Vol 7, No 4 (2025)

Background: This paper examines the opportunity to expand the gas reserves of reservoir unit J-IIA of the Aktas field. A previously overlooked prospect was identified based on production anomalies from Well No. 11, whose output did not align with the earlier geological model of the formation. It is proposed that the unusually high production may be linked to the presence of a previously undetected paleo-channel, not captured in earlier seismic interpretations.

Aim: Aim of this study is to refine the geological model of the Aktas field and to identify prospective zones – sandy bodies that may serve as lithological gas traps.

Materials and methods: The study was based on production well data, integrated with a time cube of the ExChroma attribute extracted from the seismic volume covering the Aktas Field and adjacent areas

Results: Among the technologies evaluated, the eXchroma method proved most effective for identifying ancient channel systems in the seismic wavefield of the study area. Using this technique, a channel feature was identified extending along the western structural nose of the Aktas structure, near Well No. 11. The study also highlights a non-structural geological link between the Aktas and Zhetybai structures, and provides an estimate of the gas resources associated with the interpreted paleo-channel.

Conclusion: The integrated analysis of available data revealed promising non-structural traps within the Jurassic deposits of the study area. The results of seismic data processing and interpretation are supported by geological, geophysical, and production data obtained from Well No. 11.

Background: Effective reservoir management require integrating multiple geological and technological parameters to optimize decision-making. Traditional approaches, while useful, often struggle with the complexity and volume of reservoir data, highlighting the need for more advanced analytical methods.

Aim: This article examines various methodologies for data-driven comparative analysis and its application for selection of drilling points for production and water flooding operations.

Materials and methods: Advanced computational techniques, including machine learning applications, are explored for their role in improving evaluation accuracy. Additionally, this study compares different comparative analysis approaches used in the industry, highlighting their strengths, limitations, and adaptability to various geological conditions.

Results: The synthesis of recent research demonstrates the potential of multimodal analysis approaches to enhance predictive accuracy and decision-making efficiency. Comparative evaluations reveal that while traditional methods remain valuable in certain contexts, data-driven techniques provide superior adaptability and scalability. Future advancements are identified in integrating real-time data streams and cross-disciplinary modeling.

Conclusion: Data-driven comparative analysis, particularly when supported by machine learning, shows significant promise in improving reservoir management practices. By enabling more accurate drilling point selection and more effective water flooding operations, these approaches can drive both economic and operational efficiency. The study emphasizes the importance of continuous innovation and integration of computational tools to address the evolving complexity of reservoir systems.

Background: Corrosion is among the primary factors that diminish the reliability and service life of oil pipelines. Among the existing corrosion-mitigation techniques, cathodic (electrochemical) protection is widely regarded as the most effective method, enabling a substantial extension of pipeline longevity and a significant reduction in operational risks.

Aim: The aim of this study is to calculate and analyze the key parameters of cathodic protection stations to ensure effective electrochemical protection of oil pipelines, enhance the reliability of their operation, and prevent corrosion-related degradation.

Materials and methods: The study relied on the regulatory document RD 153-39.4-039-99 and methodological guidelines for the design of electrochemical protection systems. Calculations were performed using the established formulas proposed by Bykov et al. (2006), incorporating soil resistivity as well as the length and geometric parameters of the pipeline. Additionally, the analysis examined how potentials, currents, and resistances are distributed within the pipeline–soil system.

Results: The study identified the optimal design parameters for cathodic protection stations, including current load, the required number of anodes, grounding resistance, and power supply capacity. The findings demonstrate that properly selecting these parameters helps maintain a stable protection potential and significantly enhances the operational lifetime of the pipeline.

Conclusion: Implementing cathodic protection based on accurately calculated design parameters enhances the operational safety of oil pipelines, mitigates corrosion-related risks, and reduces the overall maintenance costs.

Background: Aboveground Storage Tanks (ASTs) are critical assets in the oil and gas sector, where maintaining their structural integrity is essential for operational safety, environmental protection, and cost-efficiency. In Kazakhstan, traditional time-based inspection (TBI) methods dominate, despite their inefficiency and inflexibility. The integration of Risk-Based Inspection (RBI) with advanced Non-Destructive Testing (NDT) technologies offers a promising alternative to optimize inspection intervals and improve asset management, especially considering regulatory limitations and economic pressures that intensified during the COVID-19 pandemic.

Aim: To optimize re-inspection intervals for ASTs in Kazakhstan’s oil and gas industry by integrating RBI methodologies with advanced NDT technologies, particularly ROSEN TBIT Ultra, and to compare these with traditional inspection methods.

Materials and methods: RBI methodology outlined in API RP 580 and 581, industrial data for the given tank X.

Results: The integration of RBI and advanced NDT enabled prioritization of high-risk tanks, identification of localized corrosion mechanisms, and optimization of inspection intervals. Compared to the rigid TBI schedule, the proposed approach demonstrated higher inspection efficiency, lower resource wastage, and reduced risk of catastrophic failure, while aligning with global standards and local legal frameworks.

Conclusion: By adopting RBI methodologies supported by technologies like ROSEN TBIT Ultra, Kazakhstan’s oil and gas industry can transition from fixed-interval inspections toward a predictive, risk-prioritized approach. This transition supports better asset integrity management, enhances safety, and contributes to long-term infrastructure reliability, especially critical for aging storage systems.

Many of Kazakhstan’s major oil fields are now entering a phase of declining production, marking a new stage in the country’s oil and gas industry development. The development of heavy-oil reservoirs presents several well-recognized challenges for oil producers. These include equipment performance issues, shorter operating life of surface and downhole systems, higher failure rates under increased loads, low well productivity, and persistent difficulties in utilizing associated gas. Collectively, these factors severely undermine the overall profitability of field development and production. A wide range of studies has explored the mechanisms of emulsification and demulsification. Stable emulsions create both technical and economic challenges for the industry, particularly in treatment, refining, and transportation operations. Addressing them effectively is crucial for maintaining efficient hydrocarbon production. This paper discusses the formation of crude-oil emulsions, approaches to their demulsification, properties of suitable demulsifiers, and the mechanisms governing emulsion formation. Crude oil contains natural surface-active compounds that readily promote the formation of stable emulsions. To meet industrial standards, these emulsions must undergo thorough treatment. Understanding the role of natural surfactants that enhance emulsion stability is therefore key to achieving effective oil–water separation. The review also considers various published mechanisms of emulsification and identifies the formulations most effective for demulsification.

Background: Pollutants, mainly heavy metals, accumulate in the coastal zone of the Caspian Sea and degrade local and regional ecosystems. Their presence affects living organisms and drives the transfer of toxic substances through food chains. Heavy metals impair green biomass at the molecular level by disrupting plant cell functions. The Normalized Difference Vegetation Index (NDVI), derived from satellite imagery, tracks changes in photosynthetic activity and plant vitality over time. Combining soil heavy metals analysis with NDVI enables monitoring at both ground and satellite levels.

Aim: The study aims to conduct integrated geo-ecological monitoring of soil and vegetation in the Caspian Sea coastal zone near Shapagatova village.

Materials and methods: Atomic absorption spectrometry was used to determine heavy metals in soil samples. Physico-chemical methods were applied to assess agrochemical properties of soils, and NDVI was calculated using standard procedures.

Results: A marked decrease in soil heavy metal concentrations, attributed to natural phytoremediation was observed. This process explains the loss of vegetation cover in the study area during the five-year period from 2019 to 2023.

Conclusion: The sharp decline in heavy metal concentrations is closely linked to changes in the NDVI index. Between 2019 and 2021, when heavy metal levels exceeded maximum allowable concentrations, plants showed a reduced photosynthetic response, with the lowest values recorded in 2021. This reflects the toxic impact on vegetation, while the concurrent drop in metal concentrations that year is attributed to plant uptake. By 2023, with heavy metal levels decreasing more than twentyfold, NDVI values increased significantly, indicating recovery of plant biomass in the study area.

Background: Climate change is one of the most pressing global issues, affecting ecosystems, economies, and communities worldwide. As global temperatures rise and weather conditions become increasingly unpredictable, the need for decisive action to reduce greenhouse gas emissions is more urgent than ever. Both businesses and governments recognize the importance of transitioning to a low-carbon economy to ensure sustainable development and the rational use of natural resources.

Aim: The aim of this study is to examine the feasibility of applying CO₂ capture technology with subsequent injection into reservoirs for storage purposes

Materials and methods: Materials from INPEX were used, taking into account actual results of CO₂ capture and storage projects in Japan. Geological and physical data on oil and gas fields located within a 100 km radius of the gas processing facility in the Atyrau region of Kazakhstan were analyzed to assess the technical feasibility of CO₂ injection. Calculations were performed using UniSim Design software, where the technological process was modeled from flue gas intake to the injection of captured CO₂ into the reservoir

Results: The technological feasibility of CO₂ capture and subsequent injection was determined, and both the capture site and the storage reservoir were selected

Conclusion: Potential storage traps located near the developed fields of KMG were screened for CO₂ injection and storage. Regions with the highest emissions within a 100 km radius of the emission sources were evaluated. For analytical studies to determine the feasibility of CO₂ capture and storage, a gas processing facility at one of KMG’s fields in Western Kazakhstan was chosen as the emission source. This technology has not previously been applied in Kazakhstan; therefore, experience from projects in other countries, which demonstrated positive outcomes, was used as a reference

Background: The oil and gas industry frequently face budget overrun issues. Project costs increase, stakeholders are dissatisfied, and overall performance suffers. To avoid this, it is important to find effective methods for preventing or mitigating the risk of cost overruns.

Aim: The objective of the study is to analyze the relationship between resource-related factors, such as labor, equipment, and material factors, and cost overruns in the oil and gas projects in Kazakhstan.

Materials and methods: A structured survey consisting of 15 resource-related risk factors was distributed to experienced professionals working in the oil and gas sector. A total of 172 valid responses were gathered. The data were evaluated using descriptive statistics, econometric methods and partial-least squares structural equation modeling (PLS-SEM) to assess reliability, validity, causal relationships, and regressed variables.

Results: The empirical analysis shows that labor-related risks, including labor shortages, low productivity, and labor incompetence, have the most substantial and statistically significant impact on cost overruns. Material-related and equipment-related risks demonstrate a moderate yet meaningful effect. All three latent constructs exhibit internal consistency and convergent validity. Furthermore, change orders and financial difficulties are also strong contributors to cost escalations.

Conclusion: The study concludes that effective resource planning is critical for minimizing cost overruns and ensuring the successful execution of oil and gas projects in Kazakhstan. Improving workforce competency, enhancing material supply reliability, and efficiently providing physical resources are recommended practices for overall project management body of knowledge.