In this study, the Interferometric Synthetic Aperture Radar (InSAR) method was employed for the first time to examine the correlation between moderate earthquakes and the dynamics of volcanoes in Azerbaijan. InSAR is a powerful technique for explaining the complexities of earthquakes in spatial times, providing more detailed insights into earthquake impacts than traditional methodologies. We analyzed pre-seismic, co-seismic, and post-seismic scenarios to determine potential possible relations between the 2021 Shamakhi earthquake (Mw5) and the Ayazakhtarma mud volcano. This research presents a comprehensive deformation time series data for the volcano derived from Sentinel 1A/B observations spanning 2017 to 2023. Concurrently, radar line-of-sight (LOS) displacement maps are prepared to represent the deformation associated with the earthquake in the pre-, co-, and post-seismic phases. Specifically, our analysis of the Ayazakhtarma mud volcano revealed significant LOS alterations in the pre-, co-, and post-seismic phases of ascending and descending orbits. Also, during a seven-year time series observation of the Ayazakhtarma mud volcano, two seismic events of magnitude Mw5 were recorded. These events demonstrated no significant influence on the mud volcano's activity, indicating that earthquakes of up to Mw ≤ 5 may not prompt significant eruptions in the Ayazakhtarma mud volcano. The study of the interferometric data has revealed fresh insights into the deformation behaviours of the Ayazakhtarma mud volcano and its interplay with seismic events.

Keywords: InSAR; deformation; earthquake; volcano; Ayazakhtarma; Azerbaijan.

References

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The integration of geochemical and sedimentological data in the Khuzestan Plain, southwestern Iran, reveals insights into its origin, pollution, and sedimentary characteristics. Facing environmental threats from external particulate matter, this study employs innovative geochemical methods to explore sediment origin, pollution, paleoclimate, and paleotectonics. Findings serve as a model for global investigations, demonstrating the utility of geochemical, petrographic, and electron microscopic data in geological applications. Field observations, granulometry, petrography, and geochemical analysis of 256 sediment samples indicate predominant silt and clay content, efficient in long-distance contaminant transport. Geochemical analysis reveals prevalent oxides (Cao, SiO₂, Al₂O₃) and rare elements (Ti, Zr, V, Ce, La), suggesting contamination sources. Tectonic investigations identify sediment sources and heavy metal pollutants (copper, lead, zinc), crucial for pollution assessment. Swift sediment deposition in high-energy environments, particularly in the northern region, poses pollution challenges. Regional collaboration is essential, considering imported sediments during droughts, addressing pollution in Khuzestan Plain. 

Keywords: geochemical studies; environmental studies; Khuzestan plain; XRF, XRD, ICPMS and SEM methods; pollution control; sedimentary origin; geotectonics.

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In this paper, for the objects of the Volga-Ural oil and gas province, confined to terrigenous and carbonate reservoirs, a study was conducted aimed at reducing risks and uncertainties when using geological and statistical models. Discriminant analysis revealed a number of inconsistencies in the grouping of objects according to the criterion of tectonic confinement, within which the migration of objects and their significant dispersion relative to the centroids of the groups were revealed. In order to level out the factors of nonlinearity and heterogeneity of processes occurring in disordered oil and gas systems, the boundaries of their stability are formed using four models using algorithms for solving the dual problem by the simplex method. Based on the data obtained, some features of the influence of parameters characterizing the geological and physical properties of productive formations and the fluids saturating them on the integrity and correctness of ideas about the degree of belonging of objects to certain grouping zones are determined. The results obtained make it possible, within the framework of proactive resource management, to create optimal or refine existing algorithms for finding the most suitable analog objects for use at newly discovered sites of the best engineering solutions and practices in the field of field development. 

Keywords: geological and statistical modeling; oil deposits; tectonic confinement of objects; geological complexes; development of oil fields; asset management of subsoil users.

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In the conditions of one of the most representative groups of facilities containing significant oil reserves, confined to the Tournaisian stage of the Volga-Ural oil and gas province, and characterized by low rates of putting into active development, low recoverable reserves, low profitability of oil production, a study was made of the process of developing reserves under various modes operation. The reservoir energy depletion mode and the use of various in-loop waterflooding systems were considered. The parameters of waterflooding techniques have been established, which determine the oil recovery efficiency, by adjusting which, taking into account the peculiarities of the geological structure of the facilities under study, it would be possible to achieve an increase in the reserve’s depletion degree and a reduction in the cost of production. It is proposed to justify the decisions made to improve the process of developing these low-productive deposits with hard-to-recover reserves based on the obtained geological and statistical models and algorithms by using parameters, determined with minimum permissible errors at the stage of putting facilities into operation as well as using the full range of information at the stage of full drilling of the deposits. 

Keywords: oil recovery factor; hard-to-recover reserves; carbonate reservoirs; reservoir flooding; development profitability; reserves management.

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At present, a significant number of Russian fields have hard-to-recover hydrocarbon reserves. The share of hard-to-recover reserves in our country accounts for more than 65% (or 12 billion tons) of oil and gas reserves on the balance sheet (in categories A + B + C₁). To develop hard-to-recover re-serves successfully, it is necessary to nurture technical and technological potential because the cur-rent technological base of the Russian Federation does not meet the growing demand. The industry requires the development of new approaches concerning exploration, drilling and enhanced oil re-covery. New technologies will make it possible to start developing unique deposits in new regions. That is why the task of implementing new effective technological solutions, which will allow hard-to-recover and low-margin hydrocarbon reserves development, is relevant today. One of the ad-vanced technological solutions is drilling multilateral horizontal wells. That can significantly increase the flow rates. 

Keywords: hard-to-recover reserves; development stimulation; development of low-permeability reservoirs; multilateral wells; multibranch wells; optimal length of the horizontal rathole; Fishbone well.

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Oil production flow rate prediction is a critical aspect of oil and gas exploitation operations. Currently, flow rate forecasting is often estimated using theoretical or empirical models. Theoretical and empirical models have limitations. This study applies an Artificial neural network (ANN) for prediction flow rate. The study considered 256 datasets collected from six wells in the HST Field, Cuu Long basin. The predicted results obtained from the ANN model with eight neurons and back-propagation algorithm achieved high predictability with a strong correlation coefficient of 0.964 and a low RMSE of 32.612 bbl/d. Therefore, the developed ANN models have been promised as an effective tool in production flow rate forecasting in oilfields. 

Keywords: Artificial neural network; backpropagation algorithm; flow rate prediction; multivariate regression method; gas-lift.

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It is known that due to high thermobaric conditions during the operation of deep oil and gas fields, the parameters characterizing the rock and fluid change significantly depending on the effect of temperature and deformation. This, in turn, is reflected in the determination of factual index exploitations. The hydrodynamic models written taking into account the considered of changes form a system of nonlinear equations of the mixed type with specific characteristics and containing a high time derivative at the boundary. In numerous studies available in the literature, the solutions are found mainly using classical finite difference methods, without taking into account the characteristics of the mathematical problem. To ensure a reliable calculation of technological indicators, it is important to achieve that the hydrodynamic model adequately reflects of the process and find solutions that express all the properties of the physical process. The article proposes a solution to a mathematical model for studying the process of mass heat transfer in deformable deposits in a class of discontinues functions. 

Keywords: mass-heat transfer; deformable collector; weak solution; finite differences in the class of truncated functions.

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In this article the researchers have studied oil recovery processes under CO₂ injection into non-homogeneous production banks with the use of a compositional hydrodynamic model. GHDM calculations has shown that at the reservoir conditions there will be mutual dissolution of oil and gas while injecting carbon dioxide. Oil-to-gas and gas-to-oil partial mass transfer will occur during oil displacement. The operational benefit will come as a result of reduced oil viscosity, greater cover ratio (reduced water-to-oil phase fluidity), and displacement coefficient (reduced surface tension). This benefit will amount to 8.5 tons of extra oil recovered. 

Keywords: porosity; boundary surface tension; geological hydrodynamic model; carbon dioxide.

References

1. Khisamutdinov, N. I., Gilmanova, R. Kh., Makhmutov, A. A., et al. (2017). Study of the efficiency of oil extraction from carbonate reservoirs. Geology, Geophysics and Development of Oil and Gas Fields, 5, 31-36.
2. Khisamutdinov, N. I., Gilmanova, R. Kh., Makhmutov, A. A., et al. (2018). Some methods for extracting viscous oil from carbonate reservoirs. Geology, Geophysics and Development of Oil and Gas Fields, 4, 28-31.
3. Khisamutdinov, N. I., Makhmutov, A. A., Shchekaturova, I. Sh., et al. (2019). Experience in the industrial use of carbon dioxide to intensify oil displacement in reservoir conditions. Oilfield Engineering, 4, 31-35.
4. Gilmanova, R. Kh., Makhmutov, A. A., Kornev, E. V., Vafin, T. R. (2020). Using the methodology for constructing a permeability cube taking into account the heterogeneity of formations in oil fields of the Ural-Volga region. Oil Province, 4(24), 72-89.
5. Bakirov, I. I., Makhmutov, A. A., Minnullin, A. G., et al. (2017). Experience in modeling the oil saturation cube in formations with heterogeneous filtration and reservoir properties at a late stage of development. Geology, Geophysics and Development of Oil and Gas Fields, 12, 69-70.
6. Chudinova, D. Y., Urakov, D. S., Sultanov, Sh. Kh., et al. (2021). Improvement of oil recovery factor from geological perspectives. SOCAR Proceedings, 2, 17- 25.
7. Urakov, D. S., Rahman, S. S., Tyson, S., et al. (2021). Conceptualizing a dual porosity occurrence in sandstones by utilizing various laboratory methods. SOCAR Proceedings, 2, 8-16.
8. Mukhametshin, V. Sh., Andreev, V. E., Dubinsky, G. S., Sultanov, Sh. Kh. (2016). Using the principles of systemic geological and technological forecasting in substantiating methods of influencing the formation. SOCAR Proceedings, 3, 45-51.
9. tNavigator Manual - «Complete solution for reservoir engineer and geologist. Review of modules».

The publication analyzes the use of viscoelastic systems in order to increase the efficiency of oil production in the Caspian fields. The conducted studies of the results of pilot field work on the introduction of polymer flooding technologies in complexly constructed terrigenous reservoirs have shown a number of disadvantages of the systems used at the pilot site. In particular, the premature destruction of the polymer compositions used and the subsequent sharp watering of the extracted products were revealed. The research covers technology tests from November 2014 to October 2021, the results of which established the presence of deteriorating dynamics in the removal of polymer material, in addition, the study revealed a high influence of thermobaric and reservoir conditions on the polymer formation process and its subsequent properties. The classic solution to the described problem is the use of compositions with higher viscosity indices, however, laboratory experiments with the use of reservoir fluid have shown a decrease in the characteristics of the compositions used while maintaining conditions close to reservoir conditions. Based on the results of the research, an approach based on a systematic solution of the problem was proposed, the existing line of agents was modernized taking into account experimental data with the reaction of compositions to reservoir fluids, including elements of control and regulation of the oil recovery process during exposure, changes in the volumes of injected polymer solutions. 

Keywords: water intrusion; systemic approach; viscoelastic systems; oil recovery.

References

1. Chizhov, A. P., Doskazieva, G. Sh., Andreev, V. E., et al. (2021). Factors affecting the stability of polymers under flooding conditions at vostochny Moldabek field. Problems of Gathering, Treatment and Transportation of Oil and Oil Products, 6(134), 52-69.
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3. Tambaredjo field. SPE Reservoir Evaluation & Engineering, 17(03), 314–325.
4. Algharaib, M., Alajmi, A., Gharbi, R. (2011, May). Investigation of polymer flood performance in high salinity oil reservoirs. SPE-149133-MS. In: SPE/DGS Saudi Arabia Section Technical Symposium and Exhibition, Al-Khobar, Saudi Arabia. Society of Petroleum Engineers.
5. Farouq Ali, S. M., Thomas, S. (1989, September). The promise and problems of enhanced oil recovery methods. PETSOC-SS-89-26. In: Technical Meeting / Petroleum Conference of The South Saskatchewan Section. Society of Petroleum Engineers.
6. Delamaide, E., Tabary, R., Rousseau, D. (2014, March). Chemical EOR in low permeability reservoirs. SPE-169673-MS. In: SPE EOR Conference at Oil and Gas West Asia, Muscat, Oman. Society of Petroleum Engineers.
7. Stoll, U. M., Shureki, Kh., Finol, Dzh., et al. (2011). Potok shchelochej / poverkhnostno-aktivnykh veshchestv / polimerov: iz laboratorii v pole.
8. Tovar, F. D., Barrufet, M. A., Schechter, D. S. (2014, April). Long term stability of acrylamide based polymers during chemically assisted CO2 WAG EOR. SPE-169053-MS. In: SPE Improved Oil Recovery Symposium, Tulsa, Oklahoma, USA. Society of Petroleum Engineers.
9. Yerramilli, S. S., Zitha, P. L., Yerramilli, R. C. (2013, June). Novel insight into polymer injectivity for polymer flooding. SPE-165195-MS. In: SPE European Formation Damage Conference & Exhibition, Noordwijk, The Netherlands. Society of Petroleum Engineers.
10. Zekhner, M., Clemens, T., Suri, A., Sharma, M. M. (2014, April). Simulation of Polymer injection under fracturing conditions - a field pilot in the Matzen field, Austria. SPE-169043-MS. In: SPE Improved Oil Recovery Symposium, Tulsa, Oklahoma, USA. Society of Petroleum Engineers.

The article is devoted to the analysis and assessment of the influence of parameters characterizing the composition, properties and conditions of oil occurrence on its quality. Using the principles of the theory of fuzzy sets, modeling of the dependences of the noted characteristics of oil on the complexity of its production was carried out. Data on the properties, composition and conditions of oil occurrence in the fields of Azerbaijan and Kazakhstan were collected. By implementing the fuzzy cluster analysis algorithm, fuzzy rules are formulated based on the «if..., then...» principle. The classification features are the composition, density and viscosity of oil, the permeability of the reservoir conditions. A brief analysis of existing works on the classification and assessment of the quality of oil from fields with hard-to-recover reserves showed the need to divide the total sample into homogeneous groups (clusters) according to the totality of the noted classification features characterizing the composition, properties and conditions of oil occurrences. A generalized indicator characterizing the quality of oil is proposed. 

Keywords: oil field; classification; fuzzy cluster analysis; hard-to-recover oils; sulfur concentration; density; viscosity; permeability.

References

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The paper explores the optimal placement of the chemical blocking agent (water shut-off material) in a high-permeability watered sublayer under uncertainty of its geometry in the inter-well area. The simulation of the water flooding process at different sublayer positions and variations of blocking agent placement was performed using a high-speed computing two-dimensional model of stream tube. The decision of the optimal placement of the water shut-off agent was made using probabilistic processing of the results without using a large amount of resource-intensive numerical simulation. The relationship between the optimal water shut-off scenario and the sublayer geometry is demonstrated. The relationship between the parameters of the sublayer geometry distribution function and the probabilistic behavior of the generalized efficiency has been established. Simulations are performed for various mobility ratios: in cases with equal viscosity liquids and typical ones for reservoirs in the Volga region and Western Siberia. 

Keywords: petroleum reservoir; high-permeability layer; geological uncertainty; early water breakthrough; water shut-off; stochastic modeling; two-phase flow; model of stream tube.

References

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7. Mazo, A. B., Potashev, K. A., Baushin, V. V., Bulygin, D. V. (2017). Numerical simulation of oil reservoir polymer flooding by the model of fixed stream tube. Georesources, 19(1), 15-20.
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15. Khamees, T., Flori, R. E., Wei, M. (2017, April). Simulation study of in-depth gel treatment in heterogeneous reservoirs with sensitivity analyses. SPE-185716-MS. In: SPE Western Regional Meeting, Bakersfield, California. Society of Petroleum Engineers.
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The article discusses the hydraulic features of the «well, collection and transport» system and the issue of selecting the diameter of subsea pipelines at given technological limitations, flow rate and pressure at the beginning of export pipeline. Taking into account the interactions of the phases, various options for the hydraulic calculation of multiphase gas-condensate pipelines are analyzed. Provided, that economic considerations for the development of gas condensate resources require a significant revision of some traditional onshore positions in the design of offshore subsea pipelines. Analysis of the functioning of systems for collecting and transporting gas condensate mixtures is considered on the example of the development of the offshore field "Umid" in Azerbaijan, located at a distance of about 40 km from the coast. At the same time, the dynamics of the removal of accumulated fluid from the system of «well, collection and transport» showed a stable picture of preventing the hydrate formation. However, careful study shows that the cycle of accumulation and removal of the liquid phase has cyclic regime where the frequency is measured in days. Such a large frequency is mainly determined due to low condensate ratio as the natural gas. The calculation results showed that, in contrast to a single-phase flow, the distance of the gas-condensate fluid storage can’t be increased indefinitely with an increase in the diameter of the pipeline. Also, it is confirmed that the distance of the gas-condensate fluid storage depending on the diameter of the pipeline, taking into account the flow rate and pressure at the beginning, has a certain optimal value, which assures maximum stable operation. 

Keywords: gas-condensate resource; subsea pipelines; hydraulic features; multicomponent stream; gas-condensate storage; hydraulic resistance; flow regime.

References

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Many production and injection wells do not operate at full capacity due to damage of the near-well zone of the formation. The most frequently used and at the same time effective means of combating this problem is acid treatment of wells. Unfortunately, there are certain geological and field conditions that significantly reduce the effectiveness of acid treatments. Among them we can list the complex composition of the reservoir, heterogeneity of the reservoir, high reservoir and bottomhole temperatures, low reservoir permeability and, conversely, the presence of highly permeable zones and fractures, high water cut in well production, asphalt, resin and paraffin deposits, formation of stable emulsions upon contact of an acid solution with reservoir fluids, insufficient well preparation for acid treatment, reservoir destruction, greater thickness of the treated interval in a vertical well and a large length of the horizontal section of the horizontal well, primary treatment or retreatment, etc. However, the «sour» result of such processing can be significantly «sweetened» using modern technologies of the oil and gas industry. This article examines these situations and suggests ways to solve these problems. 

Keywords: acid treatment; improved oil recovery (IOR); well stimulation; high reservoir temperature; low permeability; high water cut; formation of stable emulsions; treatment of thick reservoirs.

References

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19. Furui, K., Burton, R. C., Burkhead, D. W., et al. (2012). A comprehensive model of high-rate matrix-acid stimulation for long horizontal wells in carbonate reservoirs: Part i-scaling up core-level acid wormholing to field treatments. SPE Journal, 17(1), 271–279.
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The article presents the results of the experiment of the time and speed reaction determining on a special reactor device simulating the reagents and accompanying materials interaction. The device allows one to determine the change in temperature and pressure over time. It is noted that heat generation dynamics largely depends on the reaction rate, on the process of transporting reagents to the reaction site, the ability to remove reaction products, and the thermal transfer of materials involved in the process. 

Keywords: bottomhole formation zone; heat generation; auxiliary reagents; reaction rate; reactor device; borehole conditions; reactive mass; acid volume; mass component; water heat capacity. 

References

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33. Mukhametshin, V. V. (2021). Improving the efficiency of managing the development of the west siberian oil and gas province fields on the basis of differentiation and grouping. Russian Geology and Geophysics, 62(12), 1373–1384.
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35. Yakupov, R. F., Mukhametshin, V. Sh., Tyncherov, K. T. (2018). Filtration model of oil coning in a bottom water-drive reservoir. Periodico Tche Quimica, 15(30), 725-733. 
36. Mukhametshin, V. V. (2020). Oil production facilities management improving using the analogy method. SOCAR Proceedings, 4, 42-50.
37. Shuster, V. L. (2022). Features of formation and placement of large and giant oil and gas deposits in megareservaries of sedimentary basins. SOCAR Proceedings, SI2, 30–38.
38. Grishchenko, V. A., Rabaev, R. U., Asylgareev, I. N., et al. (2021). Methodological approach to optimal geological and technological characteristics determining when planning hydraulic fracturing at multilayer facilities. SOCAR Proceedings, SI2, 182-191.
39. Mukhametshin, V. V. (2018). Rationale for trends in increasing oil reserves depletion in Western Siberia cretaceous deposits based on targets identification. Bulletin of the Tomsk Polytechnic University. Geo Assets Engineering, 329(5), 117–124.
40. Kudryashov, S. I., Khasanov, M. M., Krasnov, V. A., et al. (2007). Technologies application patterns – an effective way of knowledge systematization. Oil Industry, 11, 7-9.
41. Rabaev, R. U., Chibisov, A. V., Kotenev, A. Yu., et al. (2021). Mathematical modelling of carbonate reservoir dissolution and prediction of the controlled hydrochloric acid treatment efficiency. SOCAR Proceedings, 2, 40-46.
42. Rogachev, M. K., Mukhametshin, V. V. (2018). Control and regulation of the hydrochloric acid treatment of the bottomhole zone based on field-geological data. Journal of Mining Institute, 231, 275-280.
43. Orlova, I. O., Zakharchenko, E. I., Skiba, N. K., Zakharchenko, Yu. I. (2014). Methodical approach to fields classification and fields-analogues prospecting. Geology, Geophysics and Development of Oil and Gas Fields, 12, 16-18.
44. Veliev, M. M., Bondarenko, V. A., Zung, L. V., et al. (2019). Technique and technology of oil production on the shelf of the fields of the joint Venture «Vietsovpetro». Sankt-Petersburg: Nedra.

Based on the consistent image recognition techniques application and quantitative and qualitative indicators characterizing the tectonic and stratigraphic confinement and features of the geological structure of deposits, an algorithm has been developed allowing filtering scientific information about the effectiveness of oil deposits in Devonian terrigenous reservoirs of the Volga-Ural oil and gas province. The algorithm makes it possible to identify twenty-one groups of facilities the development experience of which can be accurately used to reduce the risks of making decision errors aimed at development process optimizing both in the conditions of «mature» deposits and in the conditions of deposits being put into development. 

Keywords: terrigenous reservoir; image recognition technique; tectonic-stratigraphic confinement of deposits; geological-physical and physical-chemical properties of layers; facilities identification.

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The article deals with the issue of improving the efficiency of the development of carbonate deposits of the Tournaisian tier. The object is characterized by a complex geological structure, has degraded filtration-capacitance properties and anisotropy of parameters. In recent years, oil production at the Tournai facility has increased nine times due to the active formation of a system for developing and increasing the volume of drilling horizontal wells. The historical experience of drilling horizontal wells at the C1t facility is analyzed, which is conditionally divided into two stages, differing in the approach to drilling based on the technologies available at each stage. The development of drilling technology, the influence of the type of completion and location of wells on deposits is considered. The implementation of horizontal wells with multi-stage hydraulic fracturing confirms high efficiency in deposits with high fragmentation and heterogeneity of the productive section, in conditions of low-permeable reservoirs in order to increase the degree of production and the rate of selection of reserves. 

Keywords: carbonate reservoirs; optimal horizontal well length; type of completion; multi-stage hydraulic fracturing; sampling rate; optimization of the development system.

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Water-swellable packers are designed using elastomeric components that have a unique swelling property when exposed to water or water-based fluids. The swelling of the elastomer creates a tight seal. Water-swellable packers offer several advantages in well construction and maintenance. They can be used for a variety of purposes including preventing gas migration, shutting off water flow, and facilitating fracturing operations. It is assumed that the degree of swelling and rate of expansion depends on factors such as elastomer composition, conditions in the wellbore, and the salinity of the surrounding fluids. The use of water-swellable packers requires careful consideration of well conditions and the fluids present. Matching the packer's swelling properties to the intended well’s fluids is essential to achieve effective zonal isolation. Proper elastomer compatibility testing and evaluation is recommended prior to field deployment to ensure successful and reliable packer operation. In this regard, the purpose of this study is to experimentally confirm the possibility of expanding packers in water with different salt concentrations. 

Keywords: swellable packers; elastomeric components; swelling property; brines; salinity; elastomer compatibility testing; laboratory evaluation; swelling rate.

References

1. https://www.weatherford.com/products-and-services/well-construction-and-completions/sand-face-solutions/openhole-isolation-packers/swellable-packers/
2. Espinosa, M., Leal, J., Zbitowsky, R., Pacheco, E. (2021, November). Openhole multistage completion evaluation incorporating deployment of downhole shut-in tool application in sour carbonate gas wells, field application. SPE-204905-MS. In: SPE Middle East Oil & Gas Show and Conference. Society of Petroleum Engineers.
3. Alali, E. A., Bataweel, M. A., Arias Urbina, R. E., Bulekbay, A. (2020, November). Critical review of multistage fracturing completions and stimulation methods. SPE-203284-MS. In: Abu Dhabi International Petroleum Exhibition & Conference. Society of Petroleum Engineers.
4. Ueta, E. M., Neto, J. N., Nunes, M. A., et al. (2008). First use of swell technology in Campos Basin proves water conformance solution - case history in Campos Basin-Brazil. OTC-19612-MS. In: Offshore Technology Conference, Houston, Texas, USA. Society of Petroleum Engineers.
5. Paduchak, M., Dudzych, V., Boiko, A. (2021, November). Minimization of negative impact of well cementing on productive horizons by utilization of swellable packers. SPE-208510-MS. In: SPE Eastern Europe Subsurface Conference, Kyiv, Ukraine. Society of Petroleum Engineers.
6. Denney, D. (2009). Effects of HCl and brine on water-swelling packers. Journal of Petroleum Technology, 61, 55–56.
7. Stein, T., Tunstall, M., Wellhoefer, B., Veillette, C. (2013, November). Modeling, testing, and case histories of swellable packer casing anchoring performance enable wells destined for plug and abandon to become producers. SPE-167171-MS. In: SPE Unconventional Resources Conference Canada, Calgary, Alberta, Canada. Society of Petroleum Engineers.
8. Mamedbekov, O. K. (2019). Experimental investigation of packer swelling process in cementing. Azerbaijan Oil Industry, 11, 17–20.
9. Alakberi, R. S., Igein, O. F., Aljasmi, S. A. (2023). Successful smart completion deployment of autonomous inflow control valve with 13 open hole segmentation lower completion using a light workover rig. SPE-214582-MS. In: SPE/IADC Middle East Drilling Technology Conference and Exhibition, Abu Dhabi, UAE. Society of Petroleum Engineers.
10. Li, W., Sahu, Q. (2023, March). A review: progress of diverter technology for oil and gas production applications in the past decade. SPE-214118-MS. In: Gas & Oil Technology Showcase and Conference, Dubai, UAE. Society of Petroleum Engineers.
11. Evers, R., Young, D. A., Vargus, G. W., Solhaug, K. (2009, May). Design methodology for swellable elastomer packers in fracturing operations. OTC-20157-MS. In: Offshore Technology Conference, Houston, Texas. Society of Petroleum Engineers.
12. Yahya, M. A., Alhathnawi, M. I. (2022, October). First run of 17 swellable packers in Sahil field with 15 AICV as a first new technology trial in ADNOC onshore. SPE-211771-MS. In: ADIPEC, Abu Dhabi, UAE. Society of Petroleum Engineers.
13. Hinkie, R. (2010). Non-cemented casing tieback string reduces expense and risk in deepwater operations. SPE-137852-MS. In: SPE Deepwater Drilling and Completions Conference, Galveston, Texas, USA. Society of Petroleum Engineers.
14. Wellhoefer, B., Stegent, N., Tunstall, M., et al. (2013). Unique solution to repair casing failure in a HP/HT wellbore allows for successful multistage stimulation treatment in an unconventional reservoir. SPE Drilling and Completion, 28, 237–242.
15. Kazimov, Sh. P., Abdullaeva, E. S., Racabov, N. M. (2015). Structure of swelling packers and their applicability in the fields of Azerbaijan. SOCAR Proceedings, 3, 43–51.

SCADA (Supervisory Control and Data Acquisition) systems play an important role in the oil and gas industry providing real-time monitoring, control and data acquisition of critical infrastructure. Unlike traditional SCADA systems based on local hardware and software, cloud-based SCADA systems take advantage of cloud computing technologies for real-time data collection and management. Cloud-based SCADA systems offer many advantages due to their scalability, flexibility and cost-effectiveness. To take advantage of these advantages, it is required to solve a number of problems related to the application of cloud-based SCADA systems in the oil and gas industry. One of the most important application challenges is the cybersecurity issues arising in cloud-based SCADA systems, which are a significant concern due to the critical nature of the infrastructure they control. Thus, the systems face various vulnerabilities and threats that can destroy the data integrity and the system's availability. This article outlines the current cyber-attacks that can compromise the security of cloud-based SCADA systems. Threats and vulnerabilities in using cloud-based SCADA systems are analyzed, and suggestions are made that partially help to solve them. Some security mechanisms are recommended to ensure the security of cloud-based SCADA systems. These mechanisms will help increase the reliability and security of cloud-based SCADA system operations in the oil and gas industry. 

Keywords: SCADA systems; cloud computing; cloud-based SCADA systems; SCADA security; cloud security.

References

1. Stojanović, M. D., Boštjanĉiĉ Rakas, S. V., Marković-PetroviC, J. D. (2019). Scada systems ın the cloud and fog envıronments: mıgratıon scenarıos and securıty ıssues. Electronics and Energetics, 32(3), 345–358.
2. Alshehry, F. F., Wali, A. M. (2022). Analysis of security challenges in cloud-based SCADA systems: A survey. TechRxiv. Preprint.
3. Alakbarov, R. K., Hashimov, M. A. (2020). Migration issues of SCADA systems to the Cloud Computing Environment (review). SOCAR Proceedings, 3, 155-164.
4. Alakbarov, R. K., Hashimov, M. A. (2018). Application of the internet of things in oil-gas industry. In: 6th International Conference on Control and Optimization with Industrial Applications.
5. Nazir, S., Patel, S., Patel, D. (2017). Assessing and augmenting SCADA cyber security: A survey of techniques. Computers & Security, 70, 436-454.
6. Sajid, A., Abbas, H., Saleem, K. (2016). Cloud-assisted IoT-based SCADA systems security: A review of the state of the art and future challenges. IEEE Access, 4, 1375–1385.
7. Bere, M., Muyingi, H. (2015). Initial investigation of industrial control system (ICS) security using artificial immune system (AIS). In: International Conference on Emerging Trends in Networks and Computer Communications (ETNCC).
8. Cagalaban, G., Kim, T., Kim, S. (2008). Improving SCADA control systems security with software vulnerability analysis. In: 12th WSEAS International Conference on Automatic Control, Modelling & Simulation.
9. Davis, C., Tate, J., Okhravl, H., et al. (2006). SCADA cyber security testbed development. In: 38th North American Power Symposium.
10. Kang, U., Chau, D., Faloutsos, C. (2012). Pegasus: mining billion-scale graphs in the cloud. In: IEEE International Conference on Acoustics, Speech and Signal Processing (ICASSP), Kyoto, Japan.
11. Shen, J., Xu, J., Cai, K., Ji, Y. (2021). Access point authentication scheme of Scada system based on cloud computing technology. Journal of Physics: Conference Series, IOP Publishing, 1748(2), 1-6.
12. Alakbarov, R. Q., Hashimov, M. A. (2014). Possibilities and prospects of using cloud technologies in the electronic government. In: First Republic Scientific-Practical Conference on E-Science Problems.
13. Piggin, R. S. H. (2014). Securing SCADA in the cloud: managing the risks to avoid the perfect storm. In: IET & ISA 60th International Instrumentation Symposium.
14. Kyle,W. (2013). SCADA in the cloud a security conundrum?. Trend Micro Incorporated Research Paper. https://blog. trendmicro.com/trendlabs-security-intelligence/scada-in-the-cloud a-security-conundrum/
15. Alakbarov, R., Hashimov, M. (2022). Security issues of cloud-based SCADA systems. NATO Science for Peace and Security Series - D: Information and Communication Security, 62, 1-8.
16. Alakbarov, R. K., Hashimov, M. A. (2020). Security issues of SCADA systems in cloud computing environment. In: 7th International Conference on Control and Optimization with Industrial Applications.
17. Fernandez, J., Fernandez, A. (2005). SCADA systems: vulnerabilities and remediation. Journal of Computing Sciences in Colleges, 20(4), 160-168.
18. Nazir, S., Patel, Sh., Patel, D. (2020). Cloud-based autonomic computing framework for securing SCADA systems /in book: Innovations, Algorithms, and Applications in Cognitive Informatics and Natural Intelligence. IGI Global.
19. Igure, V., Williams, R. (2006). Security and SCADA protocols. In: 5th International Topical Meeting on Nuclear Plant Instrumentation, Control, and Human-Machine Interface Technologies (NPIC HMIT).
20. Alakbarov, R., Hashimov, M. (2020). Security issues in cloud-based SCADA systems. Information Technology Problems, 2, 3-12.
21. Wang, Y. (2012). SCADA: Securing SCADA infrastructure communications. International Journal of Communication Networks and Distributed Systems, 6(1), 59-78.
22. Alakbarov, R. (2021). Cloud-based electronic government system: state-of-the-art, problems and security issues. Information Society Problems, 1, 18-31.
23. Howard, P. A. (2015). Security checklist for SCADA systems in the cloud. https://gcn.com/cloud-infrastructure/2015/06/a-security-checklist-for-scada-systems-in-the-cloud/287164/
24. Ferrag, M. A. Babaghayou, M. Yazici, M. A. (2020). Cyber security for fog-based smart grid SCADA systems: solutions and challenges. Journal of Information Security and Applications, 52, 102500.
25. Cui, L., Xie, G., Qu, Y., et al. (2018). Security and privacy in smart cities: challenges and opportunities. IEEE Access, 6, 46134–46145.

The fields developing on the shelf of the northern Caspian Sea, which belongs to the shallow water zone, are where the breeding and nagulation of semi-passable fish mainly occurs. In this regard, studies of bottom sediments where macrozoobentos is concentrated, which is a feed of benthic fish, are a problem that requires research into the state of not only pollution of bottom sediments but also the state of macrozoobenthos. In this regard, this article is aimed at detecting the state of pollution of bottom sediments by heavy metals and the state of macrozoobenthos, the number and biomass distribution. The leading approach to the study of this problem is the «The guide to methods of hydrobiological analysis of surface waters and bottom sediments» and the «The methodological manual for hydrobiological fisheries research of Kazakhstan reservoirs». The article presents the results of the state of pollution of bottom deposition by heavy metals on the structures of Kashagan, Aktoty, Kairan and the number and species composition of macrozoobenthos. The article revealed that the content of metals in bottom sediments in the studied areas was quite stable and mainly changed in a small range in all seasons of 2019. The species composition of macrozoobenthos was quite homogeneous throughout the surveyed area of the sea. The number of bottom invertebrates varied within relatively small limits, with a more expressed range of biomass fluctuations. 

Keywords: bottom sediments; Kashagan; Aktoty; Kairan; heavy metals; macrobenthos.

References

1. Nesterov, E. S. (2016). Water balance and Caspian Sea level fluctuations. Modelling and forecasting. Moscow: Triada Ltd.
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4. Kostianoy, A. G., Kosarev, A. N. (2005). Physico-geographical conditions of the Caspian Sea. The Caspian Sea environment. Vol. 5. Part P. Berlin, Heidelberg, New York: Springer–Verlag.
5. Zonn, I. S., Zhiltsov, S. S. (2008). New Caspian: geography, economics, politics. Moscow: AST Vostok-Zapad.
6. Kenzhegaliev, A., Kanbetov, A. S., Abylgazieva, A. A., et al. (2019). Condition of bottom sediment in the area of artificial islands of the Kashagan field, Kazakhstan. South of Russia: Ecology, Developmen, 14(3), 144-153.
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The legislation of the Russian Federation regulating hydrocarbon emissions is a complex hierarchical structure formed by legal acts located at its different levels. Emissions to the atmosphere from tanks are directly determined according to guidelines developed and approved by the State Committee of the Russian Federation for Environmental Protection with the participation of the Atmosphere Research Institute in 1999. In the USA, emissions to the atmosphere from tanks are determined according to standards developed by the American Petroleum Institute API MPMS 19-1 and API MPMS 19-2. All of these methods have a number of advantages and disadvantages. The paper analyzes Russian and American methods on the example of a vertical steel tank (VST), and also proposes new tools for monitoring safe and environmentally friendly operation. Methods for determining emissions used in the United States, unlike Russian ones, are also officially regulated tools for determining the loss of hydrocarbons from evaporation. Such a system makes it possible to avoid discrepancies in the volumes of emissions obtained by different committees and services, taking into account the same physical processes. Therefore, in Russia it is necessary to obtain a unified calculation scheme and methodology for determining emissions from reservoirs. 

Keywords: oil losses, reservoir storage, hydrocarbon emissions, oil evaporation, rates of natural loss, storage in VST.

References

1. Hermawan, Y. D., Kristanto, D., Hariyadi. (2021). Oil losses problem in oil and gas industries, Yogyakarta, Indonesia /in: Crude Oil – New Technologies and Recent Approaches. IntechOpen.
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14. Clavijo Mayorga, D. G., Padilla Erazo, W. L. (2014). Minimización de pérdidas en los tanques de almacenamiento de naftas en refinería Esmeraldas. Quito: Escuela Politécnica Nacional.
15. Magaril, E. (2015). Reducing gasoline loss from evaporation by the introduction of a surface-active fuel additive. WIT Transactions on The Built Environment, 146, 233-242.
16. Lyubin, E. A. (2007). Prediction of oil losses from vertical cylindrical tanks. Journal of Mining Institute, 181, 132-134.
17. Kampa, E., Ward, D. G., Leipprand, A. (2007). Convergence with EU air policy - a short guide for European Neighbourhood Policy partner countries, and Russia. Policy guide: the EU air policy. ECOLOGIC - Institute for International and European Environmental Policy.
18. Lebedev, I. V., Abouzova, F. F., Shcheglov, V. E. (2006). Calculation of the maximal capacity of hydrocarbons emission for objects of transportation and storage of oil and oil products. Ecology and Industry of Russia, 5, 28-29.
19. Korshak, A. A., Korshak, An. А. (2021). Estimation of the contribution of vapour-air mixture vol-ume increase over injection volume in oil and oil products losses from evaporation. Science and Technology of Pipeline Transport of Oil and Oil Products, 11(4), 452-459.
20. Levitin, R. E., Zemenkov, Yu. D. (). The new approach to accurately determination of oil tanks evaporation. Oil Industry, 1, 110-114.
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In the presented work, comparative studies of the dielectric and electrical properties of La0.73Ba0.27MnO3 compounds were carried out at the temperature range T = 25-225 °C and frequencies range f = 20-106 Hz. Temperature and frequency dependences of the real and imaginary parts of the dielectric constant, dielectric loss angle, dielectric constant, and electrical conductivity were obtained. This compound was found to have semiconducting properties under normal conditions. It has been established that with increasing temperature and frequency, the electrical conductivity in these compounds increases. This effect is explained by the release of charge carriers at deep levels due to thermal energy. At a temperature T = 140 °C, a semiconductor-metal phase transition was detected in this compound. The values of physical parameters for each of the semiconductor and metal phases are determined. The occurrence of a phase transition is explained by the mechanism of activation of charge carriers due to thermal energy. 

Keywords: perovskit; dielectric properties; electrical properties; La_1-xBa_xMnO₃.

References

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