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

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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

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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

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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

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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

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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

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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

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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

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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

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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

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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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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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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

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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

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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

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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.

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

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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

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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

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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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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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