Kazakhstan journal for oil & gas industry
Peer-review scholarly journal. Included in the list of recommended publications by the Committee for Quality Assurance in the Field of Science and Higher Education of the Ministry of Science and Higher Education of the Republic of Kazakhstan for the publication of the main results of scientific activities. Editor-in-Chief: Rakhim Nagangaliuly Uteyev Indexation: Google Scholar, Ulrich's Periodicals Directory, CrossRef Access & Distribution: Quarterly journal; Platinum Open Access; CC BY-NC-ND 4.0. ISSN: 2707-4226 (Print) ISSN: 2957-806X (Online)
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Authors are permitted and encouraged to post their work online (e.g., in institutional repositories or on their website) prior to and during the submission process, as it can lead to productive exchanges, as well as earlier and greater citation of published work (See The Effect of Open Access). All the Copyright statements for authors are present in the standart Publishing Agreement (Public Offer) to Publish an Article in an Peer-review science journal 'Kazakhstan journal for oil & gas industry'. READ the details online (tap to see in details) Publishing Agreement (Public Offer) to Publish an Article in an Academic Periodical 'Kazakhstan journal for oil & gas industry' KMG ENGINEERING LLP, represented by Renat G. 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Aggrading palaeozoic carbonate massifs. the main consedimentary megastructures in the ultra-deep intervals of the Central Asian Sedimentary Basin
Palaeozoic carbonates exposed in the Karatau Ridge of southern Kazakhstan represent isolated offshore carbonate massifs that developed as shallow- marine carbonate mounts within the ancient Proto-Tethys Ocean. These massifs aggraded in response to tectonic subsidence, forming prominent positive relief features on the ocean floor. Repeated sea level oscillations led to periodic subaerial exposures and associated karstification, while meteoric-marine mixing in their margins led to dolomitization. Together, these processes generated extensive karst voids and secondary porosity that later served as hydrocarbon reservoirs. Subsequent fold-and-thrust deformations and orogenesis, uplifted and exposed giant fragments of carbonate massifs, enabling detailed stratigraphic and sedimentological investigations, which provide valuable insights for geological exploration across the sedimentary basins of Central Asia.
Copyright (c) 2026 Zhemchuzhnikov V.G., Fustich M., Akhmetzhanov A.Z., Dossan A.D., Kurbaniyazov S.K. https://creativecommons.org/licenses/by-nc-nd/4.0
On the causes and mechanism of deterioration of the properties of drilling mud when drilling wells in the intervals of water-saturated layers of jurassic sediments at the Uzen and Karamandybas fields
Background: This work is devoted to the problem typical for the Uzen and Karamandybas deposits of the formation of downhole packs of drilling mud in the trunk of drilling wells with degraded viscosity, rheological and filtration characteristics in the intervals of occurrence of water-saturated layers of Jurassic sediments after the working drilling mud has been in these intervals in a static state for several hours to 1 day or more. Moreover, this happens even without fixed signs of water ingress. It is explained that the reason for this is the effect on the drilling mud of formation waters with higher mineralization and hardness than the aqueous phase of the mud. However, in the absence of water manifestations in a static state, this effect does not occur as a result of direct physical mixing of these liquids, but as a result of diffusion and osmotic mass transfer between formation waters and the dispersion medium of the drilling mud. Aim: The article reveals the mechanism of deterioration of the technological properties of the drilling mud caused by a significant increase in mineralization and the overall hardness of the aqueous phase of the solution as a result of the above-mentioned mass transfer processes. Materials and methods: The test drilling mud samples used were actual samples taken from the circulation systems of drilling wells at the Uzen field, as well as a model of Jurassic formation water prepared in the laboratory using sodium, calcium, and magnesium chloride salts. The main research methods were expert analysis and laboratory-experimental modeling of the interaction of field samples of drilling mud with a model of formation water without direct contact in a static state, with visual and instrumental determination of the properties of the mud before and after the specified interaction within 24 hours. Results: The study showed that the deterioration of drilling mud properties when it interacts with highly mineralized formation water of Jurassic deposits without direct mutual contact is due to diffusion-osmotic mass transfer between these two fluids, interacting in the “wellbore – drilling mud filter cake – formation” system. The results of laboratory and experimental studies conducted with modeling of all the specified elements of interaction between these fluids confirmed this explanation. Conclusion: As a result of a series of expert analytical and laboratory experimental studies, an answer was obtained regarding the causes of the deterioration of the technological properties of drilling muds located in the wellbore in a static state in intervals of formations saturated with highly mineralized formation waters with high hardness. The mechanism of this phenomenon, which occurs in the wellbore even without direct physical contact between these two fluids, has been explained. The practical application of the results obtained can and should find its place in the development, research, and practical application of drilling muds that are resistant to the polyminerals aggression of formation waters similar or close in their ion-salt composition to those described in this article.
Copyright (c) 2026 Bulda Y.A., Dzhalishev R.V., Kuatov R.Z., Primbetov S.A., Otebay B.M., Sarbopeyev O.K. https://creativecommons.org/licenses/by-nc-nd/4.0
Acid hydraulic fracturing in complex interbedded reservoirs
*]:pointer-events-auto [content-visibility:auto] supports-[content-visibility:auto]:[contain-intrinsic-size:auto_100lvh] scroll-mt-[calc(var(--header-height)+min(200px,max(70px,20svh)))]" dir="auto" tabindex="-1" data-turn-id="request-WEB:ec4f6a3d-6fad-43fb-9aee-6ce2cf5fe0ff-0" data-testid="conversation-turn-2" data-scroll-anchor="true" data-turn="assistant"> Background: Preventing contamination of technogenic fractures formed by hydraulic fracturing and by chemical interaction of reactive fluids with the rock is a key condition for increasing reservoir fluid production rates. Reducing the risks of formation and precipitation of insoluble reaction products within the fracture and the near-fracture zone is achieved through experimental research and mathematical modelling of the interaction processes between technological fluids, reservoir rocks, and formation fluids. At the same time, the most important task in preparation for experiments, modelling, and the actual execution of operations can be considered the identification of the principal interacting elements entering into reactions whose products may reduce stimulation efficiency, especially under conditions of limited availability of core material and specialized software for comprehensive chemical molecular modelling. Consequently, theoretical investigation of the main causes of unsuccessful chemical treatments of formations and hydraulic fracturing operations with chemically active technological fluids, as well as assessment of the risks of negative events, becomes particularly important. Aim: Increasing the efficiency of stimulation by acid hydraulic fracturing methods through optimization of technological fluid composition and prevention of the negative impact on the reservoir of reaction products formed by interaction of reservoir rocks or formation fluids with technological fluids. Materials and methods: To evaluate the main causes of insoluble precipitate formation and other factors for reduced stimulation efficiency, a detailed literature review was carried out, and mechanisms increasing and decreasing the corresponding risks were identified. A mechanical and lithological model was constructed in the vicinity of several wells of one of the Central Asian fields, which shows that one of the main reactions leading to negative consequences may occur when several conditions are simultaneously met. The feasibility of such conditions was assessed based on calculations and modelling. Results: Analysis of the geological and mechanical environment at one of the fields and a detailed study of the main reactions with formation rocks made it possible to identify the causes of ineffective acid hydraulic fracturing treatments. A treatment program was prepared aimed at preventing future risks of reduced efficiency of acid hydraulic fracturing. Conclusion: The applied approach is aimed at the justified, targeted selection of hydraulic fracturing technological fluids, which makes it possible to reduce risks or prevent fracture plugging by reaction products, avoid clay migration and swelling, and other negative impacts on the filtration properties of the formation in the vicinity of technogenic fractures. All these measures are aimed at improving the efficiency of stimulation by acid hydraulic fracturing.
Copyright (c) 2026 Duisaliyev A.M., Ismailov A.A. https://creativecommons.org/licenses/by-nc-nd/4.0
Methodological approaches to analyzing the effectiveness of hydraulic fracturing: a case study of the M field
Background: The work aims to address sand production issues and low mean time between failures (MTBF) of wells at Field M by adapting hydraulic fracturing technology for poorly consolidated formations. The scientific novelty lies in the justification of using hydraulic fracturing as a method for creating a consolidated screen that functions as a downhole filter. The proposed approach achieves a negative skin factor while simultaneously stabilizing the formation skeleton. The practical significance is confirmed by the complete elimination of sand production and improved well operation efficiency in shallow depth conditions. Aim: To demonstrate the first practical experience in Kazakhstan of implementing hydraulic fracturing in an unconventional reservoir – a poorly consolidated, highly permeable formation with high-viscosity oil at shallow reservoir depth. Materials and methods: This study is based on field data and operational reports from hydraulic fracturing (HF) activities at Field M. Geomechanical and filtration properties of the formation were simulated, and fracture propagation was modeled in the FracPro software using actual injection parameters. The resulting models were compared with the outcomes of the implemented HF treatments, allowing evaluation of the correspondence between design solutions and field performance, as well as analysis of the effectiveness of the conducted interventions. This work represents Kazakhstan’s first practical experience of implementing HF in an unconventional reservoir: a poorly cemented, highly permeable formation containing high-viscosity oil at shallow depth. Results: The study analyzed the actual HF operations performed on wells at the M field. Modeling of fracture parameters was conducted in FracPro using real-world injection data. Comparing the calculated and actual performance indicators allowed for the evaluation of treatment efficacy, validation of achieved production rates against design expectations, and identification of key result-influencing factors. A comprehensive analysis was also performed of the geological and technical conditions, reservoir structure, and initial filtration-capacitance properties (FCP) of the formation. Key factors affecting the results included the selection of the optimal concentration of the adhesive composition for proppant consolidation and the control of net pressure during the injection process. Practical recommendations were developed for optimizing the design and execution of HF in reservoirs at depths below 500 m. Conclusion: The findings confirm the necessity of further optimization in HF design and execution at the M field, particularly regarding the refinement of injection parameters and correction of the model’s filtration-storage characteristics. This comprehensive analytical approach not only improves the efficacy of already performed treatments but also forms the basis for selecting optimal candidates and enhancing HF design in future projects.
Copyright (c) 2026 Sagyngali N.N., Baspayev Y.T., Bashev A.A., Jaksylykov T.S., Mardanov A.S., Mukatov Z.A. https://creativecommons.org/licenses/by-nc-nd/4.0
Evaluating integrity of storage tank bottoms based on advanced MFL/ET scanning: use case in Kazakhstan
Background: Ensuring the structural integrity of aboveground storage tanks (ASTs), especially their bottoms, is critical for the safe and efficient operation of oil and gas facilities. Traditional inspection methods often fail to detect early-stage corrosion and defects. Aim: This study aims to evaluate the effectiveness of advanced Magnetic Flux Leakage (MFL) and Eddy Current Testing (ET) techniques for assessing AST bottom integrity and optimizing predictive maintenance strategies in Kazakhstan. Materials and methods: A dataset of 27 ASTs across different regions of Kazakhstan was analyzed using ROSEN TBIT Ultra technology and ROSOFT for Tanks software. Over 97000 anomalies were detected and categorized by type, location, and corrosion depth. Analytical comparisons were made across tank sizes, regions, service life, and presence of galvanic protection systems. Results: The results indicate a strong correlation between anomaly density and tank service life, volume, and environmental conditions. MFL/ET scanning proved more effective than traditional ultrasonic methods in detecting internal and external corrosion. The application of galvanic protection showed only partial reduction in corrosion rates. Systematic scanning significantly enhanced defect localization and maintenance planning. Conclusion: The integration of MFL and ET into RBI strategies allows for early detection of defects, optimized maintenance, reduced downtime, and enhanced safety. This approach is especially beneficial for aging infrastructure in Kazakhstan’s oil and gas industry.
Copyright (c) 2026 Ualiyev D.A., Mirzoev A. https://creativecommons.org/licenses/by-nc-nd/4.0
Radiation-induced crosslinking of polyethylenes under different media for construction and oil & gas applications
Background: Foamed polyethylene is widely used in construction and in the oil and gas industry as a thermal and acoustic insulation material. Its popularity stems from low thermal conductivity, moisture resistance, and chemical stability. However, its durability and long-term performance remain limited. Radiation crosslinking provides an effective modification method by creating a three-dimensional polymer network and improving resistance to degradation. Aim: This study examines the effects of electron beam dose and gas atmosphere (air, argon, nitrogen) on the crosslinking degree of polyethylenes used in construction and oil and gas insulation. Materials and methods: Polyethylene samples irradiated with electron beams at doses of 75, 125, and 175 kGy in three atmospheres: air, argon, and nitrogen. Crosslinking was evaluated through gel fraction analysis following GOST R 59112–2020. Structural changes were characterized by FTIR spectroscopy using Infralum FT-08 (Russia) and Shimadzu IR Spirit (Japan). Results: Maximum crosslinking was observed at 125 kGy. Irradiation in inert atmospheres (argon and nitrogen) yielded higher gel fractions than in air, where degradation processes predominated. findings confirm a direct correlation between irradiation conditions and the structural stability of polyethylene. Conclusion: Radiation crosslinking significantly improves the performance of polyethylene by enhancing its thermal, chemical, and mechanical resistance. This approach can be recommended for producing long-lasting insulation and protective materials in both construction and oil and gas applications.
Copyright (c) 2026 Seitenova G.Z., Syzdyk A.G., Dyussova R.M., Baygazinov Z.A., Nurkassimov A.K., Kassymzhanov M.T. https://creativecommons.org/licenses/by-nc-nd/4.0
Study of the sulfidogenic bacteria activity in the formation microflora of an oil field (Kazakhstan) and their potential contribution to corrosion processes
Background: Today at the oil field «N» there is an intensification of corrosion complications. Repeated monitoring of corrosion factors at all sites of the field has shown the localization of aggressive gases at site B, where thermal oil displacement technology is used, which could have triggered an increase in corrosion processes. In addition, large-scale studies of the microbial community of formation waters were conducted at field N, revealing the presence of sulfate-reducing and fermentative sulfidogenic bacteria, which could also contribute to the development of an aggressive environment. In this regard, the issue of the influence of the microbial community on corrosion processes remains a pressing task, and studies were conducted to identify the contribution of sulfidogenic bacteria to the formation of a corrosion-aggressive environment at this field. Aim: To study the contribution of sulfidogenic bacteria of production waters to the formation of aggressive environments and corrosion at the N field. Materials and methods: The objects of the study were samples of water extracted from group installations, wastewater from block cluster pumping stations, and vertical steel tanks. The studies were conducted using classical microbiological methods: anaerobic cultivation of bacteria, sowing using the tenfold dilution method, obtaining biofouling of the object under study in a natural environment, etc. A titrimetric method was used to determine the content of hydrogen sulfide and carbon dioxide. The dissolved oxygen content was determined by an express method using a Fibox 4 PreSens (Germany) fiber optic oxygen analyzer. The amount of mechanical impurities was determined by filtration followed by gravimetric analysis. The corrosion rate of steel coupons was determined gravimetrically by the loss of sample mass during their exposure at field facilities. Results: All studied objects showed high content of planktonic (105–108 cells/ml) and adherent (106–108 cells/ml) sulfidogenic bacteria. The productivity of different physiological groups of sulfidogenic bacteria was determined: sulfate-reducing bacteria contribute most to hydrogen sulfide formation (125.6–762.5 mg/L), while sulfur-reducing bacteria contribute least (59.6–298.2 mg/L). Site B of the field, where development is carried out using thermal technology, is characterized by the highest corrosion potential. At the same time, the number of sulfidogenic bacteria at site B is comparable to their number at other sites of the field. Conclusion: The microflora of the production waters of the N deposit has a high corrosion potential, but the greatest contribution to the formation of an aggressive environment is due to the use of thermal oil recovery technology at the deposit.
Copyright (c) 2026 Bissenova M.A., Bidzhieva S.K. https://creativecommons.org/licenses/by-nc-nd/4.0
Optimization results of the ELOU-AVT unit at the Atyrau Oil Refinery
Background: Increasing the depth of oil refining and improving the quality of commercial petroleum products are directly related to the efficiency of primary processing, particularly atmospheric oil distillation. This problem is extremely relevant for the modern oil and gas industradoy, since primary crude oil processing units operating in Kazakhstan were constructed during the Soviet period and therefore require modernization. Aim: Development and experimental evaluation of technological methods for intensifying atmospheric and vacuum crude oil distillation at the ELOU-AVT unit of the Atyrau Refinery, aimed at reducing the content of light fractions in fuel oil and increasing the yield of valuable distillate products. Materials and methods: To study the fractional composition of fuel oil, the ARN laboratory setup was used. Data from analytical control of ELOU-AVT products and material balance calculations are presented. Diagrams illustrating the yield of light petroleum products were constructed to visualize the obtained results. Results: Based on laboratory research, it was found that the content of light petroleum products in fuel oil exceeded the norm. To increase the yield of vacuum gas oil, raise the coke residue of the tar, and reduce the output of fuel oil at the ELOU-AVT unit, technological measures were implemented to increase the supply of live steam to the bottom of the atmospheric column and reduce its consumption in the vacuum column. During the experimental and design phase, the content of light petroleum products in fuel oil was reduced from 7% to 5.5%. The coke residue of tar increased from 10.199% to 10.619%. An increase in the yield of gasoline, jet fuel, vacuum gas oil, and vacuum diesel fuel was recorded. Conclusion: The calculations and analysis carried out confirm the feasibility of investing in the development of a modernized autonomous oil platform that has improved ice resistance and meets all safety requirements for operation in the North Caspian Sea.
Copyright (c) 2026 Karabassova N.A., Kayrliyeva F.B., Shambilova G.K., Shiriyazdanov R.R. https://creativecommons.org/licenses/by-nc-nd/4.0
Structural calculations of an ice-resistant satellite platform for the Kazakh sector of the Caspian Sea
Background: The Kazakh sector of the Caspian Sea faces problems of economic efficiency, environmental sustainability, and operational safety. This necessitates the development of an innovative oil production platform. Within this framework, it is proposed to create an unmanned platform with minimal technological equipment, designed for use as a satellite platform in projects on the northern Caspian Sea shelf. The development of an ice-resistant platform is a key task for successful oil production in ice conditions. Aim: The research is aimed at developing an ice-resistant platform design capable of withstanding static collisions with ice floes. The objective of the research is to develop a modernized autonomous oil platform suitable for use in the northern part of the Caspian Sea. Materials and methods: Existing offshore ice-resistant platforms were analyzed, including the Varandey terminal (Russia), Bohai Sea (China), Filanovsky (Russia), and Bufart Sea (Canada). Ice loads were calculated in accordance with the international standard ISO 19906. An analysis was conducted demonstrating the ability of the caisson structure to withstand static loads from ice floes. Results: The modernized platform design and the method of fixing it to the surface using suction columns and pile fastenings demonstrated the ability to withstand various loads in compliance with international safety standards, including static loads from ice floes. Conclusion: The calculations and analysis confirm the feasibility of investing in the development of a modernized autonomous oil platform with improved ice resistance and meeting all safety requirements for operation in the northern part of the Caspian Sea.
Copyright (c) 2026 Alzhanov N.K., Tleshev M.T. https://creativecommons.org/licenses/by-nc-nd/4.0
Development of an automated module for assessing the management reserve for contingencies in oil and gas construction planning
Background: Existing Russian and international principles for establishing management reserves for contingencies (hereinafter – MRC) in capital construction planning within the oil and gas sector differ significantly. The authors propose their own methodology for assessing the MRC and describe a calculation algorithm based on an automated risk management module developed by Ingenix Group LLC using this methodology. Aim: The aim of this work is to provide a more accurate accounting of risks in the evaluation of oil and gas projects, taking into account the project implementation stage and the complexity of capital construction facilities. Materials and methods: The methodology is based on a synthesis of international practices, including the classification of the Association for the Advancement of Cost Engineering International (hereinafter – AACEI) and the recommendations of the U.S. Department of Energy (hereinafter – DoE), as well as Russian regulations. The authors propose adapting the DoE contingency reserve ranges to the AACEI accuracy classes and applying them at the individual project level, aligning them with Russian design stages. The automated MRC assessment module is implemented as part of the proprietary Ingenix Cost Manager® software suite for evaluating costs of oil and gas projects. Results: The article provides detailed information and recommendations on the size of the MRC depending on the project stage (feasibility study, design documentation, etc.) and the complexity class of the facility. The methodology has been tested on a real project, demonstrating the feasibility of calculating a justified total contingency reserve for the project. Conclusion: The proposed methodology facilitates a quantitative assessment of the MRC at different project stages, considering the specific characteristics and complexity of each facility. This approach helps mitigate the risk of underfunding and enhances the likelihood of compliance with the budget and achievement of the project’s targeted profitability. The automated assessment module enables rapid calculations using all available project data and ensures accurate incorporation of the MRC in evaluating the construction costs of facilities.
Copyright (c) 2026 Chizhikov S.V., Dubovitskaya Y.A., Akhmetov R.N., Kadyrova S.D. https://creativecommons.org/licenses/by-nc-nd/4.0