relationships are linear, dolomite reservoirs exhibit complex relationships between porosity and permeability due to the change of rock volume and porosity shape. The study employs gamma-ray, neutron, density, sonic, and resistivity logs, along with other well log data from A1 and A2 wells, for analyzing shale volume, porosity, and fluid saturation. The findings divide the Jeribe formation and Oligocene formation into subzones (A, B, BE, E Units) based on calculated porosity. That indicates the reservoir quality ranges from fair to very good, with effective porosity being an important factor affecting permeability. Neutron-density and M-N cross plots are utilized to delineate various lithological features, supporting the idea that limestone and dolomite are the main components of the reservoir. The results reveal that the dolomitic composition of the Jeribe formation has moderate permeability, while micro-fractures in Unit B enhance permeability significantly. The study highlights the critical role of effective porosity in enhancing fluid flow potential. This will provide valuable insights for planning hydrocarbon development and investment strategies of Khabaz Oilfield. Overall, this research emphasizes the importance of the comprehensive petrophysical analysis in understanding reservoir static and dynamic properties supporting and optimizing resource management.

Keywords: petrophysical properties; reservoir characterization; Oligocene units and Jeribe formation.

Date submitted: 30.01.2025     Date accepted: 16.04.2025

The study investigates the petrophysical properties and reservoir characteristics of the Oligocene units and Jeribe formation of the Khabaz Oilfield, northern Iraq, focusing on well A1, for the depths between 2234.97 and 2460 meters. The Jeribe formation is of Early Miocene, has been identified as a significant hydrocarbon reservoir. The interplay between dolomite and limestone influence permeability and porosity. Unlike limestone reservoirs, whose relationships are linear, dolomite reservoirs exhibit complex relationships between porosity and permeability due to the change of rock volume and porosity shape. The study employs gamma-ray, neutron, density, sonic, and resistivity logs, along with other well log data from A1 and A2 wells, for analyzing shale volume, porosity, and fluid saturation. The findings divide the Jeribe formation and Oligocene formation into subzones (A, B, BE, E Units) based on calculated porosity. That indicates the reservoir quality ranges from fair to very good, with effective porosity being an important factor affecting permeability. Neutron-density and M-N cross plots are utilized to delineate various lithological features, supporting the idea that limestone and dolomite are the main components of the reservoir. The results reveal that the dolomitic composition of the Jeribe formation has moderate permeability, while micro-fractures in Unit B enhance permeability significantly. The study highlights the critical role of effective porosity in enhancing fluid flow potential. This will provide valuable insights for planning hydrocarbon development and investment strategies of Khabaz Oilfield. Overall, this research emphasizes the importance of the comprehensive petrophysical analysis in understanding reservoir static and dynamic properties supporting and optimizing resource management.

Keywords: petrophysical properties; reservoir characterization; Oligocene units and Jeribe formation.

Date submitted: 30.01.2025     Date accepted: 16.04.2025

References

  1. Al Kattan, W., Al Jawad, S. N., Jomaah, H. A. (2018). Cluster analysis approach to identify rock type in tertiary reservoir of Khabaz oil field case study. Iraqi Journal of Chemical and Petroleum Engineering, 19(2), 9–13.
  2. Al‐Ameri, T. K., Zumberge, J., Markarian, Z. M. (2011). Hydrocarbons in the Middle Miocene Jeribe formation, Dyala region, NE Iraq. Journal of Petroleum Geology, 34(2),199–216.
  3. Alameedy, U., Almomen, A. T., Abd, N. (2023). Evaluating machine learning techniques for carbonate formation permeability prediction using well log data. Iraqi Geological Journal, 56(1),175–187.
  4. Al-Yaseri, A. Z., Sattam, M., Alameedy, U. S. (2013). Improve permeability prediction for one of Iraqi Carbonate oil reservoir. Journal of University of Babylon, 21, 1289–1300.
  5. Ehrenberg, S. N., Eberli, G. P., Keramati, M., et al. (2006). Porosity-permeability relationships in interlayered limestone-dolostone reservoirs. American Association of Petroleum Geologists Bulletin, 90(1), 91–114.
  6. Alameedy, U., Almomen, A. (2016). Diagnosing Complex Flow Characteristics of Mishrif Formation in Stimulated Well Using Production Logging Tool. Journal of Petroleum Research and Studies, 6(2), 93–104.
  7. Al-Mozan, H. D., Al-Jawad, M. S. (2020). Reservoir modeling for mishrif formation in Nasiriyah oilfield. Iraqi Geological Journal, 53(1Е), 1–15.
  8. Kargarpour, M. A. (2020). Carbonate reservoir characterization: an integrated approach. Journal of Petroleum Exploration and Production Technology, 10(7), 2655–2667.
  9. Sadeq, D. J., Almomen, A., Hamad, H. H., Alameedy, U. (2024). Exploring the impact of petrophysical uncertainties on recoverable reserves: a case study. Iraqi Geological Journal, 57(1), 47–61.
  10. N. O. C. A. North Oil Company. (1989). Geological and petrophysical reports of Khabaz oil field. In: Geological and Petrophysical Reports of Khabaz Oil Field.
  11. Al-Ansari, N., Sissakian, V. K., Adamo, N., et al. (2020). Hydrogeology of the Mesopotamian Plain: a critical review. Journal of Earth Sciences and Geotechnical Engineering, 10(4), 111–124.
  12. Jassim, S. Z., Goff, J. C. (2006). Geology of Iraq. Brno: Dolin, Prague and Moravian Museum.
  13. Bellen, R.C., Dunnington, H.V., (1959) Lexique stratigraphique international: Asie, Iraq. Centre National de la Recherche Scientifique, 3(10).
  14. Abdula, R. A., Hussein, H. S., Hamad, M. S., et at. (2024). Reservoir characterization of the Paleogene Khurmala Formation in Tawke and Shaqlawa Areas, Kurdistan Region of Iraq. Iraqi Geological Journal, 57(1C), 62–77.
  15. Al-Ameri, T. K., Pitman, J., Naser, M. E., et at. (2011). Programed oil generation of the Zubair Formation, Southern Iraq oil fields: results from Petromod software modeling and geochemical analysis. Arabian Journal of Geosciences, 4, 1239–1259.
  16. Schlumberger (1997). Schlumberger log interpretation charts. SMP-7006, Schlumberger.
  17. Alameedy, U., Farman, G. M., Al-Tamemi, H. (2023). Mineral Inversion approach to improve Ahdeb oil field’s mineral classification. Iraqi Geological Journal, 56(2), 102–113.
  18. Schlumberger (2010). Reservoir Engineering Course Petrel 2010. 2010th ed, Schlumberger.
  19. Espinoza, J. (2013). Basic well log analysis introduction. Oslo: Slideshare.
  20. Schlumberger (1989). Log interpretation: principles and application. Schlumberger Educational Services, Houston, SMP-7017.
  21. Larionov, V. V. (1969). Borehole radiometry. Moscow: Nedra.
  22. North, F. K. (1985). Petroleum geology. Boston: George Allen & Unwin Ltd.
  23. Fertl, W. H. (1981). Openhole Crossplot concepts A powerful technique in well log analysis. Journal of PetroleumTechnology, 33(3), 535–549.
  24. Schlumberger (1989). Log interpretation: principles and application. Schlumberger Educational Services, Houston, SMP-7017.
  25. Speight, J. G. (2016). Introduction to enhanced recovery methods for heavy oil and tar sands. Houston: Gulf ProfessionalPublishing.
  26. Asquith, G., Krygowski, D., Henderson, S., et al. (2004). Basic well log analysis. American Association of Petroleum Geologists, 16
  27. Sierra, O. (1984). Fundamentals of well log interpretation, the acquisition of logging data. Amsterdam: Elsevier Science Publishing Company Inc.
  28. Tonietto, S. N., Smoot, M. Z., Pope, M. (2014). Pore type characterization and classification in carbonate reservoirs. Search and Discovery Article, 41432, 2–5.
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DOI: 10.5510/OGP20250201060

E-mail: rayyanhamoo@uomosul.edu.iq


A. I. Khuduzade1, T. Kh. Niyazov2, R. N. Suleymanova2

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

Structural characteristics and sedimentation condition of the Mesozoic complex in the northern part of the South Caspian Basin based on new geophysical data


The high hydrocarbon potential and production rates of the Productive Series deposits in the South Caspian Basin (SCB) provide grounds for investigating the existence of promising areas in deeper layers, and the high oil-gas potential of older stratigraphic sedimentary complexes. In this regard, the extraction of industrially significant oil, gas, and condensate flows from Mesozoic sediments in the Keshchay, Beyimdagh-Tekchay, and Shurabad fields of the Khizi tectonic zone necessitates geological substantiation of the oil and gas potential of the Mesozoic sediments in the continuation of this zone in the North Absheron uplifts zone in the sea.
Mesozoic sediments have been encountered in only a few well sections (Khazri, Gilavar, Arzu, etc.). Cretaceous sediments have also been identified in the Agburun-deniz, Absheron Bankasy, and Western Absheron fields. These sediments, which can reach several hundred meters in thickness, are characterized by terrigenous and carbonate facies. In the North Absheron uplifts zone, new insights into the geological structure of the deeper layers, i.e., the Mesozoic complex, have emerged in recent years based on the complex analysis of seismic profiles and drilling data. Extensive research has also been conducted in this direction by our team, and the results obtained are discussed in this article. Among the issues highlighted are the geological history of the uplift zone, the formation periods of the structures here, the distribution patterns of sediments, and the directions of future research. One of the most relevant problems is the assessment of hydrocarbon potential in deeper layers, which has been partially addressed in this article.

Keywords: seismic depth survey; Mesozoic sedimentary complex; hydrocarbon potential; tectonic faulting; paleotectonics.

Date submitted: 27.02.2025     Date accepted: 06.05.2025

The high hydrocarbon potential and production rates of the Productive Series deposits in the South Caspian Basin (SCB) provide grounds for investigating the existence of promising areas in deeper layers, and the high oil-gas potential of older stratigraphic sedimentary complexes. In this regard, the extraction of industrially significant oil, gas, and condensate flows from Mesozoic sediments in the Keshchay, Beyimdagh-Tekchay, and Shurabad fields of the Khizi tectonic zone necessitates geological substantiation of the oil and gas potential of the Mesozoic sediments in the continuation of this zone in the North Absheron uplifts zone in the sea.
Mesozoic sediments have been encountered in only a few well sections (Khazri, Gilavar, Arzu, etc.). Cretaceous sediments have also been identified in the Agburun-deniz, Absheron Bankasy, and Western Absheron fields. These sediments, which can reach several hundred meters in thickness, are characterized by terrigenous and carbonate facies. In the North Absheron uplifts zone, new insights into the geological structure of the deeper layers, i.e., the Mesozoic complex, have emerged in recent years based on the complex analysis of seismic profiles and drilling data. Extensive research has also been conducted in this direction by our team, and the results obtained are discussed in this article. Among the issues highlighted are the geological history of the uplift zone, the formation periods of the structures here, the distribution patterns of sediments, and the directions of future research. One of the most relevant problems is the assessment of hydrocarbon potential in deeper layers, which has been partially addressed in this article.

Keywords: seismic depth survey; Mesozoic sedimentary complex; hydrocarbon potential; tectonic faulting; paleotectonics.

Date submitted: 27.02.2025     Date accepted: 06.05.2025

References

  1. Guliev, I. S., Feyzullayev, A. A., Efendiyeva, M. A. (2024). All about the oil. Ministry of Science and Education of Azerbaijan, Institute of Geology and Geophysics. https://gia.az/index.php/news/detail
  2. Guliev, I. S., Kerimov, V. Y., Osipov, A. V. (2013). Hydrocarbon potential of great depths. Oil, Gas, Business, 5, 9-16.
  3. Garayev, B. M. (2012). The results of seismic exploration studies on the study of the geological structure of Mesozoic sediments. Azerbaijan Oil Industry, 7-8, 26-31.
  4. Garayev, B. M., Niyazov, T. Kh. (2013). On the origin of reflected waves registered in the Mesozoic interval of seismic sections in the exploration areas of the Yevlakh-Agjabedi trough of Azerbaijan. Geofizika, 4, 65-69.
  5. Rakhmanov, R. R. (2007). Regularities of formation and location of oil and gas deposits in Meso-Cenozoic sediments of Yevlakh-Agjabedi trough. Baku: Nafta-Press.
  6. Hajizade, F. M. (2003). Geological structure and oil-gas content of Middle Kur depression of Azerbaijan. Baku: Adiloglu.
  7. Yusifov, H. M. (2013). To substantiation of prospects of oil and gas bearing capacity of deeply submerged Meso-Cenozoic sediments of Azerbaijan. Azerbaijan Oil Industry, 5, 13-24.
  8. Akhmedov, T. R., Niyazov, T. Kh. (2021). Role of multiple reflections in the formation of the wave field in the Cretaceous sediments of the Middle Kura depression of Azerbaijan. Journal of Geophysics, 3(43), 123-134.
  9. Zeynalov, M. M. (1969). Upper Cretaceous sediments of Azerbaijan and prospects of their oil and gas content. Baku.
  10. Aliyev, A. I. (2010). Where to search for Mesozoic oil in Azerbaijan? What is necessary for this? Azerbaijan Oil Industry, 11, 70-78.
  11. Niyazov, T. Kh., Garayev, B. M. (2015). On the determination of the geological structure of the Yevlakh-Aghjabedi depression on the surface of the Cretaceous sediments based on seismic data. Azerbaijan Oil Industry, 1, 6-10.
  12. Suleymanov, A. M., Niyazov, T. Kh. (2016). Paleotectonic and paleogeographic conditions of sedimentation in the south-eastern part of the Greater Caucasus and the northwestern part of the Absheron archipelago. Azerbaijan Oil Industry, 12, 3-16.
  13. Niyazov, T. Kh., Shakarov, H. I., Khuduzade, A. I., et al. (2023). Identification of structural & tectonic features and prospects of oil and gas potential in the northwestern part of Shimali Absheron uplift. SOCAR Proceedings, SI1, 5-11.
  14. Niyazov, T. Kh. (2022). On the prospects of oil and gas field exploration in non-anticlinal traps in the North Absheron uplift zone. Azerbaijan Oil Industry, 1, 4-9.
  15. Shekarov, H., Aliyeva, E., Niyazov, T. et al. (2020). Report on «Facial analysis of Neogene rocks in the southeastern part of the North Absheron uplift zone and prediction of non-anticlinal traps». Baku: Research and Design Institute of Oil and Gas Fund.
  16. Narimanov, A. A., Khuduzade, A. I. (2010). Formation of oil and gas accumulations in the northwestern part of the Apsheron archipelago of the Southern Caspian Sea. Geologist of Ukraine, 3, 45-48.
  17. Yusubov, N. P., Guliev, G. A., Borovikova, A. Y., et al. (2013). The deep structure of the sedimentary cover of the North Absheron uplift zone and prospects for its oil and gas content according to seismic data. Azerbaijan Oil Industry, 10, 9-16.
  18. Babayev, D. Kh., Agayev, H. B., Gadzhiyev, A. N. (2003). On the joint study of the northwestern part of the Azerbaijani sector of the Middle Caspian by "Kaspmorneftegeofizrazvedka" Trust and the Institute of Geology of the National Academy of Sciences of the Republic of Azerbaijan. Report. Ministry of Science and Education of Azerbaijan, Institute of Geology and Geophysics.
  19. Valiyev, H. O., Gasimov, C. A., Shikhmammadova, T. N. (2016). North Absheron - Report of three-dimensional (3D) seismic research conducted in Goshadash field of Absheron oil and gas region. Baku.
  20. Allahverdiyev, E .G., Rasullu, R. M. (2022). Evaluation of oiliness-gasiness prospects of Mesozoic-Lower Paleogene sediments in the Northern Absheron uplift zone. Report. Baku.
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DOI: 10.5510/OGP20250201061

E-mail: tarverdi.niyazov@socar.az


V. Y. Kerimov1,2, R. A. Mammedov2, V. Sh. Gurbanov1, Sh. M. Huseynova1

1Institute of Oil and Gas of the Ministry of Science and Education of the Republic of Azerbaijan, Baku, Azerbaijan; 2Sergo Ordzhonikidze Russian State University for Geological Prospecting, Moscow, Russia

Lithologic-facies and paleogeographic conditions of formation of natural oil and gas reservoirs in the South Caspian Basin


To study the reservoirs of the South Caspian basin, models of the distribution of natural reservoirs, paleogeographic sedimentation settings, lithological and facies schemes, thickness maps, sedimentation velocity maps, and a scheme for determining the boundaries of sedimentation depocenters based on the results of lithological, paleogeographic, and sedimentary-facies studies were developed. Paleogeographic reconstructions have shown that fluvial-delta complexes played a significant role in the formation of sedimentary complexes in the South Caspian basin. The general geological background of the SKB is characterized by: sharp lithofacial and filtration-capacitive heterogeneity of the section, which was built up in separate Cenozoic intervals in an environment of nonequilibrium avalanche sedimentation; rhythmicity of the productive stratum-red-colored stratum (PT-CT), expressed in periodic vertical substitution of clay differences with sandy ones; lens-forming regionally consistent wedging of the stratigraphic components of the PT section. CT both in the direction of rising and sinking of general folding; Lithologicalpaleogeographic and lithological-facies studies indicate the existence of favorable conditions for the formation of lithological and stratigraphic traps of oil and gas in clinoform complexes in the South Caspian basin. The results of these studies are of key importance for practical applicationin the field ofin the planning of geological exploration. Reservoir maps and litho-facies schemes provide a reasonable choice of the location of project wells in the most promising areas of reservoir development. Models of paleogeographic settings make it possible to predict the distribution of sand bodies in ancient delta complexes, and sedimentation rate maps help to assess the degree of rock consolidation and predict abnormal reservoir pressures.

Keywords: South Caspian basin; paleogeography; lithologic-facies schemes; sedimentation rates; depocenters; reservoirs; clinoforms.

Date submitted: 06.02.2025     Date accepted: 10.06.2025

To study the reservoirs of the South Caspian basin, models of the distribution of natural reservoirs, paleogeographic sedimentation settings, lithological and facies schemes, thickness maps, sedimentation velocity maps, and a scheme for determining the boundaries of sedimentation depocenters based on the results of lithological, paleogeographic, and sedimentary-facies studies were developed. Paleogeographic reconstructions have shown that fluvial-delta complexes played a significant role in the formation of sedimentary complexes in the South Caspian basin. The general geological background of the SKB is characterized by: sharp lithofacial and filtration-capacitive heterogeneity of the section, which was built up in separate Cenozoic intervals in an environment of nonequilibrium avalanche sedimentation; rhythmicity of the productive stratum-red-colored stratum (PT-CT), expressed in periodic vertical substitution of clay differences with sandy ones; lens-forming regionally consistent wedging of the stratigraphic components of the PT section. CT both in the direction of rising and sinking of general folding; Lithologicalpaleogeographic and lithological-facies studies indicate the existence of favorable conditions for the formation of lithological and stratigraphic traps of oil and gas in clinoform complexes in the South Caspian basin. The results of these studies are of key importance for practical applicationin the field ofin the planning of geological exploration. Reservoir maps and litho-facies schemes provide a reasonable choice of the location of project wells in the most promising areas of reservoir development. Models of paleogeographic settings make it possible to predict the distribution of sand bodies in ancient delta complexes, and sedimentation rate maps help to assess the degree of rock consolidation and predict abnormal reservoir pressures.

Keywords: South Caspian basin; paleogeography; lithologic-facies schemes; sedimentation rates; depocenters; reservoirs; clinoforms.

Date submitted: 06.02.2025     Date accepted: 10.06.2025

References

  1. Kerimov, V. Yu., Guliyev, I. S., Huseynov, D. A., et al. (2015). Forecasting oil and gas potential in regions with complex geological structures. Moscow: Nedra Publishing House.
  2. Alizadeh, A. A., Guliyev, I. S., Mamedov, P. Z. (2018). Productive thickness of Azerbaijan. In 2 vols. Moscow: Nedra Publishing House.
  3. Kerimov, V. Yu., Mukhtarova, Kh. Z., Mustaev, R. N. (2011). Disjunctive disorders and their role in the formation and destruction of oil and gas deposits in the South Caspian Sea. Oil, Gas and Business, 6, 18-26.
  4. Kerimov, V. Yu., Rachinsky, M. Z. (2011). Geofluidodynamics of oil and gas potential in mobile belts. Moscow: Nedra Publishing House.
  5. Guliyev, I. S., Klyatsko, N. V., Mamedov, S. A., Suleymanova, S. V. (1992). Oil-producing and reservoir properties of deposits of the South Caspian basin. Lithology and Mineral Resources, 2, 110-120.
  6. Yusubov, N. P., Guliyev, I. S. (2021). Some features of the structure of the sedimentary complex of the Middle and South Caspian basins (Azerbaijan sector). Geofizika, 4(43), 199-216.
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  11. Guliev, I., Panahi, B. (2004). Geodynamics of the deep sedimentary basin of the Caspian Sea region: Paragenetic correlation of seismicity and mud volcanism. Geo Marine Letters, 24(3), 169-177.
  12. Kadirov, F., Mamedov, S., Reilinger, R., McClusky, S. (2010). Some data on modem tectonic deformation and active faulting in Azerbaijan (according to global positioning system measurement). Proceedings of Azerbaijan National Academy of Sciences, The Sciences of Earth, 1, 82-88.
  13. Abdullaev, N. R. (2004). Basin analysis of the South Caspian basin based on new geological and geophysical studies. Doctoral Thesis. Baku: Institute of Oil and Gas of the Ministry of Science and Education.
  14. Guliyev, I. S., Yusubov, N. P., Huseynova, Sh. M. (2020). On the mechanism of formation of mud volcanoes in the South Caspian basin accordingto 2D/3D seismic data. Physics of the Earth, 5, 131-138.
  15. Guliyev, I. S., Kerimov, V. Y., Osipov, A. V., Mustaev, R. N. (2017). Generation and accumulation of hydrocarbons at great depths under the earth's crust. SOCAR Proceedings, 1, 4-16.
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DOI: 10.5510/OGP20250201062

E-mail: vagif.kerimov@mail.ru


A. A. Kabdushev1, A. R. Kembayev2, G. Zh. Bimbetova2, F. A. Agzamov3, G. M. Efendiyev4, K. S. Nadirov2

1Dulaty University (Taraz University named after M.H. Dulaty), Taraz, Kazakhstan; 2South Kazakhstan University named after M. Auezov, Shymkent, Kazakhstan; 3Ufa State Petroleum Technological University, Ufa, Russia; 4Institute of Oil and Gas of the Ministry of Science and Education of Azerbaijan, Baku, Azerbaijan

Development of the composition of lightweight cement slurry using microspheres and microsilica


It is well known that Portland cement has long been used in the construction of oil and gas wells. In this case, cementing slurries based on Portland cement are placed in the annular space, and after setting, they provide long-term isolation of the formations for subsequent operation. Therefore, the cementing process and the quality of these operations are of significant importance. To minimize of complications due to circulation loss, effective lightweight additives, including microspheres and microsilica, are widely used. However, when using microspheres, they may float when the water-cement ratio increases, and the resulting slurries exhibit high water yield. Microsilica in the cement slurry reduces water yield and does not float, but it thickens the slurry. The aim of this work is to develop lightweight cementing slurries for moderate temperatures with the rational use of the aforementioned additives. The authors of this article have developed a composition of lightweight cementing slurries for various climatic conditions using these additives. It has been specifically demonstrated that by adding 10% microspheres and 10% microsilica, effective lightweight cementing slurries can be obtained, where the various properties of the additives produce a positive outcome. The addition of 0.1% anhydrous sodium silicate to the cement slurry further improves the primary technological parameters of the slurry and, in general, the cement stone. Based on the conducted studies, an increase in the compressive strength of the cement stone to 7.04 MPa with a water-cement ratio of 0.7 was observed.

Keywords: cement; microsphere; microsilica; lightweight; slurry.

Date submitted: 14.03.2025     Date accepted: 11.06.2025

It is well known that Portland cement has long been used in the construction of oil and gas wells. In this case, cementing slurries based on Portland cement are placed in the annular space, and after setting, they provide long-term isolation of the formations for subsequent operation. Therefore, the cementing process and the quality of these operations are of significant importance. To minimize of complications due to circulation loss, effective lightweight additives, including microspheres and microsilica, are widely used. However, when using microspheres, they may float when the water-cement ratio increases, and the resulting slurries exhibit high water yield. Microsilica in the cement slurry reduces water yield and does not float, but it thickens the slurry. The aim of this work is to develop lightweight cementing slurries for moderate temperatures with the rational use of the aforementioned additives. The authors of this article have developed a composition of lightweight cementing slurries for various climatic conditions using these additives. It has been specifically demonstrated that by adding 10% microspheres and 10% microsilica, effective lightweight cementing slurries can be obtained, where the various properties of the additives produce a positive outcome. The addition of 0.1% anhydrous sodium silicate to the cement slurry further improves the primary technological parameters of the slurry and, in general, the cement stone. Based on the conducted studies, an increase in the compressive strength of the cement stone to 7.04 MPa with a water-cement ratio of 0.7 was observed.

Keywords: cement; microsphere; microsilica; lightweight; slurry.

Date submitted: 14.03.2025     Date accepted: 11.06.2025

References

  1. Nelson, E. B., Guillot, D. F. (2006). Well cementing. Texas: Schlumberger.
  2. Agzamov, F. A., Izmukhambetov, B. S., Tokunova, E. F. (2011). Chemistry of cement and drilling fluids. St. Petersburg: Nedra.
  3. Low, N., Daccord, G., Bedel, J.-P. (2003). Designing fibered cement mortars for lost circulation applications: Case histories. SPE-84617-MS. In: SPE Annual Technical Conference and Exhibition, Denver, Colorado, USA.
  4. Efendiyev, G. M., Moldabayeva, G. Z., Buktukov, N. S., Kuliyev, M. Y. (2024). With comprehensive cementing quality assessment and risk management system. SOCAR Proceedings, 4, 42-47.
  5. Pernites, R., Montgomery, M., Fu, D., Padilla, F. (2020). Reducing well construction costs through field application of new unconventional lightweight cementing solutions—Multiple case histories in the Permian Basin. URTEC-2020-2995-MS. In: SPE/AAPG/SEG Unconventional Resources Technology Conference, Virtual.
  6. Suleimanov, B. A., Veliyev, E. F., Vishnyakov, V. V. (2022). Nanocolloids for petroleum engineering: Fundamentals and practices. John Wiley & Sons.
  7. Suleimanov, B. A., Veliyev, E. F., Shovgenov, A. D. (2022). Well cementing: fundamentals and practices. Moscow-Izhevsk: ICS.
  8. Suleimanov, B. A., Veliyev, E. F., Aliyev, A. A. (2023). Oil and gas well cementing for engineers. John Wiley & Sons.
  9. Suleimanov, B. A., Dyshin, O. A., Veliyev, E. F. (2016). Compressive strength of polymer nanogels used for enhanced oil recovery (EOR). SPE-181960-MS. In: SPE Russian Petroleum Technology Conference and Exhibition, Moscow, Russia.
  10. Kazmina, O. V., Mitina, N. A., Minaev, K. M. (2020). Lightweight cement mortar with inorganic perlite microspheres for equipping oil and gas production wells. Magazine of Civil Engineering, 93(1), 83–96.
  11. Akhrimenko, V. E. (2006). Lightweight cement mortars for cementing high-temperature wells. Construction of Oil and Gas Wells on Land and at Sea, 5, 34–36.
  12. Shchavelev, N. L., Lushpeeva, O. A., Loseva, N. T., et al. (2003). Lightweight cementitious composition. RU Patent 2204691.
  13. Oreshkin, D. V., Belousov, G. A. (2007). Efficiency of using cementing materials with hollow glass microspheres. Bulletin of the Association of Drilling Contractors, 4, 33–41.
  14. Agzamov, F. A., Grigoryev, A. Y. (2022). Modification of portland cement with nanoadditives. Nanotechnologies in Construction, 14(4), 319–327.
  15. Mohammedameen, A. I. M., Agzamov, F. A., Ismakov, R. A. (2024). Study on the influence of zeolite nanoparticles on selected properties of Portland cement. Nanotechnologies in Construction, 16(1), 12–21.
  16. Kabdushev, A. A., Agzamov, F. A., Manapbayev, B. Zh., et al. (2023). Research and development of cements with differential properties for completing gas wells. News of the National Academy of Sciences of the Republic of Kazakhstan: Series of Geology and Technical Sciences, 4(460), 97–108.
  17. Merzlyakov, M. Yu., Yakovlev, A. A. (2015). Application of cement mortars with the inclusion of hollow microcavity seals when casing wells in the cryolithozone. GIAB, 5, 370-376.
  18. Mata, C., Calubayan, A. (2016). Use of hollow glass spheres in lightweight cements - selection criteria. SPE-182399-MS. In: SPE Asia Pacific Oil & Gas Conference and Exhibition. 
  19. Buglov, N. A., Butakova, L. A., Bulanov, N. S. (2019). Influence of MSp on the physical properties of cement stone.
    Bulletin of the Siberian Branch of the Russian Academy of Natural Sciences: Geology, Prospecting and Exploration of Ore Deposits, 2, 67.
  20. Ma, R., Bu, Y., Liu, H., Lu, C. (2023). Study on cementing in natural gas hydrate reservoir in deep water: Application of heat storage agent in cement slurry to prevent hydrates decomposition. ISOPE-I-23-002. In: 33rd International Ocean and Polar Engineering Conference, Ottawa, Canada.
  21. Umraliev, B. T., Agzamov, F. A., Taskinbaev, M. Zh., Seitov, A. K. (2020). Production of lightweight cementing materials from local raw materials for well casing in corrosive environments. Bulletin of the Oil and Gas Industry of Kazakhstan, 1(2), 70–82.
  22. Bekbaev, A. A., Agzamov, F. A., Komleva, S. F. (2018). Dispersed reinforcement of lightweight cements. Oil Province, 3, 127–141.
  23. Kabdushev, A. A., Agzamov, F. A., Manapbayev, B. Zh., Moldamuratov, Zh. N. (2023). Microstructural analysis of strain-resistant cement designed for well construction. Nanotechnology in Construction, 15(6), 564–573.
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DOI: 10.5510/OGP20250201063

E-mail: aidos_kem@mail.ru


A. R. Deryaev1, D. S. Saduakassov2, M. T. Tabylganov2

1SRI of Natural Gas of the State Concern «Turkmengas», Ashgabat, Turkmenistan; 2S. Yessenov Caspian University of Technologies and Engineering, Aktau , Kazakhstan

Study of wellbore curvature during drilling in the Gogerendag field


During the drilling process, the borehole curves for several reasons. Both techno-technological factors and natural factors lead to this. Natural factors include inclined bedding of rocks, alternation of rocks of different hardness, layering, fracturing, presence of caverns and shear planes, and anisotropy of rocks, which means that their properties are not the same both along and across the bedding. The loss of straightness of the bottom of the drill string while creating axial load on the bit, its rotation, use of bent tubing and drill string bottom hole assembly (BHA) layout are technical and technological factors. During the initial drilling period, the well deviates from the vertical due to non-horizontality of the rotor table and non-centredness of the derrick. Two components can determine any wellbore curvature. The first is the azimuth angle or zenith angle, which shows the deviation of the well axis from vertical. The second is the curvature angle. This is the angle between the vertical plane passing through the north end of the magnetic arrow and the vertical plane lying on the axis of the warped borehole. The borehole curves in one plane at constant azimuth, whereas at variable azimuth the borehole curves in space. Investigation of well warp patterns during drilling in the Gogerendag field is the focus of the research study. The focus of the study is to assess the quality of well construction and wellbore verticality assurance. Based on the study, the author offers recommendations and results to prevent wellbore distortion.

Keywords: curvature; wellbore; drilling tool; layout; pendulum; zenith angle; conductor.

Date submitted: 26.09.2024     Date accepted: 20.05.2025

During the drilling process, the borehole curves for several reasons. Both techno-technological factors and natural factors lead to this. Natural factors include inclined bedding of rocks, alternation of rocks of different hardness, layering, fracturing, presence of caverns and shear planes, and anisotropy of rocks, which means that their properties are not the same both along and across the bedding. The loss of straightness of the bottom of the drill string while creating axial load on the bit, its rotation, use of bent tubing and drill string bottom hole assembly (BHA) layout are technical and technological factors. During the initial drilling period, the well deviates from the vertical due to non-horizontality of the rotor table and non-centredness of the derrick. Two components can determine any wellbore curvature. The first is the azimuth angle or zenith angle, which shows the deviation of the well axis from vertical. The second is the curvature angle. This is the angle between the vertical plane passing through the north end of the magnetic arrow and the vertical plane lying on the axis of the warped borehole. The borehole curves in one plane at constant azimuth, whereas at variable azimuth the borehole curves in space. Investigation of well warp patterns during drilling in the Gogerendag field is the focus of the research study. The focus of the study is to assess the quality of well construction and wellbore verticality assurance. Based on the study, the author offers recommendations and results to prevent wellbore distortion.

Keywords: curvature; wellbore; drilling tool; layout; pendulum; zenith angle; conductor.

Date submitted: 26.09.2024     Date accepted: 20.05.2025

References

  1. Deryaev, A. R. (2024). Choosing the profile of an inclined –directional well in the Caspian sea area of Turkmenistan. SOCAR Proceedings, 1, 32-39.
  2. Gerzhberg, Yu. (2013). Drilling with stepped face as mean to restrict deviation of well. Burenie i Neft, 07-08, 55-56.
  3. Ishbaev, G., Vagapov, S. (2012). BURINTEKH, Ltd. modern elements. Burenie i Neft, 06-07, 55-56.
  4. Eren, T., Suicmez, V. S. (2020). Directional drilling positioning calculations. Journal of Natural Gas Science and Engineering, 73, 103081.
  5. Robello, S. (2021). A compelling case: time to change minimum curvature survey method for well engineering calculations. IPTC-21258-MS. In: Proceedings of International Petroleum Technology Conference, Virtual.
  6. Willerth, M., Heintzelman, L., Bauman, J., et al. (2023). A comparison of high-resolution trajectory methods and their impact on drilling data analysis. SPE-212510-MS. In: Proceedings of SPE/IADC International Drilling Conference and Exhibition, Stavanger, Norway.
  7. Gillespie, P., Digranes, G., Graham, B. (2021). Structural curvature analysis from borehole image interpretation. In: Fourth EAGE Borehole Geology Workshop. European Association of Geoscientists & Engineers.
  8. Ertunç, G., Imer, A. (2022). Drillhole database applet: Minimum curvature algorithm and downhole composite. In: Proceedings of 27th International Mining Congress and Exhibition of Turkey, Antalya.
  9. Deryaev, A. R. (2024). Features of the construction of directed deep wells in Turkmenistan. Italian Journal of Engineering Geology and Environment, 1, 35-47.
  10. Agishev, E. (2025). Testing of wells with horizontal completion in the conditions of terrigenous deposits of the Vietnamese shelf. E3S Web of Conferences, 623, 02001.
  11. Stavychnyi, Y., Piatkivskyi, S., Vytiaz, A., et al. (2025). Specific features and prospects of well recovery by sidetracking based on the example of the Stynava field. Nafta-Gaz, 1, 3-15.
  12. Gu, H., Yan, T., Wu, Y. (2025). Research on intelligent optimization of wellbore trajectory in complex formation. Applied Sciences, 15(3), 1364.
  13. Jerez, L. S., Cayeux, E., Sui, D. (2025). Automatic calibration of systematic biases in directional drilling control for planar and non-planar curves. Geoenergy Science and Engineering, 246, 213642.
  14. Deryaev, A. R. (2024). Drilling of directional wells in the fields of Western Turkmenistan. Grassroots Journal of Natural Resources, 7(2), 347-369.
  15. Dani, K. C., Gupta, D. K., Sharma, P. (2023). Solution to the complications in CBM BHA during deviated well drilling. AIP Conference Proceedings, 2855(1), 040002.
  16. AlHosni, F., Echevarria, E., Ruzhnikov, A., Rojas, L. (2023). Understanding drilling dynamics thru tandem downhole recording tools enabled drilling performance: Middle East specific. SPE-214651-MS. In: Proceedings of the SPE/IADC Middle East Drilling Technology Conference and Exhibition, Abu Dhabi.
  17. Xi, C., Zhang, W., Zhang, N., Chu, H. (2022). Study on factors affecting vertical drilling bottom hole assembly performance and a new bottom hole assembly design method considering formation uncertainties. Frontiers in Energy Research, 10, 1073135. 
  18. Cheng, Z., Zhang, L., Hao, Z., et al. (2024). A new bottom-hole assembly design method to maintain verticality and reduce lateral vibration. Processes, 12(1), 95.
  19. Willerth, M., Dodson, B., McCue, K., Farrag, M. (2021). When slick is not smooth: bottom-hole assembly selection and its impact on wellbore quality. SPE-204129-MS. In: Proceedings of the SPE/IADC International Drilling Conference and Exhibition, Virtual.
  20. Gao, D. (2022). Some research advances in well engineering technology for unconventional hydrocarbon. Natural Gas Industry B, 9(1), 41-50.
  21. Qun, L., Yun, X., Zhanwei, Y., et al. (2021). Progress and development directions of stimulation techniques for ultradeep oil and gas reservoirs. Petroleum Exploration and Development, 48(1), 221-231.
  22. Zalluhoglu, U., Tilley, J., Zhang, W., Grable, J. (2020, February). Downhole attitude-hold controller leads to automatic steering of directional wells with improved accuracy and reduced tortuosity. SPE-199555-MS. In: IADC/SPE International Drilling Conference and Exhibition, Galveston, Texas, USA.
  23. Mansouri, V., Khosravanian, R., Wood, D. A., Aadnøy, B. S. (2020). Optimizing the separation factor along a directional well trajectory to minimize collision risk. Journal of Petroleum Exploration and Production Technology, 10, 2113-2125.
  24. Kamgue Lenwoue, A. R., Li, Z., Tang, C., et al. (2023). Recent Advances and challenges of the application of artificial intelligence to predict wellbore instabilities during drilling operations. SPE Drilling & Completion, 38(4), 645-662.
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DOI: 10.5510/OGP20250201064

E-mail: annagulyderyayew@gmail.com


B. A. Suleimanov1, H. F. Abbasov1, R. Y. Aliyev2, N. I. Guseynova1, N. R. Abdullayeva1

1«OilGasScientificResearchProject» Institute, SOCAR, Baku, Azerbaijan; 2JSC «Azerenerji» , Baku, Azerbaijan

Selection of proxy modelling methods for streamline simulation to waterflooding management process in oil reservoirs


Proxy modelling which uses a number of predetermined reliable parameters due to its simplicity has been widely used for the analysis of gas and oil field development in comparison to the traditional mathematical three-dimensional (3D) hydrodynamic models. Among the reservoir models with simplified physics the streamline simulation is favorably characterized by its visibility and informativeness. In this work MATLAB as well as COMSOL Multiphysics modules were used for streamline simulation of flow in porous media using known volumes of injected and produced fluid in a reservoir with known permeability and porosity for sequential waterflood treatment. The comparative analysis showed that after one month of the treatment the front of the injected water advancement became smoother. Comparing the dynamics of the location of the lines characterizing the filtration state of the area before and after the impact on the reservoir, it was found that the productivity of production wells depends not only on how close they are located to the injection well, but also on the activity of the filtration zone. Based on an analysis of the preferred directions of fluid movement after sequential waterflooding, it was determined that oil in some previously unaffected areas was also displaced by the injected fluid. The results obtained by MATLAB and COMSOL Multiphysics modules were analyzed comparatively. 

Keywords: proxy modelling; streamline simulation; COMSOL Multiphysics; MATLAB; Darcy's law; reservoir models.

Date submitted: 10.02.2025     Date accepted: 03.05.2025

Proxy modelling which uses a number of predetermined reliable parameters due to its simplicity has been widely used for the analysis of gas and oil field development in comparison to the traditional mathematical three-dimensional (3D) hydrodynamic models. Among the reservoir models with simplified physics the streamline simulation is favorably characterized by its visibility and informativeness. In this work MATLAB as well as COMSOL Multiphysics modules were used for streamline simulation of flow in porous media using known volumes of injected and produced fluid in a reservoir with known permeability and porosity for sequential waterflood treatment. The comparative analysis showed that after one month of the treatment the front of the injected water advancement became smoother. Comparing the dynamics of the location of the lines characterizing the filtration state of the area before and after the impact on the reservoir, it was found that the productivity of production wells depends not only on how close they are located to the injection well, but also on the activity of the filtration zone. Based on an analysis of the preferred directions of fluid movement after sequential waterflooding, it was determined that oil in some previously unaffected areas was also displaced by the injected fluid. The results obtained by MATLAB and COMSOL Multiphysics modules were analyzed comparatively. 

Keywords: proxy modelling; streamline simulation; COMSOL Multiphysics; MATLAB; Darcy's law; reservoir models.

Date submitted: 10.02.2025     Date accepted: 03.05.2025

References

  1. Babadagli, T. (2007). Development of mature oil fields — A review. Journal of Petroleum Science and Engineering, 57(3–4), 221-246.
  2. Liu, Z.-X., Liang, Y., Wang, Q., et al. (2020). Status and progress of worldwide EOR field applications. Journal of Petroleum Science and Engineering, 193, 107449.
  3. Suleimanov, B. A., Abbasov, H. F. (2022). Enhanced oil recovery mechanism with nanofluid injection. SOCAR Proceedings, 3, 28-37.
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  5. Jamalbayov, M. A., Ibrahimov, Kh. M. (2023). New waterflooding efficiency evaluation method (on the example of 9th horizon of the Guneshli field). Scientific Petroleum, 1, 43-47.
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  8. Mukhametshin, V. Sh. (2025). Elimination of uncertainties in the selection of parameters for assessing the impact on the bottomhole zone. SOCAR Proceedings, 4, 111-116.
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  10. Abdullayev, V. J., Gamzaev, Kh. M. (2025). A method for computing the pressure distribution in the elastic mode of single-well formation development. SOCAR Proceedings, 2, 80-84. 
  11. Bekman, A. D., Ruchkin, A. A. (2024). Method for assessing well interference at under-gas cap zone using CRM material balance model. Tyumen State University Herald. Physical and Mathematical Modeling. Oil, Gas, Energy, 10(1), 155–173.
  12. Abdullayev, V. J., Veliyev, R. G., Ryabov, S. S., et al. (2023). Application of gel systems for wa-ter shut-off on Uzbekistan oil fields. SOCAR Proceedings, 1, 68-73.
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  21. Alghamdi, A., Hiba, M., Aly, M., et al. (2021). Critical review of capacitance-resistance models. SPE-206555-MS. In: The SPE Russian Petroleum Technology Conference, Virtual.
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  24. Suleimanov, B. A., Rzayeva, S. C., Akhmedova, U. T. (2021). Self-gasified biosystems for enhanced oil recovery. International Journal of Modern Physics B, 35(27), 2150274.
  25. Ibrahimov, Kh. M., Huseynova, N. I., Hajiyev, A. A. (2021). Development of new controlling methods for the impact on the productive formation for «Neft Dashlary» oilfield. Scientific Petroleum, 1, 37-42.
  26. Suleimanov, B. A. (2011). Mechanism of slip effect in gassed liquid flow. Colloid Journal, 73(6), 846–855.
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  29. Datta-Gupta, A., King, M. J. (2007). Streamline simulation: theory and practice. Society of Petroleum Engineers.
  30. Huseynova, N. I. (2017). Hydrodynamic express monitoring of zonal impact on productive reservoirs of oil fields taking into account well interference. Petroleum Engineering, 15(3), 41-46.
  31. Hunt, B. R., Lipsman, R. L., Rosenberg, J. M. (2008). A guide to Matlab for beginners and experienced users. United Kingdom: University of Cambridge.
  32. Ibrahimov, Kh. M., Guseynova, N. I., Abdullayeva, F. Y. (2017). Experience of microbial enhanced oil recovery methods at Azerbaijan fields. Petroleum Science and Technology, 35(18), 1822-1830.
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DOI: 10.5510/OGP20250201065

E-mail: baghir.suleymanov@socar.az


A. M. Mammad-zade1, E. F. Alizade2

1«Geotechnological Problems of Oil, Gas, and Chemistry» SRI, Azerbaijan State Oil and Industry University, Baku, Azerbaijan; 2Azerbaijan State Oil and Industry University, Baku, Azerbaijan

Investigation of fluid dynamics impact with magnetic field applications on enhanced oil recovery in porous media


This study investigates the impact of magnetic fields on the electrokinetic properties of reservoir fluids and fluid discharge behavior under varying pressure conditions. A custom experimental setup was developed, comprising a high-pressure column, PVT bomb, electromagnet and multiple measurement and control devices, to simulate reservoir conditions accurately. The study systematically examined the influence of magnetic field intensities ranging from 31831 to 119366 A/m on voltage, resistance and water discharge across pressure variations between 1.6 and 14.4 atm. The results demonstrate that magnetic fields positively influence fluid behavior, significantly enhancing ion mobility and fluid conductivity. This enhancement leads to increased water discharge and stabilized fluid flow, particularly under high-pressure conditions. Notably, an optimal magnetic field intensity of 99472 A/m was identified, yielding the most favorable effects on reducing resistance, stabilizing voltage and increasing discharged water volume. At this intensity, the resistance of the system decreased significantly and the discharged water volume peaked at approximately 75 m³ around 8- 9 atm, highlighting the field's role in facilitating fluid movement through porous media. Beyond this intensity, a diminishing return effect was observed, indicating a potential saturation point in the magnetic field's influence on fluid properties. These findings provide valuable insights into the role of magnetic fields in optimizing fluid transport in porous media, offering potential advancements for enhanced oil recovery techniques. The study underscores the transformative potential of magnetic fields in improving fluid mobility and recovery efficiency in oil reservoirs, paving the way for further exploration and application of this technology in the oil and gas industry. 

Keywords: magnetic fields; electrokinetics; discharged water volume; pressure effects; fluid mobility; porous media; flow resistance; magnetic field intensity; oil recovery.

Date submitted: 28.11.2024     Date accepted: 02.05.2025

This study investigates the impact of magnetic fields on the electrokinetic properties of reservoir fluids and fluid discharge behavior under varying pressure conditions. A custom experimental setup was developed, comprising a high-pressure column, PVT bomb, electromagnet and multiple measurement and control devices, to simulate reservoir conditions accurately. The study systematically examined the influence of magnetic field intensities ranging from 31831 to 119366 A/m on voltage, resistance and water discharge across pressure variations between 1.6 and 14.4 atm. The results demonstrate that magnetic fields positively influence fluid behavior, significantly enhancing ion mobility and fluid conductivity. This enhancement leads to increased water discharge and stabilized fluid flow, particularly under high-pressure conditions. Notably, an optimal magnetic field intensity of 99472 A/m was identified, yielding the most favorable effects on reducing resistance, stabilizing voltage and increasing discharged water volume. At this intensity, the resistance of the system decreased significantly and the discharged water volume peaked at approximately 75 m³ around 8- 9 atm, highlighting the field's role in facilitating fluid movement through porous media. Beyond this intensity, a diminishing return effect was observed, indicating a potential saturation point in the magnetic field's influence on fluid properties. These findings provide valuable insights into the role of magnetic fields in optimizing fluid transport in porous media, offering potential advancements for enhanced oil recovery techniques. The study underscores the transformative potential of magnetic fields in improving fluid mobility and recovery efficiency in oil reservoirs, paving the way for further exploration and application of this technology in the oil and gas industry. 

Keywords: magnetic fields; electrokinetics; discharged water volume; pressure effects; fluid mobility; porous media; flow resistance; magnetic field intensity; oil recovery.

Date submitted: 28.11.2024     Date accepted: 02.05.2025

References

  1. Mirzajanzade, A. Kh., Iskandarov, M. A., Abdullayev, M. A., et al. (1960). Exploitation and development of oil and gas fields. Baku.
  2. Mammadzade, A. M. (2021). Nanotechnological foundations for the application of non-equilibrium effects of physical fields in oil and gas extraction. Baku.
  3. Mirzajanzade, A. Н., Mamed-Zade, А. М. (1990). Effect of clay mineral on fluid filtration in a porous medium. Lithos, 24(4), 251–260.
  4. Mamed-Zade, А. М., Salavatov, T. Sh. (2003). Application of physical fields to enhance oil recovery. In: Ist International Scientific Conference “Modern Problems of Oil Recovery”, Moscow.
  5. Suleimanov, B. A., Veliyev, E. F., Vishnyakov, V. V. (2022). Nanocolloids for petroleum engineering: Fundamentals
    and practices. John Wiley & Sons.
  6. Suleimanov, B. A. (2011). Mechanism of slip effect in gassed liquid flow. Colloid Journal, 73(6), 846–855.
  7. Mamed-Zade, А. М., Salavatov, T. Sh., Guseinov, V. G. (2002). Energy- and resource-saving technology in oil production. Azerbaijan Oil Industry, 5, 19-21.
  8. Mamed-zade, A. M., Abbasov, E. M. (1986). Some aspects of the mechanism of influence of magnetised water on the displacement coefficient. Proceedings of Higher Educational Institutions «Oil and Gas», 7, 45– 48.
  9. Mammad-zade, A. M., Alizadeh, E. F., Melikov, T.G., et al. (2025). Determination of the final oil extraction coefficient when treating waterwhit an external constant transverse magnetic field of low strength. Vestnik KazUTB, 1(26), 452-463.
  10. Alvarado, V., Manrique, E. (2010). Enhanced oil recovery: An update review. Energies, 3, 1529-1575.
  11. Yuan, B., Wood, D. A. (2018). A comprehensive review of formation damage during enhanced oil recovery. Journal of Petroleum Science and Engineering, 167, 287-299.
  12. Mammadzade, A., Nazarov, F., Veysalova, F., et al. (2024). Influence of the magnetic storm created by the solar flare on the measurements of the magnetic field of the system on the Earth. The Caucasus, Economic & Social Analysis Journal of Southern Caucasus, 59(02), 81-86.
  13. Vishnyakov, V. V., Suleimanov, B. A., Salmanov, A. V., Zeynalov, E. B. (2019). Primer on enhanced oil recovery. Gulf Professional Publishing.
  14. Suleimanov, B. A., Rzayeva, S. C., Akberova, A. F., Akhmedova, U. T. (2022). Self-foamed biosystem for deep reservoir conformance control. Petroleum Science and Technology, 40(20), 2450-2467.
  15. Józefczak, A., Wlazło, R. (2015). Ultrasonic studies of emulsion stability in the presence of magnetic nanoparticles. Advances in Condensed Matter Physics, 23, 1-9.
  16. Amrouche, F., Blunt, M. J., Iglauer, S., et al. (2024). A novel hybrid enhanced oil recovery technique to enhance oil production from oil-wet carbonate reservoirs by combining electrical heating with nanofluid flooding. Materials Today Sustainability, 27, 100915.
  17. Xu, Zh.-X., Li, S.-Y., Li, B.-F., et al. (2020). A review of development methods and EOR technologies for carbonate reservoirs. Petroleum Science, 17 (4), 990-1013.
  18. Hassan, Y. M., Guan, B. H., Zaid, H. M., et al. (2021). Application of magnetic and dielectric nanofluids for electromagnetic-assistance enhanced oil recovery: a review. Crystals, 11, 106.
  19. Asadollahi, M. (2012). Waterflooding Optimization for Improved Reservoir Management. PhD Thesis. Trondheim, Norway: Norwegian University of Science and Technology.
  20. Grema, A. S., Cao, Y. (2013). Optimization of petroleum reservoir waterflooding using receding horizon approach. In: Proceedings of the 8th IEEE Conference on Industrial Electronics and Applications, IEEE, Melbourne, Australia.
  21. Blunt, M. J. (2017). Multiphase flow in permeable media: A porescale perspective. Cambridge: Cambridge University Press.
  22. Yang, Y., Zhou, Y., Blunt, M. J., et al. (2021). Advances in multiscale numerical and experimental approaches for multiphysics problems in porous media. Advances in Geo-Energy Research, 5(3), 233-238.
  23. Joonaki, E., Ghanaatian, 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.
  24. Ali, J.A., Kolo, K., Manshad, A. K., et al. (2018). Recent advances in application of nanotechnology in chemical enhanced oil recovery: effects of nanoparticles on wettability alteration, interfacial tension reduction, and flooding. Egyptian Journal of Petroleum, 27, 1371–1383.
  25. Alotaibi, M. B, Nasr-El-Din, H. A., Fletcher, J. J. (2011). Electrokinetics of limestone and dolomite rock particles. SPE-148701-PA. SPE Reservoir Evaluation & Engineering, 14(5), 594–603.
  26. Katende, A., Sagala, F. (2019). A critical review of low salinity water flooding: mechanism, laboratory and field application. Journal of Molecular Liquids, 278, 627–649.
  27. Blaszczyk, M., Sek, J., Pacholski, P., et al. (2017). The analysis of emulsion structure changes during flow through porous structure. Journal of Dispersion Science and Technology, 38 (8), 1154-1161.
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  29. Safarov, F. E., Lobanova, S. Yu., Yelubaev, B. Ye., et al. (2021) Effective eor methods in high-viscosity oil fields: Cyclical gel-polymer flooding and ASP flooding. Kazakhstan Journal for Oil & Gas Industry, 3(8), 61-74.
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  32. https://time-in.ru/magnitnye-buri/baku
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DOI: 10.5510/OGP20250201066

E-mail: e.alizade.99@gmail.com.ru


Usama Alameedy1, Ali Rabia2, Hawraa Hamid1

1College of Petroleum Engineering, University of Baghdad, Baghdad, Iraq; 2Wireline Logging Department, COSL Middle East Iraq Branch, Baghdad, Iraq

Enhanced permeability estimation in non-cored wells using a modified flow zone index-permeability crossplot: a case study of carbonate reservoirs


The permeability estimates for the uncored wells and a porosity function adopting a modified flow zone index-permeability crossplot are given in this work. The issues with implementing that approach were mostly crossplots, due to the influence of geological heterogeneity, did not show a clear connection (scatter data). Carbonate reservoir flow units may now be identified and characterized using a new approach, which has been formally confirmed. Due to the comparable distribution and flow of clastic and carbonate rock fluids, this zoning method is most effective for reservoirs with significant primary and secondary porosity. The equations and correlations here are more generalizable since they connect these variables by combining core analysis with log data. The cross-sectional parts of the reservoir are examined in seven zones. The result demonstrates a better connection between this crossplot and traditional crossplot and a more straightforward transformation to estimate permeability in an uncored well to input models for geological and reservoir simulation and six hydraulic flow zones in the field for four wells. Start with this conception; we try to simplify the parameter Swir correlation with the Carmen-Kozeny equation, which varies across flow units but remains constant within each unit; it is added as another parameter influencing permeability. Future full-field simulation models will benefit significantly from this improved permeability estimate, leading to more accurate and reliable performance predictions.

Keywords: flow zone indicator; hydraulic flow unit, permeability; reservoir quality index; multi-resolution graph-based clustering.

Date submitted: 26.02.2025     Date accepted: 06.05.2025

The permeability estimates for the uncored wells and a porosity function adopting a modified flow zone index-permeability crossplot are given in this work. The issues with implementing that approach were mostly crossplots, due to the influence of geological heterogeneity, did not show a clear connection (scatter data). Carbonate reservoir flow units may now be identified and characterized using a new approach, which has been formally confirmed. Due to the comparable distribution and flow of clastic and carbonate rock fluids, this zoning method is most effective for reservoirs with significant primary and secondary porosity. The equations and correlations here are more generalizable since they connect these variables by combining core analysis with log data. The cross-sectional parts of the reservoir are examined in seven zones. The result demonstrates a better connection between this crossplot and traditional crossplot and a more straightforward transformation to estimate permeability in an uncored well to input models for geological and reservoir simulation and six hydraulic flow zones in the field for four wells. Start with this conception; we try to simplify the parameter Swir correlation with the Carmen-Kozeny equation, which varies across flow units but remains constant within each unit; it is added as another parameter influencing permeability. Future full-field simulation models will benefit significantly from this improved permeability estimate, leading to more accurate and reliable performance predictions.

Keywords: flow zone indicator; hydraulic flow unit, permeability; reservoir quality index; multi-resolution graph-based clustering.

Date submitted: 26.02.2025     Date accepted: 06.05.2025

References

  1. Al-Yaseri, A. Z., Sattam, M., Alameedy, U. (2013). Improve permeability prediction for one of Iraqi carbonate oil reservoir. Journal of University of Babylon, 21(February), 1289–1300.
  2. Alameedy, U., Almomen, A., Abd, N. (2023). Evaluating machine learning techniques for carbonate formation permeability prediction using well log data. Iraqi Geological Journal, 56(1D), 175–187.
  3. Winland, H., D. (1972). Oil accumulation in response to pore size changes. In: Field, W., Ed., Amoco Production Research Report, Saskatchewan.
  4. Pittman, E. D. (1992). Relationship of porosity and permeability to various parameters derived from mercury injection-capillary pressure curves for sandstone. AAPG Bulletin, 76(2), 191-198.
  5. Lucia, F. J. (1999). Carbonate reservoir characterization. Berlin Heidelberg: Springer.
  6. Alameedy, U., Farman, G., Al-Tamemi, H. (2023). Mineral Inversion approach to improve Ahdeb Oil Field’s mineral classification. Iraqi Geological Journal, 56(2B), 102–113.
  7. Corbett, P. W. M., Potter, D. (2004). Petrotyping: A basemap and atlas for navigating through permeability and porosity data for reservoir comparison and permeability prediction. SCA2004-30. In: The International Symposium of the Society of Core Analysts, January.
  8. Kurniawan, D. H., Winardi, S., Anggara, F. (2021). Linking between sedimentary facies and petrophysical rock type:  case study. IOP Conference Series: Earth and Environmental Science, 789(1), 012077.
  9. Mohebian, R., Bagheri, H., Kheirollahi, M., Bahrami, H. (2021). Permeability estimation using an integration of multi-resolution graph-based clustering and rock typing methods in an Iranian carbonate reservoir. Journal of Petroleum Science and Technology, 11(3), 49–58.
  10. Rushing, J. A., Newsham, K. E., Blasingame, T. A. (2008, February 10). Rock typing — keys to understanding productivity in tight gas sands. SPE-114164-MS. In: SPE Unconventional Reservoirs Conference, Keystone, Colorado, USA.
  11. Amraei, H., Falahat, R. (2021). Improved ST-FZI method for permeability estimation to include the impact of porosity type and lithology. Journal of Petroleum Exploration and Production Technology, 11(1), 109–115.
  12. Bear, J. (1972). Dynamics of fluids in porous media. Elsevier.
  13. Ebanks, W. J. (1987). The flow unit concept-an integrated approach to reservoir description for engineering projects. American Association of Petroleum Geologists Bulletin, 71, 551–552.
  14. Hearn, C. L., Ebanks, W. J., Tye, R. S., Ranganathan, V. (1984). Geological factors influencing reservoir performance of the Hartzog Draw Field, Wyoming. Journal of Petroleum Technology, 36(08), 1335–1344.
  15. Gunter, G. W., Finneran, J. M., Hartmann, D. J., Miller, J. D. (1997, October 5). Early determination of reservoir flow units using an integrated petrophysical method. SPE-38679-MS. In: SPE Annual Technical Conference and Exhibition, October 5–8.
  16. Schmalz, J. P., Rahme, H. D. (1950). The Variation of waterflood performance with variation in permeability profile. Producers Monthly, 15(No. 9), 9–12.
  17. Law, J. (1944). Statistical approach to the interstitial heterogeneity of sand reservoirs. SPE Transactions, 155(01), 202-222.
  18. Dykstra, H., Parsons, R. L. (1950). The prediction of oil recovery in waterflood. Seconday recovey of oil in the United States. American Petroleum Institute (API).
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  20. Tiab, D., Donaldson, E. C. (2015). Petrophysics: theory and practice of measuring reservoir rock and fluid transport properties (4th Ed.). Gulf Professional Publishing - Elsevier.
  21. Amaefule, J. O., Altunbay, M., Tiab, D., et al. (1993, October 3). Enhanced reservoir description: using core and log data to identify hydraulic (flow) units and predict permeability in uncored intervals/wells. SPE-26436-MS. In: The SPE Annual Technical Conference and Exhibition, Houston, Texas.
  22. Coates, G., Denoo, S. (1981). The producibility answer product. The technical review. Schlumberger.
  23. Mahdy, A., Zakaria, W., Helmi, A., et al. (2024). Machine learning approach for core permeability prediction from well logs in sandstone reservoir, Mediterranean Sea, Egypt. Journal of Applied Geophysics, 220, 105249.
  24. Kumar, V., Banerjee, A., Roy, K. (2024). Breaking the barriers: machine-learning-based c-RASAR approach for accurate Blood–Brain barrier permeability prediction. Journal of Chemical Information and Modeling, 64(10), 4298–4309. 
  25. Ita, K., Roshanaei, S. (2024). Artificial intelligence for skin permeability prediction: deep learning. Journal of Drug Targeting, 32(3), 334–346.
  26. Khalid, M. S., Mansour, A. S., Desouky, S. E.-D. M., et al. (2024). Improving permeability prediction via machine learning in a heterogeneous carbonate reservoir: application to Middle Miocene Nullipore, Ras Fanar field, Gulf of Suez, Egypt. Environmental Earth Sciences, 83(8), 244.
  27. Kang, Q., Li, K.-Q., Fu, J.-L., Liu, Y. (2024). Hybrid LBM and machine learning algorithms for permeability prediction of porous media: A comparative study. Computers and Geotechnics, 168, 106163.
  28. Davari, M. A., Senemari, S., Alimoradi, A., Safavi, S. J. (2024). Permeability prediction from log data using machine learning methods. Journal of Petroleum Geomechanics, 7(3), 1-17.
  29. Kumar, V., Banerjee, A., Roy, K. (2024). Breaking the barriers: Machine-learning-based c-RASAR approach for accurate blood–brain barrier permeability prediction. Journal of Chemical Information and Modeling, 64(10), 4298–4309.
  30. Aftab, N., Masood, F., Ahmad, S., et al. (2024). An optimized deep learning approach for blood-brain barrier permeability prediction with ODE integration. Informatics in Medicine Unlocked, 48, 101526.
  31. Zhao, J., Wang, Q., Rong, W., et al. (2024). Permeability prediction of carbonate reservoir based on nuclear magnetic resonance (NMR) logging and machine learning. Energies, 17(6), 1458.
  32. Ita, K., Prinze, J. (2024). Machine learning for skin permeability prediction: random forest and XG boost regression. Journal of Drug Targeting, 32(1), 57–65.
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DOI: 10.5510/OGP20250201067

E-mail: Usama.sahib@coeng.uobaghdad.edu.iq


Khurram Iqbal1, V. M. Mammadov2

1Dewan Petroleum Limited, Islamabad, Pakistan; 2Scientific-Research Institute of Geo-technological Problems of Oil, Gas and Chemistry, Baku, Azerbaijan

Improving stimulation results in shaly sandstone reservoir after investigating reservoir characteristics: a review


World oil reserves increased rapidly during the decade of 80s due to improved recovery techniques. Stimulation and hydraulic fracturing played a key role in those techniques used to enhance recovery. Stimulation is a sensitive technique to improve production and ultimate recovery, but stimulation of clastic reservoirs is a tedious job due to complex mineralogy of matrix rocks and cement, compared to carbonate rocks. A multidisciplinary approach is essential to stimulate clastic rocks for getting required results. Petrography is one of the vital tools to interpret minerals, but this is not sufficient to identify minerals composing rocks.
Experimental study was conducted to observe the reaction of mineral presets in rocks and stimulation fluids under microscopes. The objective of the study was to highlight the sensitivity of different minerals present in rocks. Petrography and X-ray Diffraction information about composition of sandstone rocks (mineralogy) was obtained in laboratory and this paper mentions the sensitivity of these grains with stimulation fluids of different rates. Mostly sandstones are dominantly composed of Quartz (SiO2), subordinating feldspars ((KAlSi3O8 – NaAlSi3O8 – CaAl2Si2O8) and lithic fragments (sand size fragments of pre-existing rocks). Quartz grains are highly resistive to 15% hydrochloric acid as compared to calcite, carbonaceous, carbonate, minerals. HCl reacts with carbonate and carbonaceous quickly to enhance near borehole permeability. Besides this, when iron minerals (mostly in red color sandstone and act as cement) react with stimulation fluids caused precipitation and permanent damage to the reservoir. Therefore, petrographic information is vital in designing stimulation jobs to minimize formation damage by identification of sensitive minerals to stimulation fluids.

Keywords: stimulation shaly; sandstone reservoir; petrography mineralogy; formation damage.

Date submitted: 08.01.2025     Date accepted: 12.06.2025

World oil reserves increased rapidly during the decade of 80s due to improved recovery techniques. Stimulation and hydraulic fracturing played a key role in those techniques used to enhance recovery. Stimulation is a sensitive technique to improve production and ultimate recovery, but stimulation of clastic reservoirs is a tedious job due to complex mineralogy of matrix rocks and cement, compared to carbonate rocks. A multidisciplinary approach is essential to stimulate clastic rocks for getting required results. Petrography is one of the vital tools to interpret minerals, but this is not sufficient to identify minerals composing rocks.
Experimental study was conducted to observe the reaction of mineral presets in rocks and stimulation fluids under microscopes. The objective of the study was to highlight the sensitivity of different minerals present in rocks. Petrography and X-ray Diffraction information about composition of sandstone rocks (mineralogy) was obtained in laboratory and this paper mentions the sensitivity of these grains with stimulation fluids of different rates. Mostly sandstones are dominantly composed of Quartz (SiO2), subordinating feldspars ((KAlSi3O8 – NaAlSi3O8 – CaAl2Si2O8) and lithic fragments (sand size fragments of pre-existing rocks). Quartz grains are highly resistive to 15% hydrochloric acid as compared to calcite, carbonaceous, carbonate, minerals. HCl reacts with carbonate and carbonaceous quickly to enhance near borehole permeability. Besides this, when iron minerals (mostly in red color sandstone and act as cement) react with stimulation fluids caused precipitation and permanent damage to the reservoir. Therefore, petrographic information is vital in designing stimulation jobs to minimize formation damage by identification of sensitive minerals to stimulation fluids.

Keywords: stimulation shaly; sandstone reservoir; petrography mineralogy; formation damage.

Date submitted: 08.01.2025     Date accepted: 12.06.2025

References

  1. Testa, S. M. (2016, October 2-5). Historical development of well stimulation and hydraulic fracturing technologies. In: 2016 AAPG Pacific Section and Rocky Mountain Section Joint Meeting, Las Vegas, Nevada.
  2. William, B. B., Gidley, J. L, Schschter, R. S. (1979). Acidizing fundamentals. Monograph. Vol. 6. Dallas, TX: Society of Petroleum Engineers.
  3. Suleimanov, B. A., Guseynova, N. I., Rzayeva, S. C., Tuleshova, G. D. (2017). Results of acidizing injection wells on the Zhetybai field (Kazakhstan). Petroleum Science and Technology, 36(3), 193-199.
  4. Suleimanov, B. A., Rzayeva, S. C., Akhmedova, U. T. (2021). Self-gasified biosystems for enhanced oil recovery. International Journal of Modern Physics B, 35(27), 2150274.
  5. Muffler, P., Cataldi, R. (1978). Methods for regional assessment of geothermal resources. Geothermics, 7(2–4), 53-89.
  6. Al-Harthy, S. (2008/2009). Options for high-temperature well stimulation. Oil Field Review, 20(4), 52–62.
  7. Kersey, D. G. (1986, March 17-20). The role of petrographic analysis in the design of non-damaging drilling, completion, and stimulation programs. SPE-14089-MS. In: International Meeting on Petroleum Engineering, Beijing, China.
  8. Salavatov, T. Sh., Iqbal, K. (2018). Analysis of the influence of a massive hydraulic fracturing with control of water breakthrough. Oilfield Engineering, 6, 31-36.
  9. Zhou, L., Nasr-El-Din, H. A. (2014). Acidizing sandstone formations using a sandstone acid system for high temperatures. SPE-165084-MS. In: SPE European Formation Damage Conference & Exhibition, Noordwijk, The Netherlands. Society of Petroleum Engineers.
  10. Zhou, Z., Wang, X., Zhao, Z., et al. (2007). New formula for acid fracturing in low permeability gas reservoirs. Experimental study and field application. Journal of Petroleum Science and Engineering, 59, 257–262.
  11. Shafiq, M. U., Mahmud, H. K. B., Rezaee, R. (2017). New acid combination for a successful sandstone acidizing. In: IOP Conference Series: Materials Science and Engineering, 206, 012010.
  12. Abdelmoneim, S. S., Nasr-El-Din, H. A. (2015). Determining the optimum HF concentration for stimulation of high temperature sandstone formations. SPE-174203-MS. In: SPE European Formation Damage Conference and Exhibition, Budapest, Hungary. Society of Petroleum Engineers.
  13. Farley, J. T., Miller, B. M., Schoettle, V. (1970). Design criteria for matrix stimulation with hydrochloric-hydrofluoric acids. SPE JPT, 22, 433-440.
  14. Van Hong, L., Mahmud, H. B. (2017). A comparative study of different acids used for sandstone acid stimulation: A literature review. International Conference on Materials Technology and Energy IOP Publishing. IOP Conference Series: Materials Science and Engineering, 217, 012018.
  15. Al-Dahlan, M. N., Nasr-El-Dinh, A., Al-Qahtani, A. A. (2001). Evaluation of retarded HF acid systems. In: SPE International Symposium Oilfield Chemistry, Houston, Texas.
  16. Kline, W. E., Fogler, H. S. (1981). Dissolution kinetics: The nature of the particle attack of layered silicates in HF. Chemical Engineering Science, 36(5), 871-884.
  17. Sutton, G. D., Lastar, A. R. (1972). Aspects of acid additive selection in sandstone acidization. SPE-4114-MS. In: Fall Meeting of the Society of Petroleum Engineers of AIME, San Antonio, Texas.
  18. Malate, R. C. M., Austria, J. J. C., Sarmiento, Z. F., et al. (1998, January 26-28). Matrix stimulation treatment of geothermal
    wells using sandstone acid. In: 23rd Workshop on Geothermal Reservoir Engineering, Stanford, California, USA.
  19. Malate, R. C. M., Yglopaz, D. M., Austria, J. J. C., et al. (1997, January 27-29). Acid stimulation of injection wells in the Leyte geothermal power project, Philippines. In: 22nd Workshop on Geothermal Reservoir Engineering, Stanford, California, USA.
  20. Suleimanov, B. A., Abbasov, H. F. (2025). Gasified acid solution in pre-transition state for well stimulation. Journal of Dispersion Science and Technology, Published online: 10 Jan.
  21. Hemeida, A. M., Awad, M. N. J. (1997, December). Stimulation of sandstone formations any mud acid. In: Al-Azher Engineering Fifth International Conference.
  22. Cikes, M., Vranješevic, B., Tomic, M., Jamnicky, O. (1990). A successful treatment of formation damage caused by high-density brine. SPE Production Engineering, 5(02), 175-179.
  23. Smith, C. F., Hendrickson, A. R. (1965). Hydrofluoric acid stimulation of sandstone reservoirs. SPE JPT, 17(02), 215-222. 
  24. Shafique, M. U., Mahmud, H. B. (2017). Sandstone matrix acidizing knowledge and future development. Journal of Petroleum Exploration, Production and Technology, 7, 1205-1216.
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DOI: 10.5510/OGP20250201068

E-mail: khurram@dewanpetroleum.com


S. A. Rza-zade1, R. S. Ibrahimov1, Sh. O. Bahshaliyeva1, Z.R. Ibrahimov2

1Azerbaijan State Oil and Industry University, Baku, Azerbaijan; 2«Expro Group», Baku, Azerbaijan

Results of the analysis of modern equipment for testing formations in oil and gas fields of the Caspian sea


The article considers in providing barrier between the production fluid and environment. Subsea test tree has 2 ball valves which can prevent blow out in case of abnormal pressure reachs to surface, also isolate well, unlatch and semi subor drill ship can relocate on safe zone. To control the operation of the formation tester, it is necessary to equip it with monometers located in separate sections of the formation tester system. When working with these formation testers, it was necessary to regularly obtain, over a certain period of time, the pressure values (both behind the column and inside) that arise during its operation, which presents certain difficulties, especially when operating this system in offshore conditions. The system has couple of unique features that will tie into the surface well test system and rig. The emergency shut down system is a vital part of the surface welltest equipment. It allows the flow of the well to be stopped in the event of problems occurring at surface and relocate platform into safe zone. Prior to running the equipment, testing should be carried out to allow hardware failures to be tested, including loss of trigger line pressure, loss of subsea electronic module, loss of enhanced data acquisition system surface card and loss of a human
machine interface. These tests may be performed by physically disconnecting each device in turn and confirming the expected behavior. It is recommended that the testing should also include a test where the trigger line pressure is raised, triggerlLine rapid vent option enabled, and then the trigger line pressure reduced below the trigger pressure to initiate a triiger line rapid vent – this may be done without the valve mechanism.

Keywords: subsea; shear rams; well; hydraulic; lubricator valves; platform.

Date submitted: 08.07.2024     Date accepted: 07.05.2025

The article considers in providing barrier between the production fluid and environment. Subsea test tree has 2 ball valves which can prevent blow out in case of abnormal pressure reachs to surface, also isolate well, unlatch and semi subor drill ship can relocate on safe zone. To control the operation of the formation tester, it is necessary to equip it with monometers located in separate sections of the formation tester system. When working with these formation testers, it was necessary to regularly obtain, over a certain period of time, the pressure values (both behind the column and inside) that arise during its operation, which presents certain difficulties, especially when operating this system in offshore conditions. The system has couple of unique features that will tie into the surface well test system and rig. The emergency shut down system is a vital part of the surface welltest equipment. It allows the flow of the well to be stopped in the event of problems occurring at surface and relocate platform into safe zone. Prior to running the equipment, testing should be carried out to allow hardware failures to be tested, including loss of trigger line pressure, loss of subsea electronic module, loss of enhanced data acquisition system surface card and loss of a human
machine interface. These tests may be performed by physically disconnecting each device in turn and confirming the expected behavior. It is recommended that the testing should also include a test where the trigger line pressure is raised, triggerlLine rapid vent option enabled, and then the trigger line pressure reduced below the trigger pressure to initiate a triiger line rapid vent – this may be done without the valve mechanism.

Keywords: subsea; shear rams; well; hydraulic; lubricator valves; platform.

Date submitted: 08.07.2024     Date accepted: 07.05.2025

References

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DOI: 10.5510/OGP20250201069

E-mail: sameddrilling7@gmail.com


V. M. Fataliyev1, N. N. Hamidov2, K. F. Aliyev1

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

Advances in understanding and controlling liquid loading in gas-condensate production well


Gas-condensate production wells frequently encounter retrograde condensation as a result of significant pressure and temperature changes during production, which disrupts mass conservation, alters fluid composition, and changes flow regimes along the wellbore and production tubing with depth. This phenomenon can lead to liquid accumulation, resulting in reduced gas flow rates at the bottomhole zone and unstable well operation. The transition from annular to slug flow regimes typically marks the onset of liquid loading, which poses risks to well integrity and may ultimately lead to production failure. This paper reviews the conventional understanding of well liquid loading and explores various deliquification techniques used to mitigate its impact. Based on detailed analysis, introduces a novel pipe element and an automated control system designed to maintain stable production in gas-condensate wells. The pipe element helps sustain constant mass flow through the production tubing and effectively prevents liquid loading. Laboratory testing of this element demonstrated a 20–40 % improvement in production stability. The automated control system enables real-time synchronization between the choke valve and the pressure differential between the wellhead and bottomhole, ensuring optimal gas flow rates. It functions by continuously monitoring changes in wellhead and downhole pressures, comparing them to predefined optimal values, and adjusting flow conditions accordingly. Overall, this integrated control approach has shown promising results in simulation scenarios and offers a practical solution for improving production efficiency and operational reliability in gas-condensate wells. The presented research advances scientific and theoretical understanding of the fluid loading process in gas-condensate production wells and introduces practical, more easily applicable technologies aimed at ensuring smooth well operation within normal operating limits. 

Keywords: gas-condensate reservoir; retrograde condensation; liquid loading; vertical flow regimes; automatic control system.

Date submitted: 04.03.2025     Date accepted: 14.05.2025

Gas-condensate production wells frequently encounter retrograde condensation as a result of significant pressure and temperature changes during production, which disrupts mass conservation, alters fluid composition, and changes flow regimes along the wellbore and production tubing with depth. This phenomenon can lead to liquid accumulation, resulting in reduced gas flow rates at the bottomhole zone and unstable well operation. The transition from annular to slug flow regimes typically marks the onset of liquid loading, which poses risks to well integrity and may ultimately lead to production failure. This paper reviews the conventional understanding of well liquid loading and explores various deliquification techniques used to mitigate its impact. Based on detailed analysis, introduces a novel pipe element and an automated control system designed to maintain stable production in gas-condensate wells. The pipe element helps sustain constant mass flow through the production tubing and effectively prevents liquid loading. Laboratory testing of this element demonstrated a 20–40 % improvement in production stability. The automated control system enables real-time synchronization between the choke valve and the pressure differential between the wellhead and bottomhole, ensuring optimal gas flow rates. It functions by continuously monitoring changes in wellhead and downhole pressures, comparing them to predefined optimal values, and adjusting flow conditions accordingly. Overall, this integrated control approach has shown promising results in simulation scenarios and offers a practical solution for improving production efficiency and operational reliability in gas-condensate wells. The presented research advances scientific and theoretical understanding of the fluid loading process in gas-condensate production wells and introduces practical, more easily applicable technologies aimed at ensuring smooth well operation within normal operating limits. 

Keywords: gas-condensate reservoir; retrograde condensation; liquid loading; vertical flow regimes; automatic control system.

Date submitted: 04.03.2025     Date accepted: 14.05.2025

References

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  14. Abdullayev, V. J., Ibrahimov, Kh. M., Kyazimov, F. K., Shafiyev, T. Kh. (2016). Experimental studies on gas drive and gas-and-water oil displacement. SOCAR Proceedings, 1, 51-77.
  15. Abdullayev, V. J., Alieva, N. T., Gamzaeva, N. Kh., Gamzaev, Kh. M. (2022). About one model of infiltration of oil and petroleum products into the ground during their spills. SOCAR Proceedings, SI2, 72-77.
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  25. Ismayilov, G. G., Fataliyev, V. M., Iskenderov, E. Kh. (2019). Investigating the impact of dissolved natural gas on the flow characteristics of multicomponent fluid in pipelines. Open Physics, 17(1), 206-213.
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    of two-phase fluid flow in compacting gas condensate reservoirs using potential flow theory. Scientific Petroleum, 1, 29-35.
  31. Luo, S., Kelkar, M., Pereyra, E., et al. (2014). A new comprehensive model for predicting liquid loading in gas wells. SPE-172501-PA. SPE Production & Operations, 29(04), 337–349.
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  34. Fataliyev, V. M., Hamidov, N. N., Aliyev, K. F. (2023). Methods for optimizing the operation of a gas condensate well under retrograde condensation condition. In: The International Scientific Conference Dedicated to the 100th Anniversary of the Birth of National Leader Heydar Aliyev, ASOIU, Baku, Azerbaijan.
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  39. Drozdov, A. N., Bulatov, G. G., Lapoukhov, A. N., et al. (2012). Artificial-lift operation technologies of low-pressure flooded gas and gas-condensate wells. SPE-158287-MS. In: The SPETT Energy Conference and Exhibition, Port-of-Spain, Trinidad.
  40. Ismayilov, Q. Q., Fataliyev, V. M., Iskenderov, E. X., et al. (2022). The maintenance of stable operation of a pipeline keeping natural gas in disperse state. Azerbaijan Oil Industry, 8, 35-40.
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DOI: 10.5510/OGP20250201070

E-mail: natiq.hamidov@socar.az


N. M. Temirbekov1,4, A. K. Turarov2, F. A. Aliev3, A. N. Temirbekov1,4

1Al-Farabi Kazakh National University, Almaty, Kazakhstan; 2D. Serikbayev East Kazakhstan Technical University, Ust-Kamenogorsk, Kazakhstan; 3Institute of Applied Mathematics of Baku State University, Baku, Azerbaijan; 4National Engineering Academy of the Republic of Kazakhstan, Almaty, Kazakhstan

Solution of the direct and inverse problem of gas lift oil production process by the optimal control method


The article presents a numerical method for solving the direct and inverse problems of the gas-lift process of oil production described by one-dimensional Navier-Stokes equations for compressible gas. To solve the direct problem, a family of difference schemes was developed and an analysis of the correctness of the difference problem was carried out depending on the parameter. The solution of the inverse problem is reduced to an optimal control problem, where the target functional is formed using an additional condition. To minimize the target functional, the gradient method is used, and its gradient is calculated by solving the conjugate problem. The conjugate problem contains important information about the solution of the direct problem and is based on the Lagrange identity and the condition of equality to zero of the integral terms. A feature of the conjugate problem is its retrospective nature, since the additional condition on the volumetric gas flow rate and pressure is specified at a certain point in time. The iteration method determines the initial conditions for the volumetric gas flow rate and pressure through the solution of the conjugate retrospective problem. The conducted computational experiment confirmed that the proposed algorithm can be used to determine the initial values of the volumetric gas flow rate and pressure with high accuracy under a given additional condition. The developed method also allows plotting the performance curve of the gas lift process.

Keywords: gas-lift oil production process; Navier-Stokes equations; conjugate equation; inverse problem; optimal control; gradient method; finite-difference method.

Date submitted: 03.03.2025     Date accepted: 13.05.2025

The article presents a numerical method for solving the direct and inverse problems of the gas-lift process of oil production described by one-dimensional Navier-Stokes equations for compressible gas. To solve the direct problem, a family of difference schemes was developed and an analysis of the correctness of the difference problem was carried out depending on the parameter. The solution of the inverse problem is reduced to an optimal control problem, where the target functional is formed using an additional condition. To minimize the target functional, the gradient method is used, and its gradient is calculated by solving the conjugate problem. The conjugate problem contains important information about the solution of the direct problem and is based on the Lagrange identity and the condition of equality to zero of the integral terms. A feature of the conjugate problem is its retrospective nature, since the additional condition on the volumetric gas flow rate and pressure is specified at a certain point in time. The iteration method determines the initial conditions for the volumetric gas flow rate and pressure through the solution of the conjugate retrospective problem. The conducted computational experiment confirmed that the proposed algorithm can be used to determine the initial values of the volumetric gas flow rate and pressure with high accuracy under a given additional condition. The developed method also allows plotting the performance curve of the gas lift process.

Keywords: gas-lift oil production process; Navier-Stokes equations; conjugate equation; inverse problem; optimal control; gradient method; finite-difference method.

Date submitted: 03.03.2025     Date accepted: 13.05.2025

References

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DOI: 10.5510/OGP20250201071

E-mail: t010183@gmail.com


R. Z. Akchurin1, F. F. Davletshin1, A. Sh. Ramazanov1, R. A. Valiullin1, R. F. Sharafutdinov1, F. I. Ibadov2

1Ufa University of Science and Technology, Ufa, Russia; 2SOCAR, Baku, Azerbaijan

Application of active thermometry technology in the determination of the behind-the-casing flow into upper aquifer


Based on the results of numerical mathematical modeling, the application of active thermometry technology to determine of the behind-the-casing flow into upper aquifer is considered. The technology of active thermometry be confined in local induction heating of a section of a metal casing in a well, recording the temperature of the inner wall of the casing at the heating site, as well as above and below it. Mathematical modeling is based on the numerical solution of the Navier-Stokes equations and heat transfer equations, taking into account convection, thermal conductivity and a heat source in the Ansys Fluent software package. Two variants are modeled, in the first variant there is gas in the well in the logged section, in the second – water, which corresponds to a different position of the fluid level in the well relative to the logged section. The criteria are shown to determine the presence of the behind-the-casing flow on a series of surveys of the casing temperature distribution in depth: the asymmetry of the casing temperature distribution curves in depth relative to the middle of the heating section, the movement of the maximum point on the temperature curves in time upward in the direction of the behind-the-casing flow. It is shown that the results of surveys the temperature of the casing wall (in depth, in time) can be used to quantify the flow rate of the behind-the-casing flow.

Keywords: active thermometry; temperature field; induction heating; aquifer; ecological monitoring; behind-the-casing flow.

Date submitted: 17.10.2024     Date accepted: 10.04.2025

Based on the results of numerical mathematical modeling, the application of active thermometry technology to determine of the behind-the-casing flow into upper aquifer is considered. The technology of active thermometry be confined in local induction heating of a section of a metal casing in a well, recording the temperature of the inner wall of the casing at the heating site, as well as above and below it. Mathematical modeling is based on the numerical solution of the Navier-Stokes equations and heat transfer equations, taking into account convection, thermal conductivity and a heat source in the Ansys Fluent software package. Two variants are modeled, in the first variant there is gas in the well in the logged section, in the second – water, which corresponds to a different position of the fluid level in the well relative to the logged section. The criteria are shown to determine the presence of the behind-the-casing flow on a series of surveys of the casing temperature distribution in depth: the asymmetry of the casing temperature distribution curves in depth relative to the middle of the heating section, the movement of the maximum point on the temperature curves in time upward in the direction of the behind-the-casing flow. It is shown that the results of surveys the temperature of the casing wall (in depth, in time) can be used to quantify the flow rate of the behind-the-casing flow.

Keywords: active thermometry; temperature field; induction heating; aquifer; ecological monitoring; behind-the-casing flow.

Date submitted: 17.10.2024     Date accepted: 10.04.2025

References

  1. Ramazanov, A. Sh., Kosmylin, D. V., Akchurin, R. Z., et al. (2024). Active thermometry technology for solving environmental problems in oil and gas fields. Geology, Geophysics and Development of Oil and Gas Fields, 3(387), 57-62.
  2. Dzyublo, A. D., Ruban, G. N. (2018). Reliable diagnostics and liquidation of behind casing flows as an ecological safety guarantee during the oil and gas fields development. Actual Problems of Oil and Gas, 4(23), 56.
  3. Aslanyan, A. M., Aslanyan, I. Yu., Maslennikova, Yu. S., et al. (2016). Detection of behind-casing gas flows using integrated high-precision temperature logging, spectral noise logging, and pulsed neutron logging toolstring. Oil and Gas Territory, 6, 52-59.
  4. Lutfullin, A. A., Abdrahimov, A. R., Shigapov, I. N., et al. (2014). Identification of behind-casing flowing reservoir intervals by the integrated high-precision temperature and spectral noise logging techniques. SPE-171251-MS. In: SPE Russian Oil and Gas Exploration and Production Technical Conference and Exhibition. Society of Petroleum Engineers. 
  5. Ramazanov, A. Sh. (2023). Analytical models in borehole thermometry. Moscow: Infra-M.
  6. Arbuzov, A. A., Alekhin, A. P., Bochkarev, V. V., et al. (2012). Memory pulsed neutron-neutron logging. SPE162074-MS. In: SPE Russian Oil and Gas Exploration and Production Technical Conference and Exhibition. Society of Petroleum Engineers. 
  7. Nagimov, V., Alekseev, A., Tolmachev, E., et al. (2018). Prospects for the spectral noise logging application in the analysis of stimulated reservoir volume in horizontal wells with multistage fracturing. SPE-191488-MS. In: SPE Russian Petroleum Technology Conference. Society of Petroleum Engineers.
  8. Kosmylin, D. V., Davletshin, F. F., Islamov, D. F., et al. (2023). Experimental study of the thermal field in the wellbore during induction heating. Petroleum Engineering, 21(2), 56-64.
  9. Yarullin, A. R., Yarullin, R. K., Gayazov, M. S., et al. (2024). Interpretation peculiarities of spectral noise logging data based on the results of studying existing horizontal wells. Herald of the Academy of Sciences of the Republic of Bashkortostan, 51, 2(114), 32-42.
  10. Valiullin, R. A., Sharafutdinov, R. F., Fedotov, V. Ya., et al. (2017). Studies of temperature field in wellbore during induction heating of the casing pipe with behind-the-casing fluid flow channels. Tyumen State University Herald. Physical and Mathematical Modeling. Oil, Gas, Energy, 3(3), 17-28.
  11. Valiullin, R. A., Sharafutdinov, R. F., Ramazanov, A. Sh., et al. (2024). Experience and prospects for the use of active thermometry in quantitative diagnostics of the condition of the well and formation. Oil. Gas. Novation, 3(280), 27-31.
  12. Kosmylin, D. V., Fedotov, V. Ya. (2024). Development of an equivalent 3-core logging cable for testing equipment for “active thermometry”. Herald of the Academy of Sciences of the Republic of Bashkortostan, 53(4), 25-32.
  13. Rymarenko, K., Nukhaev, M., Grishchenko, S., et al. (2020). Test results of active thermometry technology using a distributed temperature measurement system. SPE-202040-MS. In: SPE Russian Petroleum Technology Conference, Virtual, October. Society of Petroleum Engineers.
  14. Yarullin, R. K., Yarullin, A. R., Gayazov, M. S. (2019). Concept of applying the temperature marker method in horizontal wells under multiphase flow conditions. PROneft. Professionally About Oil, 1(11), 7-11.
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  19. Ramazanov, A. Sh. Davletshin, F. F., Akchurin, R. Z., et al. (2023). Temperature dynamics in a well during local induction heating of the well casing. Journal of Applied Mechanics and Technical Physics, 64(2), 208-215.
  20. Davletshin, F. F., Akchurin, R. Z., Sharafutdinov, R. F., et al. (2023). Nonisothermal fluid flow in a well during induction heating of the casing string. Fluid Dynamics, 58(4), 586-597.
  21. Bergman, Th. L., Lavine, A. S., Incropera, F. P., et al. (2006). Fundamentals of heat and mass transfer. 8th ed. USA: University of Notre Dame.
  22. Akchurin, R. Z., Davletshin, F. F., Islamov, D. F., et al. (2023). Temperature field in a well with casing induction heating: considering the natural convection influence. Thermophysics and Aeromechanics, 30(3), 487-498.
  23. Akchurin, R. Z., Davletshin, F. F., Ramazanov, A. Sh., et al. (2023). Thermal field in the well during induction heating of the casing under conditions of low flow velocity. Bulletin of the Tomsk Polytechnic University. Geo Assets Engineering, 334(2), 87-98.
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  25. Davletshin, F. F., Islamov, D. F., Khabirov, T. R., et al. (2023). The study of heat exchange processes during induction heating of the casing string in relation to the determination of behind-the-casing flows. Tyumen State University Herald. Physical and Mathematical Modeling. Oil, Gas, Energy, 9(1), 60-77.
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DOI: 10.5510/OGP20250201072

E-mail: ac4urin.ruslan@yandex.ru


M. A. Hajiyev1, I. G. Huseynov2, U. M. Hajiyeva3, S. R. Bashirzade1

1Azerbaijan University of Architecture and Construction, Baku, Azerbaijan; 2Azerbaijan State University of Oil and Industry, Baku, Azerbaijan; 3«OilGasScientificResearchProject» Institute, SOCAR, Baku, Azerbaijan

Structural performance of marine circular reinforced concrete piers under axial loading


In this study, an analytical framework was developed for the analysis of the structural behavior of marine circular RC piers under axial compressive loads, accounting for material and geometric nonlinearities. The proposed methodology includes the biaxial stress-strain relationships of concrete and reinforcement within the anisotropic behavior that these materials exhibit under loads. With this type of methodology, it is possible to model critical factors such as concrete cracking, reinforcement yielding, and material interactions. In addition, geometric influences, including slenderness and stability, were analyzed to properly understand pier performance. A parametric study was extended to the influence of the main design parameters, namely, concrete compressive strength, pier height, and reinforcement ratio. Indeed, higher classes of concrete strength provide an important increase in the load-bearing capacity and improvement in structural behavior. The same trends were observed with respect to the variation in pier height, which directly affects the slenderness ratios and stability parameters, indicating geometrical dimensioning optimization in the process of structural design. The reinforcement ratio has a positive effect on the critical stress distribution and enhancement of the critical load capacity. Subsequently, a series of FEA using the DIANA program was performed to verify the analytical framework. As a result, all the FEA results featured by good correspondences against such an analytical prediction are provided in proving the effectiveness of the proposed method with a sufficient degree of precision. This alignment underlines the effectiveness of the analytical approach for understanding the complex behavior of RC piers subjected to axial compression. 

Keywords: marine structures; offshore structures; circular reinforced concrete piers; axial compression; slenderness; finite element analysis (FEA); load-bearing capacity; stability.

Date submitted: 06.01.2025     Date accepted: 05.05.2025

In this study, an analytical framework was developed for the analysis of the structural behavior of marine circular RC piers under axial compressive loads, accounting for material and geometric nonlinearities. The proposed methodology includes the biaxial stress-strain relationships of concrete and reinforcement within the anisotropic behavior that these materials exhibit under loads. With this type of methodology, it is possible to model critical factors such as concrete cracking, reinforcement yielding, and material interactions. In addition, geometric influences, including slenderness and stability, were analyzed to properly understand pier performance. A parametric study was extended to the influence of the main design parameters, namely, concrete compressive strength, pier height, and reinforcement ratio. Indeed, higher classes of concrete strength provide an important increase in the load-bearing capacity and improvement in structural behavior. The same trends were observed with respect to the variation in pier height, which directly affects the slenderness ratios and stability parameters, indicating geometrical dimensioning optimization in the process of structural design. The reinforcement ratio has a positive effect on the critical stress distribution and enhancement of the critical load capacity. Subsequently, a series of FEA using the DIANA program was performed to verify the analytical framework. As a result, all the FEA results featured by good correspondences against such an analytical prediction are provided in proving the effectiveness of the proposed method with a sufficient degree of precision. This alignment underlines the effectiveness of the analytical approach for understanding the complex behavior of RC piers subjected to axial compression. 

Keywords: marine structures; offshore structures; circular reinforced concrete piers; axial compression; slenderness; finite element analysis (FEA); load-bearing capacity; stability.

Date submitted: 06.01.2025     Date accepted: 05.05.2025

References

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  17. Hadi, M. N. S., Karim, H. F., Sheikh, M. N. S. (2016). Experimental investigations on circular concrete columns reinforced with GFRP bars and helices under different loading conditions. Journal of Composites for Construction, 20(4), 04016009.
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  19. Hajiyev, M. A., Damirov, M. M. (2023). Stress-strain state and bearing capacity of compressed reinforced concrete elements of annular section. Architectural Studies, 9(2), 35–46.
  20. Hajiyev, M. A., Damirov, M.M. (2024). Construction of the «Moment-Curvature» scheme for annular cross-sectional reinforced concrete elements and its application in the calculation of reinforced concrete beams. HERALD of the Azerbaijan Engineering Academy, 16(1), 56–69.
  21. Hajiyeva, U. M. (2021). Calculation of compressed reinforced concrete elements with a circular cross section according to a nonlinear deformation model. Expert: Theory and Practice, 5(14)), 13-20.
  22. Hajiyeva, U. M. (2020). Calculation of a compressed reinforced concrete element with a circular cross section using a three time concrete compression scheme. In: The 3rd International Conference on Building Innovations, Springer International Publishing.
  23. Hajiyeva, U. M. (2021). Stress deformation state and load-bearing capacity of circular cross-sectional compressed reinforced concrete elements based on two-line diagrams of materials. Construction and Architecture in Azerbaijan, 3, 9–15.
  24. Pavlikov, A., Kochkarev, D., Harkava, O. (2019). Analysis of eccentrically loaded members of circular cross section by nonlinear deformation model. In: International Conference Building Innovations. Cham: Springer International Publishing.
  25. Kodysh, E. N., Nikitin, I. K., Trekin, N. N. (2010). Calculation of reinforced concrete structures of heavy concrete on strength, cracking and deformations. Monograph. Moscow: Association of Construction Universities.
  26. Kolmogorov, A. G., Plevkov, V. S. (2014). Calculation of reinforced concrete structures according to Russian and foreign norms. Мoscow: ASV.
  27. Krishan, A. L., Krishan, M. A. (2014). Influence of flexibility on bearing capacity of compressed reinforced concrete elements. Khabarovsk: Pacific State University.
  28. Murashkin, G. V., Mordovsky, S. S. (2013). Application of deformation diagrams for calculation of load-bearing capacity of off-centre compressed reinforced concrete elements. Housing Construction, 3, 38–40.
  29. Rimshin, V. I., Krishan, A. L., Mukhametzyanov, A. I. (2015). Constructing a deformation diagram of uniaxially compressed concrete. Proceedings of Moscow State University of Civil Engineering, 6, 23-31.
  30. Starishko, I. N. (2014). Methods for determining the carrying capacity of eccentrically compressed concrete elements. Proceedings of Moscow State University of Civil Engineering, 4, 59–69.
  31. SP 63.13330.2018. (2018). Concrete and reinforced concrete structures. General provisions. Moscow: JSC SIC Construction. A.A. Gvozdev NIIZhB.
  32. Ferreira, D., Manie, J. (2022). DIANA - Finite element analysis: DIANA Documentation - Release 10.4. DIANA FEA BV.
  33. Ferreira, D. (2013) A model for the nonlinear, time-dependent and strengthening analysis of shear critical frame concrete structures. Doctoral Thesis. Universitat Politècnica de Catalunya.
  34. Bashirzade, S., Ozcan, O., Cagdas, I. U. (2024). Internal force transfer in segmental RC structures. Research on Engineering Structures & Materials, 10(4), 1639-1662.
  35. Chai, S. (2020) Finite element analysis for civil engineering with DIANA software. Singapore: Springer Nature.
  36. Bashirzade, S. R., Lipin, A. A., Hajiyev, M. A., et al. (2024). Fire resistance of offshore concrete structures. SOCAR Proceedings, 4, 79-84.
  37. Aslanov, L. F., Aslanlı, U. L. (2024). Study of marine hydraulic structures under seismic effects. In: Ksibi, M., et al. Recent advances in environmental science from the Euro-Mediterranean and surrounding regions. EMCEI 2022. Advances in Science, Technology & Innovation. Springer, Cham.
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DOI: 10.5510/OGP20250201073

E-mail: hajiyevmuxlis@mail.ru


V. M. Abbasov1, L. M. Afandiyeva1, Yu. P. Cherepnova1, A. M. Mammadov1,2, S. F. Ahmadbayova1, N. M. Aliyeva1, G. G. Nasibova1, D. B. Agamaliyeva1,3

1Y. H. Mamedaliyev’s Institute of Petrochemical Processes of the Ministry of Science and Education, Baku, Azerbaijan; 2Sumgayit State University, Sumgayit, Azerbaijan; 3Azerbaijan State Oil and Industry University, Baku, Azerbaijan

Study of physico-chemical characteristics of the bitumen obtained by aerobic catalytic oxidation of oil tar


The article considers the way to improve the quality of bitumen. In order to improve the quality characteristics of bitumen, the authors propose introducing special additive (catalyst-modifier) into the tar during its oxidation. The effect of a manganese-containing catalyst synthesized on the basis of petroleum acids on the rate of obtaining road bitumen from petroleum tar by means of a liquid-phase oxidation process was studied. The conducted studies have established that the introduction of the catalyst in various concentrations (0.1-0.5 wt.%) and a change in the amount of supplied air (0.3-0.6 l/min) leads to an increase in the rate
of bitumen production. Based on the obtained experimental data, the optimal amount of catalyst (0.3 wt.%) and air supply rate (0.6 l/min) at the most acceptable oxidation process temperature of 260±2 °C were determined. Analysis of the elemental composition of the initial tar and the obtained bitumen samples showed that the oxidation process significantly increases the amount of oxygen and reduces the amount of hydrogen. In particular, during oxidation in the presence of a catalyst, the amount of oxygen reaches its maximum level, which confirms the effectiveness of the reaction. The results of structural-group analysis show significant changes in the structure of molecules that occur during oxidation: chain rupture, changes in the ratio of saturated and unsaturated fragments, an increase in the number of substitutions in aromatic nuclei. Thus, the oxidation process carried out in the presence of a catalyst has a more effective and profound effect in terms of structural changes.

Keywords: tar; liquid-phase oxidation; manganese-containing catalyst; road bitumen.

Date submitted: 15.01.2025     Date accepted: 14.05.2025

The article considers the way to improve the quality of bitumen. In order to improve the quality characteristics of bitumen, the authors propose introducing special additive (catalyst-modifier) into the tar during its oxidation. The effect of a manganese-containing catalyst synthesized on the basis of petroleum acids on the rate of obtaining road bitumen from petroleum tar by means of a liquid-phase oxidation process was studied. The conducted studies have established that the introduction of the catalyst in various concentrations (0.1-0.5 wt.%) and a change in the amount of supplied air (0.3-0.6 l/min) leads to an increase in the rate
of bitumen production. Based on the obtained experimental data, the optimal amount of catalyst (0.3 wt.%) and air supply rate (0.6 l/min) at the most acceptable oxidation process temperature of 260±2 °C were determined. Analysis of the elemental composition of the initial tar and the obtained bitumen samples showed that the oxidation process significantly increases the amount of oxygen and reduces the amount of hydrogen. In particular, during oxidation in the presence of a catalyst, the amount of oxygen reaches its maximum level, which confirms the effectiveness of the reaction. The results of structural-group analysis show significant changes in the structure of molecules that occur during oxidation: chain rupture, changes in the ratio of saturated and unsaturated fragments, an increase in the number of substitutions in aromatic nuclei. Thus, the oxidation process carried out in the presence of a catalyst has a more effective and profound effect in terms of structural changes.

Keywords: tar; liquid-phase oxidation; manganese-containing catalyst; road bitumen.

Date submitted: 15.01.2025     Date accepted: 14.05.2025

References

  1. Gureev, A. A. (2018). Oil-based binding materials. Moscow: Nedra.
  2. Piskunov, I. V., Pankin, A. A., Bashkirtseva, N. Yu. (2022). Mathematical modeling of the oxidized petroleum bitumen production process (review). Herald of Technological University, 25(4), 83-93.
  3. Cherepnova, Yu. P. (2024). Road oil bitumens: promising ways for obtaining and controlling properties (review). PPOR, 25(3), 694-703.
  4. Grushova, Е. I., Stan’ko, M. V., Khat’ko, I. N. (2021). Influence of heavy pyrolysis resin on the process of oil tar oxidation. Proceeding of BSTU, Issue 2 - Chemical Engineering, Biotechnologies, Geoecology, 1(241), 57-62.
  5. Usov, B. A., Gorbunova, T.N. (2017). Modern technologies of production of road bitumen. System Technologies, 2, 67-72.
  6. Anupam, K., Akinmade, D., Kasbergen, C., et al. (2023). A state-of-the-art review of natural bitumen in pavement: underlining challenges and the way forward. Journal of Cleaner Production, 382, 134957.
  7. Shrubok, A. O., Grushova, E. I. (2017). Features of liquid phase oxidation of tar in the presence of modifiers. Petrochemistry, 57(5), 545-550.
  8. Ongarbayev, Y. K., Zhambolova, A. B., Tileuberdi, Y., et al. (2019). Oxidation of heavy oil residues in the presence of catalysts and modifiers. Combustion and Plasma Chemistry, 17, 47-56.
  9. Popov, M. R. Chernysheva, E. A., Zuikov, A. V., Kozhevnikova, J. V. (2024). Assessment of the effect of tar additives on properties bitumen. World of Petroleum Products, 3, 42-47.
  10. Sharma, S., Sharma, S., Upadhyay, N. (2019). Modifier based enhancement in physical and chemical properties of bitumen. Oriental Journal of Chemistry, 35(3), 997–1003.
  11. Silkin, V. V., Lupanov, A. P., Rudakova, V. V. (2015). Installations for bitumen modification. STT: Construction Machinery and Technologies, 6, 82-87.
  12. Garashchuk, Yu. A., Grushova, E. I., Kuzemkin, D. V. (2023, April). The influence of a flavored additive to tar on the group composition of oxidizing bitumen. In: Chemistry. Ecology. Urban Studies: Materials of the All-Russian Scientific and Practical Conference. Perm: Publishing House of Perm National Research Polytechnic University.
  13. Abbasov, V. M., Afandiyeva, L. M., Nasibova, G. G., et al. (2024). Synthesis of petroleum acids by oxidation of dearomatized oil distillate. Petroleum Chemistry, 64, 1187-1193.
  14. Christopher, J., Sarpal, A. S., Kapur, G. S., et al. (1996). Chemical structure of bitumen-derived asphaltenes by nuclear magnetic resonance spectroscopy and X-ray diffractometry. Fuel, 75(8), 999-1008.
  15. Teltayev, B. B., Seilkhanov, T. M. (2018). NMR-spectroscopy determination of fragmentary composition of bitumen and its components. Eurasian Chemico-Technological Journal, 20(2), 153-158.
  16. Rossi, C. O., Caputo, P., De Luca, G., et al. (2018). 1H-NMR spectroscopy: a possible approach to advanced bitumen characterization for ındustrial and paving applications. Applied Sciences, 8(2), 229.
  17. Werkovits, S., Bacher, M., Theiner, J., et al. (2022). Construction and building materials multi-spectroscopic characterization of bitumen and its polarity-based fractions. Construction and Building Materials, 352, 128992.
  18. Yolchuyeva, U. J., Abbasov, V. M., Jafarova, R., et al. (2024). Chemical composition and molecular structure of asphaltene in Azerbaijani crude oil: A case study of the Zagli field. Fuel, 373, 132084.
  19. Begak, O. Y., Syroezhko, A. M. (2001). Estimation of quality of petroleum bitumens by NMR spectroscopy and X-ray diffraction. Russian Journal of Applied Chemistry, 74, 881–884.
  20. Michon, L., Martin, D., Planche, J.-P., Hanquet, B. (1997). Estimation of average structural parameters of bitumens by 13C nuclear magnetic resonance spectroscopy. Fuel, 76(1), 9–15.
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DOI: 10.5510/OGP20250201074

E-mail: uta1980@inbox.ru


S. A. Kaverzin1, A. E. Verisokin1, Boudjema Hamada2, Y. K. Dimitriadi1, I. N. Morozova1

1North Caucasus Federal University, Stavropol, Russia; 2University of Boumerdes, Algeria

Substantiation of the methodology for determining the market value of patented developments related to the oil and gas production industry


The given article is devoted to the problem of substantiation of the methodology to determine the market value of patented developments related to the oil and gas industry. The presented results of analytical studies allow concluding that the lag in the development of the Russian market of intangible assets is significant in comparison with not only the developed countries, but also with the developing ones. The article analyzes the existing approaches and methods for assessing the market value of intangible assets. The patented technical and technological solutions associated with the implementation of work on the development and hydrodynamic studies of wells in conditions of weakly cemented reservoirs saturated with high-viscosity oils are substantiated in this article. The market value of the patented development is substantiated: patent № 2131023 «A method for developing, studying wells and intensifying oil and gas inflows and an instrument for its implementation». As a result of this work, a conclusion is made about the possibility to use in calculations the primary indicators which affect the cost of patented developments, contributing to the increase in profits by a licensee during the development of oil and gas wells. In this context, the practical value of the proposed methodology for performing calculations with the purpose to establish the value equivalent for which a patent can be sold is that it can be extended to patents related to jet technology used in oil and gas production for generating foam or aerated liquids.

Keywords: patent; cost of exclusive rights; fluid inflow enhancement; jet equipment.

Date submitted: 17.12.2024     Date accepted: 06.05.2025

The given article is devoted to the problem of substantiation of the methodology to determine the market value of patented developments related to the oil and gas industry. The presented results of analytical studies allow concluding that the lag in the development of the Russian market of intangible assets is significant in comparison with not only the developed countries, but also with the developing ones. The article analyzes the existing approaches and methods for assessing the market value of intangible assets. The patented technical and technological solutions associated with the implementation of work on the development and hydrodynamic studies of wells in conditions of weakly cemented reservoirs saturated with high-viscosity oils are substantiated in this article. The market value of the patented development is substantiated: patent № 2131023 «A method for developing, studying wells and intensifying oil and gas inflows and an instrument for its implementation». As a result of this work, a conclusion is made about the possibility to use in calculations the primary indicators which affect the cost of patented developments, contributing to the increase in profits by a licensee during the development of oil and gas wells. In this context, the practical value of the proposed methodology for performing calculations with the purpose to establish the value equivalent for which a patent can be sold is that it can be extended to patents related to jet technology used in oil and gas production for generating foam or aerated liquids.

Keywords: patent; cost of exclusive rights; fluid inflow enhancement; jet equipment.

Date submitted: 17.12.2024     Date accepted: 06.05.2025

References

  1. Mazur, N. Z., Popova, N. V., Demyanets, E. A. (2024). The value of intangible assets of enterprises of the Russian Federation. VKO-Intellect LLC. https://www.vko-intellekt.ru/media-center/velichina-nematerialnyh-aktivov-predpriyatij-rossii/
  2. Kryukov, V. A., Tokarev, A. N. (2021). Analysis of the knowledge base in the oil and gas sector in Russia: patents for inventions. Voprosy Ekonomiki, 3, 84-99.
  3. Ayerbe, C., Azzam, J., Boussetta, S., et al. (2023). Revisiting the consequences of loans secured by patents on technological firms' intellectual property and innovation strategies. Research Policy, 52(8), 104824.
  4. Cappelli, R., Corsino, M., Laursen, K., et al. (2023). Technological competition and patent strategy: protecting innovation, preempting rivals and defending the freedom to operate. Research Policy, 52(6), 104785.
  5. Li, L., Xin, D., Yang, X., et al. (2025). How does patent portfolio structure affect patent value in different technological environments? Evidence from Chinese high-tech industries. Technological Forecasting and Social Change, 215, 124127.
  6. Arora, A., Cohen, W., Lee, H., et al. (2023). Invention value, inventive capability and the large firm advantage. Research Policy, 52(1), 104650.
  7. (2024). Global Innovation Index. WIPO. https://www.wipo.int/edocs/pubdocs/ru/wipo-pub-2000-2022-exec-ru-globalinnovation-index-2022-15th-edition.pdf
  8. Kalinin, D. V., Pomulev, A. A. (2024). Analysis of the development of the intangible assets market: Russian and foreign realities. Humanities, Socio-Economic and Social Sciences, 4, 211-217.
  9. (2024). Federal State Statistics Service. https://rosstat.gov
  10. Tax Code of the Russian Federation. Part two: official text according to Federal Law of 05.08.2000 No. 117-FZ. https://www.nalog.gov.ru/html/sites/www.eng.nalog.ru/Tax%20Code%20Part%20Two.pdf
  11. Kartskhia, A. A. (2015). Intellectual property rights and technology transfer (at oil and gas enterprises). Moscow: Publishing Center of the Gubkin Russian State University of Oil and Gas.
  12. Civil Code of the Russian Federation. Part four: official text according to Federal Law of 18.12.2006 No. 230-FZ. https://new.fips.ru/upload/medialibrary/Doc_Content/4-civil-code-of-the-russian-federation-part-four.pdf.
  13. Volynets-Russet, E. Ya. (1992). Domestic and foreign trade in inventions and know-how under licensing agreements. Book 1. Moscow: INTERAC.
  14. Kaverzin, S. A., Akopov, A. S. (2023). Methodological aspects of calculating the cost of exclusive rights to intellectual property in the oil and gas industry. Problems of Economics and Management of the Oil and Gas Complex, 2(218), 24-33.
  15. Order of the Ministry of Economic Development of Russia dated 14.04.2022 No. 200 «On approval of federal valuation standards and on amendments to someorders of the Ministry of Economic Development of Russia on federal valuation standards». https://www.wipo.int/wipolex/en/legislation/details/21858.
  16. Leontiev, B. B., Mamadzhanov, H. A. (2012). Evaluation of intangible assets of high-tech enterprises. Moscow: INITs «PATENT».
  17. Baruch, L. (2001). Intangibles: management, measuring and reporting. Brookings Institution Press. 
  18. Lekarkina, N. K. (2017). Application of income approach methods to assess intellectual property. Economic Scientific Journal «Investment Assessment», 1(5), 21-34.
  19. Zubareva, V. D., Gradus, A. E., Martynova, O. A. (2020). Development of methods for assessing the value of a business. Problems of Economics and Management of the Oil and Gas Complex, 4(184), 26-29.
  20. Smith, G. V., Parr, R. L. (2000). Valuation of intellectual property and intangible assets. 3rd Edition. John Willey & Sons Inc.
  21. Verisokin, A. E. (2022). Development of a set of technical means and technological solutions for hydraulic fracturing and development of oil wells. PhD Thesis. Stavropol: North Caucasus Federal University.
  22. Shlein, G. A., Chernov, E., Yu., Semenenko, G. D., et al. (2017). Method for development, well research and stimulation of oil and gas inflows and device for its implementation. RU Patent 2131023.
  23. (2008). Decision of the Government of the Russian Federation No. 941 of December 10. (As amended up to Decision of the Government No. 1676 of October 13, 2020). Russian Federation.
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DOI: 10.5510/OGP20250201075

E-mail: sergei-kaverzin@list.ru


A. I. Mirgeydarova, E. G. Mammadova

Azerbaijan State of Oil and Industry University, Baku, Azerbaijan

Mechanism of strategic management of innovative activity in industry


In countries striving for high industrial development, scientific and economic growth should be carried out mutually. Enterprises and organizations achieve better results by applying high-quality, newer, and more efficient technologies and equipment in production. In modern times, the innovation system is developing at a rapid pace. Innovation refers to the correct and efficient application of technological and scientific advancements in the economy. Another significant factor contributing to the relevance of this issue is the importance of effective innovation management in creating competitive advantages, economic growth, employment opportunities, and increasing sustainability. In the context of rapidly changing economic conditions, increasing globalization, and the merging of economic and political interests, innovation is crucial for the survival of enterprises. Every enterprise faces the necessity to modernize its production system to some extent, search for new opportunities to improve its products, implement innovations, engage in competitive struggle, and work out a development strategy. Thus, the issues of strategic management of innovative activities are highly relevant for modern enterprises. Strategic management is undoubtedly one of the key components of the innovation management system as it is aimed at solving problems related to the planning and implementation of long-term innovation projects. These innovative projects, by their nature, are focused on significant, qualitative changes in the production and commercial activities of an enterprise. Unlike operational management, which ensures the survival of an enterprise in the short term, the strategic management of innovative activity is aimed at gaining leadership positions in business in the long term.

Keywords: innovation; competition; strategy; efficiency; innovation projects; scientific-technical potential.

Date submitted: 21.01.2025     Date accepted: 20.05.2025

In countries striving for high industrial development, scientific and economic growth should be carried out mutually. Enterprises and organizations achieve better results by applying high-quality, newer, and more efficient technologies and equipment in production. In modern times, the innovation system is developing at a rapid pace. Innovation refers to the correct and efficient application of technological and scientific advancements in the economy. Another significant factor contributing to the relevance of this issue is the importance of effective innovation management in creating competitive advantages, economic growth, employment opportunities, and increasing sustainability. In the context of rapidly changing economic conditions, increasing globalization, and the merging of economic and political interests, innovation is crucial for the survival of enterprises. Every enterprise faces the necessity to modernize its production system to some extent, search for new opportunities to improve its products, implement innovations, engage in competitive struggle, and work out a development strategy. Thus, the issues of strategic management of innovative activities are highly relevant for modern enterprises. Strategic management is undoubtedly one of the key components of the innovation management system as it is aimed at solving problems related to the planning and implementation of long-term innovation projects. These innovative projects, by their nature, are focused on significant, qualitative changes in the production and commercial activities of an enterprise. Unlike operational management, which ensures the survival of an enterprise in the short term, the strategic management of innovative activity is aimed at gaining leadership positions in business in the long term.

Keywords: innovation; competition; strategy; efficiency; innovation projects; scientific-technical potential.

Date submitted: 21.01.2025     Date accepted: 20.05.2025

References

  1. Sombart, W. (2005). Selected works. (Series «University library of Alexander Pogorelsky»). Moscow: Territory of the Future.
  2. Santo, B. (1990). Innovation as a means of economic development. Moscow: Progress.
  3. Biryutin, A. S. (2001). Management of technical innovation in industry. Leningrad.
  4. Yakovets, Yu. V. (2021). New paradigm of theory, history and future of the world of civilization. Moscow: MISK-INES.
  5. Valdaytsev, S. V. (2001). Management of innovative business. Textbook for universities. Moscow: UNITY-DANA.
  6. Schumpeter, J. A. (2008). Theory of economic development. Capitalism, socialism and democracy. Moscow: Eksmo.
  7. Kolokolov, V. A. (2002). Innovative mechanisms of functioning of entrepreneurial structures. Management in Russia and Abroad, 1, 95–104.
  8. Mohtarami, A., Hosseini, S. H. Kh., Kandjani, H. (2013). Rethinking the national innovation system functions based on viable system model: a theoretical discussion and a comparative analysis. Middle-East Journal of Scientific Research, 16(10), 1383-1392.
  9. Yashin, S. N., Koshelev, E. V., Kuptsov, A.V. (2011). Development and implementation of the enterprise's innovation and investment strategy: monograph. Nizhny Novgorod: NGTU im. R.Ye. Alekseyeva.
  10. Zub, A. T. (2011). Systemic strategic management: methodology and practice. Moscow: Genesis.
  11. Sviridova, S. V. (2016). Formation of the organizational and economic mechanism for implementing the strategy of innovative development of industrial enterprises. Production Organizer, 1(68), 73-79.
  12. Anisimov, Yu. P. (2015). Prospective directions of strategic development of innovatively active enterprises. Bulletin of the Voronezh State University, 2, 92-98.
  13. Suleymanov, G. S., Kerimov, K. S., Isayev, K. H. (2017). Economic mechanisms of innovative management of industrial sectors: monograph. Baku.
  14. Drucker, P. (1985). Innovations and entrepreneurship. Practice and principles. New York: Harper and Row.
  15. Greene, J. C. (2015). The inequality of performance measurements. Evaluation, 5(2), 160–72.
  16. https://www.weforum.org/reports/the-global-competitiveness-report
  17. https://www.trolex.com /blog/how-to-prepare-for-innovation-in-an-industrial-sector
  18. Tao, L., Probert, D., Phaal, R. (2010). Towards an integrated framework for managing the process of innovation. R&D Management, 40(1), 19–30.
  19. Nolte, W. L., Kennedy, B. C., Dziegiel, R. J. (2003). Technology readiness level calculator. In: NDIA Systems Engineering Conference, October 20.
  20. Paun, F. (2011). Demand readiness level as equilibrium tool for the hybridization between technology push and market pull approaches. Paris: ANR-ERANET Workshop.
  21. Giza, F., Zaytsev, А. А. (2015). Integration of supply chain management subsystem in the innovative activities of high-tech enterprises. Issues of Innovative Economy, 5(3), 63-78.
  22. Hartmann, E., Kerkfeld, D., Henke, M. (2012). Top and bottom line relevance of purchasing and supply management. Journal of Purchasing and Supply Management, 18, 22-34.
  23. Jac, I., Sedlar, J. (2011). Time-series analysis of raw materials consumption as an approach to savings on the working
    capital of the company. In: The Proceedings of the 10th International Conference Liberec Economic Forum, Liberec, Czech Republic.
  24. Jac, I., Sedlar, J., Zaytsev, A.A., et al. (2013). Principles of creating a cost-cutting strategy at an enterprise by means of the lean production concept. E&M Economics and Management, 3, 75-84.
  25. Gasimov, F., Aliyev, T., Najafov, Z. (2013). Organization and management of the national innovation system. Baku: Science and Education.
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DOI: 10.5510/OGP20250201076

E-mail: ai_1280@mail.ru


R. E. Nuriyev, C. J. McFerren

Corvinus University of Budapest, Budapest, Hungary

The current state of the gas industry and the emerging green energy sector in Azerbaijan


Azerbaijan is at the crossroads of its energy development, weighing its traditional position as a leading gas exporter against the increasing trend towards renewable energy. This article examines the interaction between Azerbaijan's fossil fuel industry and its nascent green energy sector, looking at its contribution to European energy security and the shift towards sustainability. This research evaluates the importance of the Southern Gas Corridor in providing EU gas diversification, especially during geopolitical transformations, and measures the renewable energy potential of Azerbaijan. Based on PESTEL and SWOT assessments, the article analyzes Azerbaijan's renewable and gas industries with implications of strength, weaknesses, challenges, and opportunities. The analysis indicates that although gas exports are crucial for Europe's immediate energy security, Azerbaijan is also investing in wind power and solar energy to become a green energy hub. Its participation in the EU – Black Sea – Caspian Sea Green Energy Corridor is particularly significant as an indicative change towards renewable electricity exports. The research determines that natural gas will be the central pillar of Azerbaijan's economy in the near future, but the nation is preparing the ground for a future based on renewable energy. Breaking through the infrastructure issues, attracting investment, and coordinating policies with international decarbonization targets will be decisive. If well managed, Azerbaijan can not only become a stable source of energy but also a regional clean energy leader, achieving long-term economic and environmental stability.

Keywords: Southern Gas Corridor; renewable energy transition; Azerbaijan-EU energy relations; green energy corridor.

Date submitted: 01.02.2025     Date accepted: 12.05.2025

Azerbaijan is at the crossroads of its energy development, weighing its traditional position as a leading gas exporter against the increasing trend towards renewable energy. This article examines the interaction between Azerbaijan's fossil fuel industry and its nascent green energy sector, looking at its contribution to European energy security and the shift towards sustainability. This research evaluates the importance of the Southern Gas Corridor in providing EU gas diversification, especially during geopolitical transformations, and measures the renewable energy potential of Azerbaijan. Based on PESTEL and SWOT assessments, the article analyzes Azerbaijan's renewable and gas industries with implications of strength, weaknesses, challenges, and opportunities. The analysis indicates that although gas exports are crucial for Europe's immediate energy security, Azerbaijan is also investing in wind power and solar energy to become a green energy hub. Its participation in the EU – Black Sea – Caspian Sea Green Energy Corridor is particularly significant as an indicative change towards renewable electricity exports. The research determines that natural gas will be the central pillar of Azerbaijan's economy in the near future, but the nation is preparing the ground for a future based on renewable energy. Breaking through the infrastructure issues, attracting investment, and coordinating policies with international decarbonization targets will be decisive. If well managed, Azerbaijan can not only become a stable source of energy but also a regional clean energy leader, achieving long-term economic and environmental stability.

Keywords: Southern Gas Corridor; renewable energy transition; Azerbaijan-EU energy relations; green energy corridor.

Date submitted: 01.02.2025     Date accepted: 12.05.2025

References

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DOI: 10.5510/OGP20250201077

E-mail: ramin.nuriyev15@gmail.com; charles.mcferren@uni-corvinus.hu


F. F. Yusifov

Institute of Information Technology, Ministry of Science and Education, Baku, Azerbaijan

Digital technologies in the oil and gas industry: technology selection, advantages and risks


Currently, the widespread use of digital technologies (DTs) in the oil-gas industry is shaping an environment referred to as digital oil-gas ecosystems. The key digital solutions used in the oil and gas sector include artificial intelligence, machine learning, the Internet of Things, cloud computing, smart materials, digital twins, robotics, drones, blockchain, and other emerging technologies. The article main aims to research the existing condition of digital transformations in oil and gas sector, analyze utilization capabilities of DTs and potential risks. The literature review shows that digital transformation is widely used to effectively organize oil and gas industry activities and increase management effectiveness. Despite the implementation of DTs, determining the next steps to be taken due to technological changes remains one of the key challenges. The article studies the directions of digital transformation in the oil and gas industry and analyses development strategies in this direction in thematic research and case studies. The reasons for the effectiveness of DTs include increasing production efficiency, lower production costs, faster management decision-making, improving the quality of applied solutions, and so on. The article reviews selection of DTs in oil-gas sector based on a multi-criteria decision-making method and conducts experimental evaluation. Risks caused by digital transformation are studied, advantages and disadvantages of development of DTs in oil and gas industry are demonstrated. Considering the findings of existing studies, along with the associated advantages and potential risks, there is a clear need to further explore the application of DTs in complex fields such as the oil and gas industry. 

Keywords: digital transformation; digital technology; oil-gas industry; artificial intelligence; internet of things; digital platform.

Date submitted: 19.09.2024     Date accepted: 07.05.2025

Currently, the widespread use of digital technologies (DTs) in the oil-gas industry is shaping an environment referred to as digital oil-gas ecosystems. The key digital solutions used in the oil and gas sector include artificial intelligence, machine learning, the Internet of Things, cloud computing, smart materials, digital twins, robotics, drones, blockchain, and other emerging technologies. The article main aims to research the existing condition of digital transformations in oil and gas sector, analyze utilization capabilities of DTs and potential risks. The literature review shows that digital transformation is widely used to effectively organize oil and gas industry activities and increase management effectiveness. Despite the implementation of DTs, determining the next steps to be taken due to technological changes remains one of the key challenges. The article studies the directions of digital transformation in the oil and gas industry and analyses development strategies in this direction in thematic research and case studies. The reasons for the effectiveness of DTs include increasing production efficiency, lower production costs, faster management decision-making, improving the quality of applied solutions, and so on. The article reviews selection of DTs in oil-gas sector based on a multi-criteria decision-making method and conducts experimental evaluation. Risks caused by digital transformation are studied, advantages and disadvantages of development of DTs in oil and gas industry are demonstrated. Considering the findings of existing studies, along with the associated advantages and potential risks, there is a clear need to further explore the application of DTs in complex fields such as the oil and gas industry. 

Keywords: digital transformation; digital technology; oil-gas industry; artificial intelligence; internet of things; digital platform.

Date submitted: 19.09.2024     Date accepted: 07.05.2025

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DOI: 10.5510/OGP20250201078

E-mail: farhadyusifov@gmail.com